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Gibson Energy

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FY2018 Annual Report · Gibson Energy
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ANNUAL REPORT 2018

IN THIS REPORT

1  Management’s Discussion & Analysis

45  Consolidated Financial Statements

Management’s 

Discussion and Analysis

2018 Year End Report

Management’s 
Discussion and Analysis
2018 Year End Report

Contents 

BUSINESS OVERVIEW  _____________________________________________________________________  2 

SELECTED FINANCIAL MEASURES ____________________________________________________________  3 

2018 REVIEW ____________________________________________________________________________  4 

PROJECT DEVELOPMENTS AND MARKET OUTLOOK  _____________________________________________  6 

RESULTS OF CONTINUING OPERATIONS _______________________________________________________  7 

BUSINESS OVERVIEW  

INFRASTRUCTURE _______________________________________________________________________________ 8 

LOGISTICS ____________________________________________________________________________________ 11 

WHOLESALE  __________________________________________________________________________________ 12 

EXPENSES ______________________________________________________________________________  14 

RESULTS OF DISCONTINUED OPERATIONS ____________________________________________________  16 

SUMMARY OF QUARTERLY RESULTS  ________________________________________________________  20 

LIQUIDITY AND CAPITAL RESOURCES ________________________________________________________  23 

Liquidity Sources _______________________________________________________________________________ 23 

Capital expenditures and acquisitions ______________________________________________________________ 25 

Capital structure _______________________________________________________________________________ 26 

Dividends  ____________________________________________________________________________________ 27 

Distributable cash flow  _________________________________________________________________________ 27 

Contractual obligations and contingencies __________________________________________________________ 30 

OFF-BALANCE SHEET ARRANGEMENTS  ______________________________________________________  30 

OUTSTANDING SHARE DATA  ______________________________________________________________  30 

opportunities; 

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK ____________________________  31 

pursue high quality cash flows to underpin our dividend and fund growth capital; 

ACCOUNTING POLICIES ___________________________________________________________________  32 

DISCLOSURE CONTROLS & PROCEDURES _____________________________________________________  36 

RISK FACTORS  __________________________________________________________________________  37 

funding costs and increase our access to capital;  

FORWARD-LOOKING INFORMATION ________________________________________________________  41 

NON-GAAP FINANCIAL MEASURES __________________________________________________________  42 

  maintain a strong balance sheet and financial position through targeting a debt leverage ratio of 3.0x – 3.5x and a payout 

ratio of 70% – 80% of distributable cash flow 1. We anticipate being fully funded for our growth capital through the end of 

2019 through internally generated cash flows and proceeds from non-core asset dispositions and will subsequently seek to 

fund growth capital with a maximum of 50% - 60% debt. We also target an investment grade credit rating to decrease our 

remain highly skilled in building and operating our infrastructure while aggressively managing costs to maintain and improve 

operating margins. We will be customer-focused and will foster long-term relationships with our customers in order to better 

understand their infrastructure requirements and be more responsive in providing the best solutions for them; and 

continue our firm commitment to be a leader in environment, health, and safety. Our experienced leadership team has a 

proven history of successful operations and a strong industry reputation. 

The following Management’s Discussion and Analysis (“MD&A”) was prepared and approved by the Board of Directors (the “Board”) 

of Gibson Energy Inc. (“we”, “our”, “us”, its”, “Gibson Energy”, “Gibson” or the “Company”) as of March 4, 2019 and should be read 

in conjunction with the audited consolidated financial statements and related notes of the Company for the years ended December 

31, 2018 and 2017, which were prepared under International Financial Reporting Standards (“IFRS”) as set out in the Handbook of the 

Canadian Institute of Chartered Professional Accountants and as issued by the International Accounting Standards Board (“IASB”), 

also  referred  to  as  GAAP.  Amounts  are  stated  in  thousands  of  Canadian  dollars  except  per  share  data,  unless  otherwise  noted. 

Additional information about Gibson, including the Annual Information Form for the year ended December 31, 2018 (“AIF”) is available 

on SEDAR at www.sedar.com and on our website at www.gibsonenergy.com. This MD&A contains forward-looking statements and 

non-GAAP measures and readers are cautioned that this MD&A should be read in conjunction with the Company’s disclosure under 

“Forward-Looking Statements” and “Non-GAAP Financial Measures” included at the end of this MD&A. 

Gibson  is  a  Canadian-based  oil  infrastructure  company  with  its  principal  businesses  consisting  of  the  storage,  optimization, 

processing, and gathering of crude oil and refined products. Headquartered in Calgary, Alberta, the Company’s operations are focused 

around  its  core  terminal  assets  located  at  Hardisty  and  Edmonton,  Alberta,  and  also  include  the  Moose  Jaw  Facility  and  an 

infrastructure position in the United States (U.S.). 

Our strategy and strengths 

The key attributes of our strategy are: 

an oil infrastructure focus, with the Infrastructure segment targeting to comprise approximately 85% of segment profit and 

the terminals and pipelines representing approximately 75% of total segment profit;  

targeting 10% distributable cash flow per share growth 1; and 

offering a secure, growing dividend that is underpinned by long-term contracts with investment grade counterparties at its 

terminal assets, with total Company cash flows expected to be comprised of approximately 85% take-or-pay, stable fee-

based structures, inclusive of internal take-or-pay. 

In order to be successful in our strategy we will: 

leverage our competitive position at our terminals to continue to secure a significant proportion of new tankage business. 

Through offering the most connectivity to inbound and outbound pipelines at Hardisty, as well as exclusive access to the 

only  unit  train  rail  facility  at  Hardisty,  we  have  built  a  position  that  provides  us  a  competitive  advantage  to  service  our 

customers. We intend to harvest additional opportunities within our terminals to provide incremental connectivity and other 

services to existing terminal customers; 

seek complementary growth through our basin strategy, focusing on the oil sands, Viking and Duvernay basins in Canada, 

and the Permian and SCOOP / STACK basins in the U.S. Within these basins, we will leverage our core terminals and growing 

infrastructure  position  in  the  U.S.  to  advantage  us  in  competing  for  gathering  pipeline  and  related  infrastructure 

 

 

 

 

 

 

 

 

1 See definition of non-GAAP measures on page 28 and 42. 

      Gibson Energy Inc.                                                            2                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            1                                              Management’s Discussion and Analysis  
Gibson Energy

2 

Management’s Discussion and Analysis 

 
 
                                                 
 
 
 
 
Contents 

BUSINESS OVERVIEW  _____________________________________________________________________  2 

SELECTED FINANCIAL MEASURES ____________________________________________________________  3 

2018 REVIEW ____________________________________________________________________________  4 

PROJECT DEVELOPMENTS AND MARKET OUTLOOK  _____________________________________________  6 

RESULTS OF CONTINUING OPERATIONS _______________________________________________________  7 

INFRASTRUCTURE _______________________________________________________________________________ 8 

LOGISTICS ____________________________________________________________________________________ 11 

WHOLESALE  __________________________________________________________________________________ 12 

EXPENSES ______________________________________________________________________________  14 

RESULTS OF DISCONTINUED OPERATIONS ____________________________________________________  16 

SUMMARY OF QUARTERLY RESULTS  ________________________________________________________  20 

LIQUIDITY AND CAPITAL RESOURCES ________________________________________________________  23 

Liquidity Sources _______________________________________________________________________________ 23 

Capital expenditures and acquisitions ______________________________________________________________ 25 

Capital structure _______________________________________________________________________________ 26 

Dividends  ____________________________________________________________________________________ 27 

Distributable cash flow  _________________________________________________________________________ 27 

Contractual obligations and contingencies __________________________________________________________ 30 

OFF-BALANCE SHEET ARRANGEMENTS  ______________________________________________________  30 

OUTSTANDING SHARE DATA  ______________________________________________________________  30 

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK ____________________________  31 

ACCOUNTING POLICIES ___________________________________________________________________  32 

DISCLOSURE CONTROLS & PROCEDURES _____________________________________________________  36 

RISK FACTORS  __________________________________________________________________________  37 

FORWARD-LOOKING INFORMATION ________________________________________________________  41 

NON-GAAP FINANCIAL MEASURES __________________________________________________________  42 

      Gibson Energy Inc.                                                            1                                              Management’s Discussion and Analysis  

The following Management’s Discussion and Analysis (“MD&A”) was prepared and approved by the Board of Directors (the “Board”) 
of Gibson Energy Inc. (“we”, “our”, “us”, its”, “Gibson Energy”, “Gibson” or the “Company”) as of March 4, 2019 and should be read 
in conjunction with the audited consolidated financial statements and related notes of the Company for the years ended December 
31, 2018 and 2017, which were prepared under International Financial Reporting Standards (“IFRS”) as set out in the Handbook of the 
Canadian Institute of Chartered Professional Accountants and as issued by the International Accounting Standards Board (“IASB”), 
also  referred  to  as  GAAP.  Amounts  are  stated  in  thousands  of  Canadian  dollars  except  per  share  data,  unless  otherwise  noted. 
Additional information about Gibson, including the Annual Information Form for the year ended December 31, 2018 (“AIF”) is available 
on SEDAR at www.sedar.com and on our website at www.gibsonenergy.com. This MD&A contains forward-looking statements and 
non-GAAP measures and readers are cautioned that this MD&A should be read in conjunction with the Company’s disclosure under 
“Forward-Looking Statements” and “Non-GAAP Financial Measures” included at the end of this MD&A. 

BUSINESS OVERVIEW  
Gibson  is  a  Canadian-based  oil  infrastructure  company  with  its  principal  businesses  consisting  of  the  storage,  optimization, 
processing, and gathering of crude oil and refined products. Headquartered in Calgary, Alberta, the Company’s operations are focused 
around  its  core  terminal  assets  located  at  Hardisty  and  Edmonton,  Alberta,  and  also  include  the  Moose  Jaw  Facility  and  an 
infrastructure position in the United States (U.S.). 

Our strategy and strengths 

The key attributes of our strategy are: 

 

 
 

an oil infrastructure focus, with the Infrastructure segment targeting to comprise approximately 85% of segment profit and 
the terminals and pipelines representing approximately 75% of total segment profit;  
targeting 10% distributable cash flow per share growth 1; and 

offering a secure, growing dividend that is underpinned by long-term contracts with investment grade counterparties at its 
terminal assets, with total Company cash flows expected to be comprised of approximately 85% take-or-pay, stable fee-
based structures, inclusive of internal take-or-pay. 

In order to be successful in our strategy we will: 

 

 

leverage our competitive position at our terminals to continue to secure a significant proportion of new tankage business. 
Through offering the most connectivity to inbound and outbound pipelines at Hardisty, as well as exclusive access to the 
only  unit  train  rail  facility  at  Hardisty,  we  have  built  a  position  that  provides  us  a  competitive  advantage  to  service  our 
customers. We intend to harvest additional opportunities within our terminals to provide incremental connectivity and other 
services to existing terminal customers; 

seek complementary growth through our basin strategy, focusing on the oil sands, Viking and Duvernay basins in Canada, 
and the Permian and SCOOP / STACK basins in the U.S. Within these basins, we will leverage our core terminals and growing 
infrastructure  position  in  the  U.S.  to  advantage  us  in  competing  for  gathering  pipeline  and  related  infrastructure 
opportunities; 

pursue high quality cash flows to underpin our dividend and fund growth capital; 

 
  maintain a strong balance sheet and financial position through targeting a debt leverage ratio of 3.0x – 3.5x and a payout 
ratio of 70% – 80% of distributable cash flow 1. We anticipate being fully funded for our growth capital through the end of 
2019 through internally generated cash flows and proceeds from non-core asset dispositions and will subsequently seek to 
fund growth capital with a maximum of 50% - 60% debt. We also target an investment grade credit rating to decrease our 
funding costs and increase our access to capital;  

 

 

remain highly skilled in building and operating our infrastructure while aggressively managing costs to maintain and improve 
operating margins. We will be customer-focused and will foster long-term relationships with our customers in order to better 
understand their infrastructure requirements and be more responsive in providing the best solutions for them; and 

continue our firm commitment to be a leader in environment, health, and safety. Our experienced leadership team has a 
proven history of successful operations and a strong industry reputation. 

1 See definition of non-GAAP measures on page 28 and 42. 

Gibson Energy 

      Gibson Energy Inc.                                                            2                                              Management’s Discussion and Analysis  

Management’s Discussion and Analysis

3 

 
 
                                                 
 
 
 
 
SELECTED FINANCIAL MEASURES 

Continuing operations 2 
Segment profit 4 ......................................................  
Adjusted EBITDA 3,4 .................................................  
Cash flow from operating activities 4 ......................  
Distributable cash flow 3,4,6 .....................................  
Growth capital expenditures 4 ................................  

Combined operations 2 
Combined Adjusted EBITDA 2,3,4 ..............................  
Distributable cash flow 3,4,6 .....................................  

Three months ended December 31 
20171 

2018 

Years ended December 31 

2018 

20171 

$          153,569  
134,001  
262,044  
78,190  
81,745  

  $ 

$          71,387  
68,475  
37,371  
50,181  
56,271  

  $ 

$           487,087  
457,315  
527,086  
259,126  
221,198  

  $ 

$          261,758  
229,201  
175,272  
160,479  
151,154  

  $ 

  $         140,479              
  $           84,123                                 

  $          82,271     

$          73,556                      

  $          282,517   $          180,493                   

$          490,083   $          291,272  

Debt and dividend payout ratios 2,5 
Debt leverage ratio  ............................................................  
Interest coverage ratio ........................................................  
Combined dividend payout ratio 6 ......................................  

Last Twelve Months - As at December 31 
2017 

2018 

2.3 
6.7 
67% 

4.0 
3.7 
104% 

Revenue 4 ........................................................................... 
Net income (loss) 4 ............................................................. 
Basic income (loss) per share 4 ........................................... 
Diluted income (loss) per share 4 ....................................... 
Dividends declared ............................................................. 

Total assets  ....................................................................... 
Total non-current liabilities ................................................ 

For the years ended December 31 

  $ 

2018 
6,846,589
81,125
                 0.57
                 0.56
$          190,326

  $ 

20171 
5,659,646  
(66,326)
              (0.47)
              (0.47)
              $          188,470 

  $ 

20161 
4,221,712
(19,854)
             (0.15)
             (0.15)
$          181,994

2018
$      2,809,576
$      1,461,685

As at December 31 
                     20171 
          $      2,964,434       
          $      1,498,900 

                   20161 
$      3,261,347
$      1,639,045

1. 

2. 

3. 

4. 

5. 

6. 

The  current  period  results  include  the  impacts  from  the  adoption  of  new  accounting  standards  as  discussed  on  page  34.  Comparative 
information has not been restated and, therefore, may not be comparable. 

See definition of non-GAAP measures on pages 20 to 21 and 42. Combined Adjusted EBITDA and Combined distributable cash flow, represents 
the aggregated results of both continuing and discontinued operations.  

See  pages  21  to  22  and  28  to  29  for  a  reconciliation  of  Adjusted  EBITDA  to  segment  profit  and  distributable  cash  flow  to  cash  flow  from 
operations, respectively.  

Comparative period information has been represented to reflect the impact of discontinued operations.  

Refer to page 27 and 34 for more information on the ratio calculation and impact of new accounting standards adoption on the covenant 
calculations. 

The distributable cash flow calculation was revised during 2018 and comparative information has been restated, refer to page 29 for details. 

Management’s Discussion and Analysis 

      Gibson Energy Inc.                                                            3                                              Management’s Discussion and Analysis  
Gibson Energy

4 

2018 REVIEW 

Financial highlights 

o 

o 

o 

o 

o 

o 

o 

o 

o 

o 

o 

Segment profit for the Infrastructure segment of $283 million increased by $48 million, for the year ended December 31, 

2018 compared to $235 million, for the year ended December 31, 2017 primarily due to additional tankage brought into 

service at the beginning of 2018 under take-or-pay, stable fee-based contracts.  

Segment profit for the Wholesale segment of $211 million increased by $180 million, for the year ended December 31, 

2018 compared to $31 million, for the year ended December 31, 2017 due to higher margins earned from the refined 

product and the crude marketing businesses, and the impact of the adoption of IFRS 16 – Leases (“IFRS 16”) resulting in 

higher segment profit by $8.8 million and $40.1 million in the three months and year ended December 31, 2018, as noted 

in the “Accounting Policies” section. 

Segment profit from continuing operations of $487 million increased by $225 million, for the year ended December 31, 

2018 compared to $262 million, for the year ended December 31, 2017 driven by stronger performance from 

Infrastructure and Wholesale. 

Adjusted EBITDA from continuing operations of $457 million increased by $228 million, for the year ended December 31, 

2018  compared  to  $229  million,  for  the  year  ended  December  31,  2017  due  to  higher  segment  profits  from  the 

Infrastructure and Wholesale business segments. As at December 31, 2018, the debt to EBITDA leverage ratio was 2.3 on 

a trailing twelve-month basis. 

Distributable cash flow from combined operations of $283 million increased by $103 million, for the year ended December 

31,  2018  compared  to  $180  million,  for  the  year  ended  December  31,  2017.  Distributable  cash  flow  from  combined 

operations during the year ended December 31, 2018 resulted in a payout ratio of approximately 67%.  

Net income from continuing operations of $81 million increased by $147 million, for the year ended December 31, 2018 

compared to a net loss of $66 million, for the year ended December 31, 2017. 

In the fourth quarter of 2018 and 2017, the Company declared a dividend of $0.33 per common share, respectively. Total 

dividends declared for the years ended December 31, 2018 and 2017 were $190 million and $188 million, respectively or 

$1.32 per common share.  

Capital projects highlights 

During the year ended December 31, 2018, the Company incurred total growth capital expenditures, including acquisitions, 

of $302 million on construction of new tanks and related infrastructure at the Hardisty and Edmonton Terminals, the Viking 

Pipeline project (“Viking Pipeline”) and the extension of the Pyote gathering system.  

On January 3, 2018 the Company placed into service a total of 800,000 barrels of crude oil storage tank capacity and related 

pipeline connection infrastructure at the Edmonton Terminal which are underpinned by long-term take or pay contracts. 

On February 21, 2018, the Company announced the sanction of the $50 million Viking Pipeline.  

On August 8, 2018, the Company announced an additional $200 to $250 million of growth capital opportunities, consisting 

Sanction of 1.0 million barrels of new tankage at the Hardisty Terminal related to the second phase of development 

at the Top of the Hill portion of the Hardisty Terminal underpinned by long-term take or pay contracts; 

The acceleration of the U.S. strategy through investments made in and around its existing Pyote gathering system; 

of the following: 

 

 

 

and 

The expansion of the Moose Jaw Facility. 

o  On  October  15,  2018,  the  Company  announced  the  sanction  of  an  additional  1.0  million  barrels  of  new  tankage  at  the 

Hardisty Terminal, underpinned by a long-term contract with an investment grade, senior oil sands customer.  

      Gibson Energy Inc.                                                            4                                              Management’s Discussion and Analysis  

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
SELECTED FINANCIAL MEASURES 

Three months ended December 31 

Years ended December 31 

2018 

20171 

2018 

20171 

Continuing operations 2 

Segment profit 4 ......................................................  

$          153,569  

$          71,387  

$           487,087  

$          261,758  

Adjusted EBITDA 3,4 .................................................  

Cash flow from operating activities 4 ......................  

Distributable cash flow 3,4,6 .....................................  

134,001  

262,044  

78,190  

68,475  

37,371  

50,181  

56,271  

457,315  

527,086  

259,126  

229,201  

175,272  

160,479  

151,154  

Growth capital expenditures 4 ................................  

  $ 

81,745  

  $ 

  $ 

221,198  

  $ 

Combined operations 2 

Combined Adjusted EBITDA 2,3,4 ..............................  

  $         140,479              

  $          82,271     

$          490,083   $          291,272  

Distributable cash flow 3,4,6 .....................................  

  $           84,123                                 

$          73,556                      

  $          282,517   $          180,493                   

Debt and dividend payout ratios 2,5 

Debt leverage ratio  ............................................................  

Interest coverage ratio ........................................................  

Combined dividend payout ratio 6 ......................................  

Last Twelve Months - As at December 31 

2018 

2.3 

6.7 

67% 

2018 

2017 

4.0 

3.7 

104% 

20171 

Revenue 4 ........................................................................... 

  $ 

6,846,589

  $ 

5,659,646  

  $ 

4,221,712

Net income (loss) 4 ............................................................. 

Basic income (loss) per share 4 ........................................... 

Diluted income (loss) per share 4 ....................................... 

81,125

                 0.57

                 0.56

(66,326)

              (0.47)

              (0.47)

Dividends declared ............................................................. 

$          190,326

              $          188,470 

$          181,994

20161 

(19,854)

             (0.15)

             (0.15)

For the years ended December 31 

Total assets  ....................................................................... 

Total non-current liabilities ................................................ 

$      2,809,576

$      1,461,685

          $      2,964,434       

          $      1,498,900 

$      3,261,347

$      1,639,045

2018

As at December 31 

                     20171 

                   20161 

The  current  period  results  include  the  impacts  from  the  adoption  of  new  accounting  standards  as  discussed  on  page  34.  Comparative 

information has not been restated and, therefore, may not be comparable. 

See definition of non-GAAP measures on pages 20 to 21 and 42. Combined Adjusted EBITDA and Combined distributable cash flow, represents 

the aggregated results of both continuing and discontinued operations.  

See  pages  21  to  22  and  28  to  29  for  a  reconciliation  of  Adjusted  EBITDA  to  segment  profit  and  distributable  cash  flow  to  cash  flow  from 

Comparative period information has been represented to reflect the impact of discontinued operations.  

Refer to page 27 and 34 for more information on the ratio calculation and impact of new accounting standards adoption on the covenant 

1. 

2. 

3. 

4. 

5. 

6. 

operations, respectively.  

calculations. 

The distributable cash flow calculation was revised during 2018 and comparative information has been restated, refer to page 29 for details. 

      Gibson Energy Inc.                                                            3                                              Management’s Discussion and Analysis  

2018 REVIEW 

Financial highlights 

o 

o 

o 

o 

o 

o 

o 

Segment profit for the Infrastructure segment of $283 million increased by $48 million, for the year ended December 31, 
2018 compared to $235 million, for the year ended December 31, 2017 primarily due to additional tankage brought into 
service at the beginning of 2018 under take-or-pay, stable fee-based contracts.  

Segment profit for the Wholesale segment of $211 million increased by $180 million, for the year ended December 31, 
2018 compared to $31 million, for the year ended December 31, 2017 due to higher margins earned from the refined 
product and the crude marketing businesses, and the impact of the adoption of IFRS 16 – Leases (“IFRS 16”) resulting in 
higher segment profit by $8.8 million and $40.1 million in the three months and year ended December 31, 2018, as noted 
in the “Accounting Policies” section. 

Segment profit from continuing operations of $487 million increased by $225 million, for the year ended December 31, 
2018 compared to $262 million, for the year ended December 31, 2017 driven by stronger performance from 
Infrastructure and Wholesale. 

Adjusted EBITDA from continuing operations of $457 million increased by $228 million, for the year ended December 31, 
2018  compared  to  $229  million,  for  the  year  ended  December  31,  2017  due  to  higher  segment  profits  from  the 
Infrastructure and Wholesale business segments. As at December 31, 2018, the debt to EBITDA leverage ratio was 2.3 on 
a trailing twelve-month basis. 

Distributable cash flow from combined operations of $283 million increased by $103 million, for the year ended December 
31,  2018  compared  to  $180  million,  for  the  year  ended  December  31,  2017.  Distributable  cash  flow  from  combined 
operations during the year ended December 31, 2018 resulted in a payout ratio of approximately 67%.  

Net income from continuing operations of $81 million increased by $147 million, for the year ended December 31, 2018 
compared to a net loss of $66 million, for the year ended December 31, 2017. 

In the fourth quarter of 2018 and 2017, the Company declared a dividend of $0.33 per common share, respectively. Total 
dividends declared for the years ended December 31, 2018 and 2017 were $190 million and $188 million, respectively or 
$1.32 per common share.  

Capital projects highlights 

o 

o 

o 
o 

During the year ended December 31, 2018, the Company incurred total growth capital expenditures, including acquisitions, 
of $302 million on construction of new tanks and related infrastructure at the Hardisty and Edmonton Terminals, the Viking 
Pipeline project (“Viking Pipeline”) and the extension of the Pyote gathering system.  

On January 3, 2018 the Company placed into service a total of 800,000 barrels of crude oil storage tank capacity and related 
pipeline connection infrastructure at the Edmonton Terminal which are underpinned by long-term take or pay contracts. 

On February 21, 2018, the Company announced the sanction of the $50 million Viking Pipeline.  

On August 8, 2018, the Company announced an additional $200 to $250 million of growth capital opportunities, consisting 
of the following: 

 

 

 

Sanction of 1.0 million barrels of new tankage at the Hardisty Terminal related to the second phase of development 
at the Top of the Hill portion of the Hardisty Terminal underpinned by long-term take or pay contracts; 

The acceleration of the U.S. strategy through investments made in and around its existing Pyote gathering system; 
and 

The expansion of the Moose Jaw Facility. 

o  On  October  15,  2018,  the  Company  announced  the  sanction  of  an  additional  1.0  million  barrels  of  new  tankage  at  the 

Hardisty Terminal, underpinned by a long-term contract with an investment grade, senior oil sands customer.  

Gibson Energy 

      Gibson Energy Inc.                                                            4                                              Management’s Discussion and Analysis  

Management’s Discussion and Analysis

5 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
o  On December 4, 2018, the Company announced the approval of the 2019 growth capital expenditure budget in the range of 

$200 million to $250 million with an additional $30 to $35 million allocated to replacement capital expenditures. 

o  On December 16, 2018, the Viking Pipeline went into service. 
Disposition of non-core businesses 

o 

o 

o 

o 
o 

o 

On January 30, 2018, the Company announced its new corporate strategy and plans for the sale of its non-core businesses, 
including Wholesale Propane, Canadian Truck Transportation, non-core Environmental Services North (“ESN”) and non-
core U.S. Injection Stations and Truck Transportation assets.  

On May 3, 2018, the Company completed the sale of its U.S. Environmental Services business for gross proceeds of $123 
million (US$96 million).  

On November 26, 2018, the Company announced the sale of its Wholesale Propane and ESN businesses for aggregate 
proceeds of approximately $100 million, prior to closing adjustments. 

On December 3, 2018, the Company completed the sale of its Wholesale Propane business. 

The  Company  continues  to  progress  on  the  divestiture  of  its  Canadian  Truck  Transportation  business  with  a  target  of 
concluding the divestiture process by mid-2019.  

Aggregate  proceeds  from  the  sale  of  non-core  businesses  have  been  and  are  expected  to  be  reinvested  into  the  core 
infrastructure business through funding future growth capital expenditures. 

Capital Structure 

o 

o 

On April 11, 2018 the Company extended the maturity date of its unsecured revolving credit facility (“Revolving Credit 
Facility”) from March 2022 to March 2023, and among other revisions, the maximum consolidated senior debt leverage 
ratio and the maximum consolidated total debt leverage ratio were revised to 4.85 to 1.0 until the end of the 2018 fiscal 
year, 4.50 to 1.0 for the 2019 fiscal year and 4.0 to 1.0 thereafter. 

On August 30, 2018 S&P Global ratings raised its long-term issuer credit and senior unsecured debt ratings on the Company 
to “BB+” from “BB”. 

Accounting standards 

o 

As disclosed in note 4 of the 2018 consolidated financial statements, the Company has adopted certain new accounting 
standards  as  at  January  1,  2018.  These  standards  have  been  applied  retrospectively  using  the  modified  retrospective 
approach, which does not require restatement of prior period financial information and applies the standard prospectively 
effective January 1, 2018. Accordingly, comparative information, including non-GAAP measures, included herein are not 
restated  for  the  impact  of  these  standards.  Where  the  impact  was  material,  the  amounts  have  been  quantified  for 
comparative  analysis  purposes  in  the  respective  sections  of  this  document.  Refer  to  “Accounting  Policies”  section  for 
further details. 

SUBSEQUENT EVENTS 

Disposition of non-core business 

On February 28, 2019, the Company completed the sale of its non-core ESN business. 

o 
Dividend 

o 

On  March  4,  2019,  the  Board  declared  a  quarterly  dividend  of  $0.33  per  common  share  for  the  first  quarter  on  its 
outstanding common shares. The dividend is payable on April 17, 2019 to shareholders of record at the close of business 
on March 29, 2019. 

PROJECT DEVELOPMENTS AND MARKET OUTLOOK 

Major growth projects 

The  Company  continues  to  progress  several  major  growth  projects  within  its  Infrastructure  segment,  including  advancing  the 

construction of 3.1 million barrels of tankage at Hardisty and completing the Viking Pipeline during the year. All major growth projects 

currently under construction are expected to be completed within or ahead of initial timelines. The following represents key activities 

with respect to major growth projects over 2018: 

o 

o 

o 

o 

o 

o 

On  January  3,  2018,  the  Company  placed  into  service  800,000  barrels  of  crude  oil  storage  tanks  and  related  pipeline 

connection infrastructure at the Edmonton Terminal; 

On February 21, 2018, the Company announced the sanction of the $50 million Viking Pipeline, which went into services 

on December 16, 2018; 

On August 8, 2018, the Company secured an additional $200 to $250 million of growth capital opportunities, consisting of 

the sanction of 1.0 million barrels of new tankage at the Hardisty Terminal, underpinned by long-term take or pay contracts 

and  expected  to  be  placed  in  service  in  the  fourth  quarter  of  2019,  the  acceleration  of  the  U.S.  strategy  through  the 

extension of the Pyote gathering system and the expansion of the Moose Jaw Facility; 

On October 15, 2018, the Company announced the sanction of 1.0 million barrels of new tankage at the Hardisty Terminal, 

underpinned by a long-term contract with an investment grade, senior oil sands customer. The construction of two new 

500,000 barrel tanks represents the third phase of development at the Top of the Hill portion of the Hardisty Terminal, and 

will leverage certain infrastructure built as part of the prior phases. The third phase is expected to be in service in the first 

quarter of 2020. In aggregate the three phases currently under construction will add seven new tanks, representing an 

incremental 3.1 million barrels of storage, an approximately 35% expansion of the Hardisty Terminal; 

The expansion of the Hardisty Unit Rail Facility, which is expected to be placed in service in the first quarter of 2019, while 

the expansion of the Moose Jaw Facility is expected to be placed into service during the second quarter of 2019; and 

Subsequent to the end of the quarter, the Company successfully placed the first phase of development at the Top of the 

Hill portion of the Hardisty Terminal into service ahead of schedule with capital costs in-line with budget.  With the three 

tanks from first phase at the Top of the Hill adding an incremental 1.1 million barrels of storage, Gibson’s Hardisty Terminal 

has reached an aggregate storage capacity of 10 million barrels.  

In addition to the sanctioned major growth projects currently under construction and discussed above, the Company continues to 

advance  numerous  commercial  development  opportunities  at  its  Hardisty  and  Edmonton  Terminals,  outside  its  Terminals  within 

Canada and around its Permian position in the U.S. The ability to reach long-term commercial agreements on these opportunities, 

and underpin the sanction of the construction of additional infrastructure for the Company’s existing and potential customers, would 

help increase the Infrastructure Segment’s revenues and segment profit in the future.  

Management’s Discussion and Analysis 

      Gibson Energy Inc.                                                            5                                              Management’s Discussion and Analysis  
Gibson Energy

6 

      Gibson Energy Inc.                                                            6                                              Management’s Discussion and Analysis  

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
o  On December 4, 2018, the Company announced the approval of the 2019 growth capital expenditure budget in the range of 

$200 million to $250 million with an additional $30 to $35 million allocated to replacement capital expenditures. 

PROJECT DEVELOPMENTS AND MARKET OUTLOOK 

Major growth projects 

The  Company  continues  to  progress  several  major  growth  projects  within  its  Infrastructure  segment,  including  advancing  the 
construction of 3.1 million barrels of tankage at Hardisty and completing the Viking Pipeline during the year. All major growth projects 
currently under construction are expected to be completed within or ahead of initial timelines. The following represents key activities 
with respect to major growth projects over 2018: 

o 

o 

o 

o 

o 

o 

On  January  3,  2018,  the  Company  placed  into  service  800,000  barrels  of  crude  oil  storage  tanks  and  related  pipeline 
connection infrastructure at the Edmonton Terminal; 

On February 21, 2018, the Company announced the sanction of the $50 million Viking Pipeline, which went into services 
on December 16, 2018; 

On August 8, 2018, the Company secured an additional $200 to $250 million of growth capital opportunities, consisting of 
the sanction of 1.0 million barrels of new tankage at the Hardisty Terminal, underpinned by long-term take or pay contracts 
and  expected  to  be  placed  in  service  in  the  fourth  quarter  of  2019,  the  acceleration  of  the  U.S.  strategy  through  the 
extension of the Pyote gathering system and the expansion of the Moose Jaw Facility; 

On October 15, 2018, the Company announced the sanction of 1.0 million barrels of new tankage at the Hardisty Terminal, 
underpinned by a long-term contract with an investment grade, senior oil sands customer. The construction of two new 
500,000 barrel tanks represents the third phase of development at the Top of the Hill portion of the Hardisty Terminal, and 
will leverage certain infrastructure built as part of the prior phases. The third phase is expected to be in service in the first 
quarter of 2020. In aggregate the three phases currently under construction will add seven new tanks, representing an 
incremental 3.1 million barrels of storage, an approximately 35% expansion of the Hardisty Terminal; 

The expansion of the Hardisty Unit Rail Facility, which is expected to be placed in service in the first quarter of 2019, while 
the expansion of the Moose Jaw Facility is expected to be placed into service during the second quarter of 2019; and 

Subsequent to the end of the quarter, the Company successfully placed the first phase of development at the Top of the 
Hill portion of the Hardisty Terminal into service ahead of schedule with capital costs in-line with budget.  With the three 
tanks from first phase at the Top of the Hill adding an incremental 1.1 million barrels of storage, Gibson’s Hardisty Terminal 
has reached an aggregate storage capacity of 10 million barrels.  

In addition to the sanctioned major growth projects currently under construction and discussed above, the Company continues to 
advance  numerous  commercial  development  opportunities  at  its  Hardisty  and  Edmonton  Terminals,  outside  its  Terminals  within 
Canada and around its Permian position in the U.S. The ability to reach long-term commercial agreements on these opportunities, 
and underpin the sanction of the construction of additional infrastructure for the Company’s existing and potential customers, would 
help increase the Infrastructure Segment’s revenues and segment profit in the future.  

o  On December 16, 2018, the Viking Pipeline went into service. 

Disposition of non-core businesses 

On January 30, 2018, the Company announced its new corporate strategy and plans for the sale of its non-core businesses, 

including Wholesale Propane, Canadian Truck Transportation, non-core Environmental Services North (“ESN”) and non-

core U.S. Injection Stations and Truck Transportation assets.  

On May 3, 2018, the Company completed the sale of its U.S. Environmental Services business for gross proceeds of $123 

million (US$96 million).  

On November 26, 2018, the Company announced the sale of its Wholesale Propane and ESN businesses for aggregate 

proceeds of approximately $100 million, prior to closing adjustments. 

On December 3, 2018, the Company completed the sale of its Wholesale Propane business. 

The  Company  continues  to  progress  on  the  divestiture  of  its  Canadian  Truck  Transportation  business  with  a  target  of 

concluding the divestiture process by mid-2019.  

Aggregate  proceeds  from  the  sale  of  non-core  businesses  have  been  and  are  expected  to  be  reinvested  into  the  core 

infrastructure business through funding future growth capital expenditures. 

On April 11, 2018 the Company extended the maturity date of its unsecured revolving credit facility (“Revolving Credit 

Facility”) from March 2022 to March 2023, and among other revisions, the maximum consolidated senior debt leverage 

ratio and the maximum consolidated total debt leverage ratio were revised to 4.85 to 1.0 until the end of the 2018 fiscal 

year, 4.50 to 1.0 for the 2019 fiscal year and 4.0 to 1.0 thereafter. 

On August 30, 2018 S&P Global ratings raised its long-term issuer credit and senior unsecured debt ratings on the Company 

Capital Structure 

to “BB+” from “BB”. 

Accounting standards 

As disclosed in note 4 of the 2018 consolidated financial statements, the Company has adopted certain new accounting 

standards  as  at  January  1,  2018.  These  standards  have  been  applied  retrospectively  using  the  modified  retrospective 

approach, which does not require restatement of prior period financial information and applies the standard prospectively 

effective January 1, 2018. Accordingly, comparative information, including non-GAAP measures, included herein are not 

restated  for  the  impact  of  these  standards.  Where  the  impact  was  material,  the  amounts  have  been  quantified  for 

comparative  analysis  purposes  in  the  respective  sections  of  this  document.  Refer  to  “Accounting  Policies”  section  for 

further details. 

SUBSEQUENT EVENTS 

Disposition of non-core business 

Dividend 

on March 29, 2019. 

On February 28, 2019, the Company completed the sale of its non-core ESN business. 

On  March  4,  2019,  the  Board  declared  a  quarterly  dividend  of  $0.33  per  common  share  for  the  first  quarter  on  its 

outstanding common shares. The dividend is payable on April 17, 2019 to shareholders of record at the close of business 

o 

o 

o 

o 

o 

o 

o 

o 

o 

o 

o 

      Gibson Energy Inc.                                                            5                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            6                                              Management’s Discussion and Analysis  

7 

Management’s Discussion and Analysis

Gibson Energy 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Market outlook  

Gibson regularly evaluates its long-range strategic plan in order to assess the implications of emerging industry trends. These industry 
trends have the ability to affect Gibson’s business and prospects over the short-term (generally less than two years) and the medium 
to long-term (generally two to five years). 

There are a number of factors that affect customers’ views of market access over the short and medium term, particularly in the 
Western  Canadian  Sedimentary  Basin  (the  “WCSB”).  These  views,  in  addition  to  commodity  prices,  impact  capital  expenditure 
programs and ultimately the growth in production that creates a meaningful portion of opportunities at the Hardisty and Edmonton 
terminals, as well as services that support those assets: 

o 

o 

In  the  short-term,  crude  oil  pricing,  location  and  quality  disconnects,  combined  with  the  existing  shortage  of  pipeline 
takeaway capacity from the WCSB, increase demand for terminal services as well as the use of crude by rail as a solution 
for market access. The Company believes that increased reliance on storage during periods of limited egress, especially 
during pipeline upsets or to facilitate crude by rail, may lead customers to consider increasing their available storage. Wider 
differentials improve margins at the Moose Jaw Facility, and, in conjunction with increased price fluctuations, typically 
provide increased opportunities within the Crude Wholesale business.  

There are currently three large pipeline projects at various stages of development and/or regulatory approval that have 
the potential to impact the Company over the short, medium and long-term. Over the long-term, the Company would 
expect  to  benefit  from  incremental  egress  from  Enbridge’s  Line  3  pipeline,  TC  Pipeline’s  Keystone  XL  project  and  the 
Government of Canada’s Trans Mountain Expansion, as it would encourage additional oil sands development. This increase 
in production in the WCSB would lead to further demand for tankage at the Company’s Hardisty and Edmonton Terminals, 
which are either connected or in close proximity to the respective starting points of these pipeline projects. There is a risk 
that these projects may be substantially delayed or cancelled. 

The recent stabilization in global oil price and improving cost efficiencies has resulted in improved project economics for many of 
Gibson’s producer customers. In addition, the Government of Alberta’s recently mandated oil production curtailments have improved 
Canadian oil price differentials relative to global benchmarks and increased pricing for crude oil in Western Canada. These factors 
have been supportive of the cash flows of Gibson’s producer customers and have helped improve their financial position, including 
the  ability  to  fund  growth  capital  programs.  Assuming  a  continued  supportive  global  macro  environment  for  oil  prices,  Gibson 
anticipates additional greenfield and brownfield project sanctions from its oil sands customers pending resolution of existing pipeline 
egress concerns. In the short term, the Company expects investment in heavy oil production in Alberta to be modest as long as the 
Government of Alberta’s mandated oil production curtailments are in place. 

Price  fluctuations  between  crude  oil  types  can  create  incremental  margin  opportunities  in  multiple  areas  of  the  Company’s 
operations. Crude price differentials remain volatile and the Company remains attentive to potential opportunities.  

RESULTS OF CONTINUING OPERATIONS  

The Company’s senior management evaluates segment performance based on a variety of measures depending on the particular 
segment being evaluated, including profit, volumes, operating expenses, profit per barrel and replacement capital requirements. The 
Company defines segment profit as revenues less cost of sales (excluding depreciation, amortization and impairment expense) and 
operating expenses. Revenues presented by segment in the table below include inter-segment revenue, as this is considered more 
indicative  of  the  level  of  each  segment’s  activity.  Profit  by  segments  excludes  depreciation,  amortization,  accretion,  impairment 
charges, stock based compensation and corporate expenses, as senior management looks at each period’s earnings before corporate 
expenses and non-cash items, as one of the Company’s important measures of segment performance. 

Management’s Discussion and Analysis 

      Gibson Energy Inc.                                                            7                                              Management’s Discussion and Analysis  
Gibson Energy

8 

The following is a discussion of the Company’s segmented results of operations for the three months and years ended December 31, 

2018 and 2017 and the following table sets forth revenue and profit by segment for those periods: 

Three months ended  

December 31 

Years ended  

December 31 

20181 

20171 

20181 

20171 

Segment revenue 

Infrastructure ....................................................................................  

  $ 

  $ 

391,627 

    $ 

Logistics .............................................................................................  

Wholesale .........................................................................................  

Total segment revenue .....................................................................  

95,531 

13,151 

1,366,269 

1,474,951 

  $ 

82,690 

16,609 

1,714,250 

1,813,549 

48,520 

7,142,713 

7,582,860 

Revenue – inter-segmental ...............................................................  

(160,346)   

(163,104)   

(736,271)   

Total revenue – external ...................................................................  

1,314,605 

1,650,445 

6,846,589 

Segment profit (loss) 

Infrastructure ....................................................................................  

Logistics .............................................................................................  

Wholesale .........................................................................................  

Total segment profit .........................................................................  

General and administrative ...............................................................  

Depreciation and impairment ...........................................................  

Right-of-use asset depreciation ........................................................  

Amortization and impairment ...........................................................  

Impairment of goodwill .....................................................................  

Stock based compensation ...............................................................  

Debt extinguishment costs................................................................  

Loss on net assets held for sale .........................................................  

Foreign exchange loss (gain) .............................................................  

Net interest expense .........................................................................  

Income (loss) before income tax .......................................................  

Income tax expense (recovery) .........................................................  

71,712 

383 

81,474 

153,569 

8,597 

25,265 

10,359 

3,146 

8,050 

- 

- 

4,974 

(1,732)   

17,669 

77,241 

29,966 

47,275 

55,737 

(3,008)   

18,658 

71,387 

22,975 

24,589 

2,898 

69,414 

8,492 

(2,630)   

- 

- 

2,534 

17,341 

(74,226)   

(18,375)   

283,489 

(7,513)   

211,111 

487,087 

32,155 

143,160 

43,184 

10,870 

20,479 

19,124 

- 

4,974 

2,314 

74,089 

136,738 

55,613 

336,901 

74,705 

5,817,252 

6,228,858 

(569,212) 

5,659,646 

235,276 

(4,103) 

30,585 

261,758 

50,016 

100,837 

23,340 

69,414 

23,244 

60,492 

- 

- 

(18,136) 

77,081 

(124,530) 

(58,204) 

(66,326) 

Net income (loss) from continuing operations .................................  

  $ 

  $ 

(55,851)   

  $ 

81,125 

    $ 

1. 

The current period results include the impacts from the adoption of new accounting standards as discussed on page 34. Comparative information has not been 

restated and, therefore, may not be comparable throughout the discussion on continuing operations. In addition, Comparative period segment information was 

represented to reflect the results of continuing operations separately from discontinued operations (see note 8 of the consolidated financial statements).  

The exclusion of depreciation, amortization and impairment expense could be viewed as limiting the usefulness of segment profit as 

a performance measure because it does not take into account, in current periods, the implied reduction in value of the Company’s 

capital assets (such as, tanks, pipelines, plant and equipment, rolling stock and disposal wells) caused by use, aging and wear and 

tear. Repair and maintenance expenditures that do not extend the useful life, improve the efficiency or expand the operating capacity 

of the Company’s capital assets are charged to operating expense as incurred. 

The Company’s segment analysis involves an element of judgment relating to the allocations between segments. Inter-segment sales, 

cost  of  sales  and  operating  expenses  are  eliminated  on  consolidation.  Transactions  between  segments  and  within  segments  are 

valued at prevailing market rates. The Company believes that the estimates with respect to these allocations and rates are reasonable. 

INFRASTRUCTURE 

The Infrastructure segment is comprised of a network of oil infrastructure assets that include oil terminals, rail loading and unloading 

facilities,  injection  stations,  gathering  pipelines,  a  crude  oil  processing  facility  and  procession,  recovery,  and  disposal  (“PRD”) 

terminals. The primary facilities within this segment include the terminals located at Hardisty and Edmonton, which are the principal 

hubs for aggregating and exporting oil and refined products out of the WCSB; gathering pipelines, which are connected to the Hardisty 

Terminal; an infrastructure position located in the U.S, a crude oil processing facility in Moose Jaw, Saskatchewan. The Moose Jaw 

Facility is impacted by maintenance turnarounds typically occurring within the spring period. PRD business is dependent upon the 

drilling activity in various areas of operations and as a result, the PRD business is impacted by seasonality due to road bans as part of 

spring break-up. 

      Gibson Energy Inc.                                                            8                                              Management’s Discussion and Analysis  

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Market outlook  

Gibson regularly evaluates its long-range strategic plan in order to assess the implications of emerging industry trends. These industry 

trends have the ability to affect Gibson’s business and prospects over the short-term (generally less than two years) and the medium 

to long-term (generally two to five years). 

There are a number of factors that affect customers’ views of market access over the short and medium term, particularly in the 

Western  Canadian  Sedimentary  Basin  (the  “WCSB”).  These  views,  in  addition  to  commodity  prices,  impact  capital  expenditure 

programs and ultimately the growth in production that creates a meaningful portion of opportunities at the Hardisty and Edmonton 

terminals, as well as services that support those assets: 

o 

o 

In  the  short-term,  crude  oil  pricing,  location  and  quality  disconnects,  combined  with  the  existing  shortage  of  pipeline 

takeaway capacity from the WCSB, increase demand for terminal services as well as the use of crude by rail as a solution 

for market access. The Company believes that increased reliance on storage during periods of limited egress, especially 

during pipeline upsets or to facilitate crude by rail, may lead customers to consider increasing their available storage. Wider 

differentials improve margins at the Moose Jaw Facility, and, in conjunction with increased price fluctuations, typically 

provide increased opportunities within the Crude Wholesale business.  

There are currently three large pipeline projects at various stages of development and/or regulatory approval that have 

the potential to impact the Company over the short, medium and long-term. Over the long-term, the Company would 

expect  to  benefit  from  incremental  egress  from  Enbridge’s  Line  3  pipeline,  TC  Pipeline’s  Keystone  XL  project  and  the 

Government of Canada’s Trans Mountain Expansion, as it would encourage additional oil sands development. This increase 

in production in the WCSB would lead to further demand for tankage at the Company’s Hardisty and Edmonton Terminals, 

which are either connected or in close proximity to the respective starting points of these pipeline projects. There is a risk 

that these projects may be substantially delayed or cancelled. 

The recent stabilization in global oil price and improving cost efficiencies has resulted in improved project economics for many of 

Gibson’s producer customers. In addition, the Government of Alberta’s recently mandated oil production curtailments have improved 

Canadian oil price differentials relative to global benchmarks and increased pricing for crude oil in Western Canada. These factors 

have been supportive of the cash flows of Gibson’s producer customers and have helped improve their financial position, including 

the  ability  to  fund  growth  capital  programs.  Assuming  a  continued  supportive  global  macro  environment  for  oil  prices,  Gibson 

anticipates additional greenfield and brownfield project sanctions from its oil sands customers pending resolution of existing pipeline 

egress concerns. In the short term, the Company expects investment in heavy oil production in Alberta to be modest as long as the 

Government of Alberta’s mandated oil production curtailments are in place. 

Price  fluctuations  between  crude  oil  types  can  create  incremental  margin  opportunities  in  multiple  areas  of  the  Company’s 

operations. Crude price differentials remain volatile and the Company remains attentive to potential opportunities.  

RESULTS OF CONTINUING OPERATIONS  

The Company’s senior management evaluates segment performance based on a variety of measures depending on the particular 

segment being evaluated, including profit, volumes, operating expenses, profit per barrel and replacement capital requirements. The 

Company defines segment profit as revenues less cost of sales (excluding depreciation, amortization and impairment expense) and 

operating expenses. Revenues presented by segment in the table below include inter-segment revenue, as this is considered more 

indicative  of  the  level  of  each  segment’s  activity.  Profit  by  segments  excludes  depreciation,  amortization,  accretion,  impairment 

charges, stock based compensation and corporate expenses, as senior management looks at each period’s earnings before corporate 

expenses and non-cash items, as one of the Company’s important measures of segment performance. 

      Gibson Energy Inc.                                                            7                                              Management’s Discussion and Analysis  

The following is a discussion of the Company’s segmented results of operations for the three months and years ended December 31, 
2018 and 2017 and the following table sets forth revenue and profit by segment for those periods: 

Three months ended  
December 31 

Years ended  
December 31 

20181 

20171 

20181 

20171 

Segment revenue 
Infrastructure ....................................................................................  
Logistics .............................................................................................  
Wholesale .........................................................................................  
Total segment revenue .....................................................................  
Revenue – inter-segmental ...............................................................  
Total revenue – external ...................................................................  
Segment profit (loss) 
Infrastructure ....................................................................................  
Logistics .............................................................................................  
Wholesale .........................................................................................  
Total segment profit .........................................................................  
General and administrative ...............................................................  
Depreciation and impairment ...........................................................  
Right-of-use asset depreciation ........................................................  
Amortization and impairment ...........................................................  
Impairment of goodwill .....................................................................  
Stock based compensation ...............................................................  
Debt extinguishment costs................................................................  
Loss on net assets held for sale .........................................................  
Foreign exchange loss (gain) .............................................................  
Net interest expense .........................................................................  
Income (loss) before income tax .......................................................  
Income tax expense (recovery) .........................................................  
Net income (loss) from continuing operations .................................  

  $ 

95,531 
13,151 
1,366,269 
1,474,951 
(160,346)   
1,314,605 

  $ 

82,690 
16,609 
1,714,250 
1,813,549 
(163,104)   
1,650,445 

  $ 

    $ 

391,627 
48,520 
7,142,713 
7,582,860 
(736,271)   
6,846,589 

336,901 
74,705 
5,817,252 
6,228,858 
(569,212) 
5,659,646 

71,712 
383 
81,474 
153,569 
8,597 
25,265 
10,359 
3,146 
- 
8,050 
- 
4,974 
(1,732)   
17,669 
77,241 
29,966 
47,275 

  $ 

55,737 
(3,008)   
18,658 
71,387 
22,975 
24,589 
- 
2,898 
69,414 
8,492 
(2,630)   

- 
2,534 
17,341 
(74,226)   
(18,375)   
(55,851)   

  $ 

  $ 

283,489 

(7,513)   

211,111 
487,087 
32,155 
143,160 
43,184 
10,870 
20,479 
19,124 
- 
4,974 
2,314 
74,089 
136,738 
55,613 
81,125 

    $ 

235,276 
(4,103) 
30,585 
261,758 
50,016 
100,837 
- 
23,340 
69,414 
23,244 
60,492 
- 
(18,136) 
77,081 
(124,530) 
(58,204) 
(66,326) 

1. 

The current period results include the impacts from the adoption of new accounting standards as discussed on page 34. Comparative information has not been 
restated and, therefore, may not be comparable throughout the discussion on continuing operations. In addition, Comparative period segment information was 
represented to reflect the results of continuing operations separately from discontinued operations (see note 8 of the consolidated financial statements).  

The exclusion of depreciation, amortization and impairment expense could be viewed as limiting the usefulness of segment profit as 
a performance measure because it does not take into account, in current periods, the implied reduction in value of the Company’s 
capital assets (such as, tanks, pipelines, plant and equipment, rolling stock and disposal wells) caused by use, aging and wear and 
tear. Repair and maintenance expenditures that do not extend the useful life, improve the efficiency or expand the operating capacity 
of the Company’s capital assets are charged to operating expense as incurred. 

The Company’s segment analysis involves an element of judgment relating to the allocations between segments. Inter-segment sales, 
cost  of  sales  and  operating  expenses  are  eliminated  on  consolidation.  Transactions  between  segments  and  within  segments  are 
valued at prevailing market rates. The Company believes that the estimates with respect to these allocations and rates are reasonable. 

INFRASTRUCTURE 

The Infrastructure segment is comprised of a network of oil infrastructure assets that include oil terminals, rail loading and unloading 
facilities,  injection  stations,  gathering  pipelines,  a  crude  oil  processing  facility  and  procession,  recovery,  and  disposal  (“PRD”) 
terminals. The primary facilities within this segment include the terminals located at Hardisty and Edmonton, which are the principal 
hubs for aggregating and exporting oil and refined products out of the WCSB; gathering pipelines, which are connected to the Hardisty 
Terminal; an infrastructure position located in the U.S, a crude oil processing facility in Moose Jaw, Saskatchewan. The Moose Jaw 
Facility is impacted by maintenance turnarounds typically occurring within the spring period. PRD business is dependent upon the 
drilling activity in various areas of operations and as a result, the PRD business is impacted by seasonality due to road bans as part of 
spring break-up. 

Gibson Energy 

      Gibson Energy Inc.                                                            8                                              Management’s Discussion and Analysis  

Management’s Discussion and Analysis

9 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
The following tables set forth the operating results from the Company’s Infrastructure segment for the three months and years ended 
December 31, 2018 and 2017: 

Financial performance 

Three months ended  
December 31 

Volumes (barrels in thousands) 
Terminals and facilities 

Hardisty Terminal ....................................................................  
Edmonton Terminal ................................................................  
Moose Jaw Facility ..................................................................  
PRD Terminals .........................................................................  
Injection Stations ....................................................................  
Total terminals and facilities ...................................................  

20181 

80,084 
11,761 
1,551 
5,144 
2,553 
101,093 

20171 

70,424 
5,358 
1,483 
3,453 
2,259 
82,977 

Years ended  
December 31 

20181 

20171 

310,909 
35,420 
5,741 
16,282 
8,970 
377,322 

259,953 
20,835 
5,524 
13,301 
17,238 
316,851 

Three months ended  
December 31 

Years ended  
December 31 

20181 

20171 

20181 

20171 

Revenue 
    Hardisty Terminal ....................................................................  
    Edmonton Terminal .................................................................  
    Moose Jaw Facility ...................................................................  
    PRD Terminals .........................................................................  
    Injection Stations .....................................................................  
Revenue ......................................................................................  
Operating expenses and other ....................................................  
Segment profit ............................................................................  

$  53,804 
              18,954 
9,845 
11,737 
1,191 
95,531 
23,819 
$  71,712 

$  47,693 
12,944 
9,844 
11,679 
530 
82,690 
26,953 
$  55,737 

$  217,253 
              84,052 
39,379 
46,421 
4,522 
391,627 
108,138 
$  283,489 

$  198,926 
52,119 
39,391 
43,114 
3,351 
  336,901 
101,625 
$  235,276 

1. 

The current period results include the impacts from the adoption of new accounting standards as discussed on pages 34. Comparative information has not been 
restated and, therefore, may not be comparable throughout the discussion on continuing operations. In addition, Comparative period segment information was 
represented to reflect the results of continuing operations separately from discontinued operations (see note 8 of the consolidated financial statements). 

Operational performance 

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

Hardisty Terminal volumes increased 14% and 20%, respectively. The increase in both comparative periods was largely driven by the 
addition  of  infrastructure  connections  which  provided  for  higher  throughput  volumes  primarily  from  certain  customers  with 
additional  volumes  from  an  oil  sands  project  with  dedicated  tankage  underpinned  by  long-term  take  or  pay  contracts,  higher 
customer’s contract tankage volumes, increased traffic from the Hardisty Unit Rail Facility (“HURC”) and higher trucked volumes. 

Edmonton Terminal volumes increased by 120% and 70%, respectively. The increase in both comparative periods was mainly due to 
the commissioning of two new tanks and common infrastructure at the Edmonton Terminal in January of 2018. 

Terminal and the Viking Pipeline in the current period. 

Moose Jaw Facility volumes increased by 5% and 4%, respectively. The increase was primarily due to a higher throughput efficiency 
to support higher refined product volumes and a shorter turnaround period in the current year. 

PRD Terminal volumes increased by 49% and 22%, respectively. The increase was mainly due to higher facility activity levels in the 
Company’s WCSB service areas, particularly in the Alberta Montney. 

Injection  Station  volumes  increased  by  13%  and  decreased  by  48%,  respectively.  The  quarter  over  quarter  increase  was  due  to 
additional activity created by favorable locational pricing differential opportunities in the Permian basin. The decrease in the year 
ended comparative period was due to the termination of the exclusive injection station access contract with a major customer in 
November 2017. 

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

Revenue at the Hardisty Terminal increased by $6.1 million and $18.3 million, respectively, which was largely driven by the increase 

in volumes as discussed above. 

Revenue at the Edmonton Terminal increased by $6.0 million and $31.9 million, respectively. The increase was primarily due to the 

commissioning of the two new tanks and related common infrastructure in Q1 2018 which are supported by take-or-pay, stable fee-

based  arrangements  and  the  receipt  of  additional  revenue  related  to  a  contractual  amendment  regarding  a  future  capital 

commitment. Additionally, the increase in revenue was supported by the commissioning of the Heartland sulfur facility in the current 

PRD Terminal revenues were consistent and increased by $3.3 million, respectively. The increase was mainly due to higher facility 

activity levels in the Company’s WCSB service areas, particularly in the Alberta Montney, as well as higher revenues from recovered 

period.  

oil. 

There was no material change in the revenue for the Moose Jaw Facility in both periods. 

Injection Station revenues increased by $0.7 million and $1.2 million, respectively. These increases were mainly due to locational 

pricing differential opportunities and new rental service arrangements. 

Segment profit increased by $16.0 million and $48.2 million, respectively. As described above, the increase was primarily due to the 

increased  revenues  from  the  Hardisty  and  Edmonton  Terminals.  The  quarter  over  quarter  increase  was  also  supported  by  lower 

operating costs due to the focus on cost reduction and recovery initiatives. The year ended comparative period increase was also 

impacted by higher salaries and benefit costs relating to the addition of rail loading operators, and higher environmental remediation 

costs. 

Capital expenditures 

Below is the summary of Infrastructure capital expenditures for the years ended December 31, 2018 and 2017: 

Growth capital .............................................................................................................................  

219,213 

  $  146,739 

Replacement capital ....................................................................................................................  

Acquisitions ..................................................................................................................................  

17,547 

80,844 

  $ 

  $ 

17,436 

- 

  $ 

  $ 

  $ 

Years ended December 31 

2018 

2017 

The increase in growth capital expenditures for the year ended December 31, 2018 compared to the year ended December 31, 2017 

primarily relate to an increase in project development activities specific to additional tanks and related infrastructure at the Hardisty 

Replacement capital includes purchases that replace existing assets as necessary to maintain current service levels or replace assets 

that no longer have a useful economic life and was consistent year over year.  

Acquisitions include an agreement to acquire, develop and operate a pipeline gathering network adjacent to the existing Pyote system 

in the U.S, of which the purchase price is payable in two installments, with U.S.$25 million paid on August 8, 2018 and U.S.$30 million 

payable by August 8, 2019. In addition, Acquisitions also include the Company’s purchase of the remaining interests in the Plato 

Pipeline.  

      Gibson Energy Inc.                                                            10                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            9                                              Management’s Discussion and Analysis  
Gibson Energy

10 

Management’s Discussion and Analysis 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
The following tables set forth the operating results from the Company’s Infrastructure segment for the three months and years ended 

Financial performance 

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

Revenue at the Hardisty Terminal increased by $6.1 million and $18.3 million, respectively, which was largely driven by the increase 
in volumes as discussed above. 

Revenue at the Edmonton Terminal increased by $6.0 million and $31.9 million, respectively. The increase was primarily due to the 
commissioning of the two new tanks and related common infrastructure in Q1 2018 which are supported by take-or-pay, stable fee-
based  arrangements  and  the  receipt  of  additional  revenue  related  to  a  contractual  amendment  regarding  a  future  capital 
commitment. Additionally, the increase in revenue was supported by the commissioning of the Heartland sulfur facility in the current 
period.  

PRD Terminal revenues were consistent and increased by $3.3 million, respectively. The increase was mainly due to higher facility 
activity levels in the Company’s WCSB service areas, particularly in the Alberta Montney, as well as higher revenues from recovered 
oil. 

There was no material change in the revenue for the Moose Jaw Facility in both periods. 

Injection Station revenues increased by $0.7 million and $1.2 million, respectively. These increases were mainly due to locational 
pricing differential opportunities and new rental service arrangements. 

Segment profit increased by $16.0 million and $48.2 million, respectively. As described above, the increase was primarily due to the 
increased  revenues  from  the  Hardisty  and  Edmonton  Terminals.  The  quarter  over  quarter  increase  was  also  supported  by  lower 
operating costs due to the focus on cost reduction and recovery initiatives. The year ended comparative period increase was also 
impacted by higher salaries and benefit costs relating to the addition of rail loading operators, and higher environmental remediation 
costs. 

Capital expenditures 

Below is the summary of Infrastructure capital expenditures for the years ended December 31, 2018 and 2017: 

Growth capital .............................................................................................................................  
Replacement capital ....................................................................................................................  
Acquisitions ..................................................................................................................................  

  $ 
  $ 
  $ 

Years ended December 31 

2018 
219,213 
17,547 
80,844 

2017 
  $  146,739 
17,436 
  $ 
- 
  $ 

The increase in growth capital expenditures for the year ended December 31, 2018 compared to the year ended December 31, 2017 
primarily relate to an increase in project development activities specific to additional tanks and related infrastructure at the Hardisty 
Terminal and the Viking Pipeline in the current period. 

Replacement capital includes purchases that replace existing assets as necessary to maintain current service levels or replace assets 
that no longer have a useful economic life and was consistent year over year.  

Acquisitions include an agreement to acquire, develop and operate a pipeline gathering network adjacent to the existing Pyote system 
in the U.S, of which the purchase price is payable in two installments, with U.S.$25 million paid on August 8, 2018 and U.S.$30 million 
payable by August 8, 2019. In addition, Acquisitions also include the Company’s purchase of the remaining interests in the Plato 
Pipeline.  

December 31, 2018 and 2017: 

Three months ended  

December 31 

Volumes (barrels in thousands) 

Terminals and facilities 

Hardisty Terminal ....................................................................  

Edmonton Terminal ................................................................  

Moose Jaw Facility ..................................................................  

PRD Terminals .........................................................................  

Injection Stations ....................................................................  

Total terminals and facilities ...................................................  

20181 

80,084 

11,761 

1,551 

5,144 

2,553 

101,093 

Three months ended  

December 31 

Years ended  

December 31 

20181 

20171 

20181 

20171 

20171 

70,424 

5,358 

1,483 

3,453 

2,259 

82,977 

12,944 

9,844 

11,679 

530 

82,690 

26,953 

Years ended  

December 31 

20181 

20171 

310,909 

35,420 

5,741 

16,282 

8,970 

377,322 

259,953 

20,835 

5,524 

13,301 

17,238 

316,851 

39,379 

46,421 

4,522 

391,627 

108,138 

$  198,926 

52,119 

39,391 

43,114 

3,351 

  336,901 

101,625 

$  235,276 

Revenue 

    Hardisty Terminal ....................................................................  

$  53,804 

$  47,693 

    Edmonton Terminal .................................................................  

              18,954 

$  217,253 

              84,052 

    Moose Jaw Facility ...................................................................  

    PRD Terminals .........................................................................  

    Injection Stations .....................................................................  

Revenue ......................................................................................  

Operating expenses and other ....................................................  

9,845 

11,737 

1,191 

95,531 

23,819 

Segment profit ............................................................................  

$  71,712 

$  55,737 

$  283,489 

1. 

The current period results include the impacts from the adoption of new accounting standards as discussed on pages 34. Comparative information has not been 

restated and, therefore, may not be comparable throughout the discussion on continuing operations. In addition, Comparative period segment information was 

represented to reflect the results of continuing operations separately from discontinued operations (see note 8 of the consolidated financial statements). 

Operational performance 

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

Hardisty Terminal volumes increased 14% and 20%, respectively. The increase in both comparative periods was largely driven by the 

addition  of  infrastructure  connections  which  provided  for  higher  throughput  volumes  primarily  from  certain  customers  with 

additional  volumes  from  an  oil  sands  project  with  dedicated  tankage  underpinned  by  long-term  take  or  pay  contracts,  higher 

customer’s contract tankage volumes, increased traffic from the Hardisty Unit Rail Facility (“HURC”) and higher trucked volumes. 

Edmonton Terminal volumes increased by 120% and 70%, respectively. The increase in both comparative periods was mainly due to 

the commissioning of two new tanks and common infrastructure at the Edmonton Terminal in January of 2018. 

Moose Jaw Facility volumes increased by 5% and 4%, respectively. The increase was primarily due to a higher throughput efficiency 

to support higher refined product volumes and a shorter turnaround period in the current year. 

PRD Terminal volumes increased by 49% and 22%, respectively. The increase was mainly due to higher facility activity levels in the 

Company’s WCSB service areas, particularly in the Alberta Montney. 

Injection  Station  volumes  increased  by  13%  and  decreased  by  48%,  respectively.  The  quarter  over  quarter  increase  was  due  to 

additional activity created by favorable locational pricing differential opportunities in the Permian basin. The decrease in the year 

ended comparative period was due to the termination of the exclusive injection station access contract with a major customer in 

November 2017. 

      Gibson Energy Inc.                                                            9                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            10                                              Management’s Discussion and Analysis  

11 

Management’s Discussion and Analysis

Gibson Energy 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
LOGISTICS 

WHOLESALE 

The  Logistics  segment  represents  the  Company’s  U.S  Truck  Transportation  business  due  to  the  Canadian  Truck  Transportation 
business being classified as a discontinued operation during 2018. This segment provides truck transportation services in the Permian 
and SCOOP/STACK basins in the U.S. that enable oil production to access fixed midstream infrastructure. 

The  following  tables  set  forth  operating  results  from  the  Company’s  Logistics  segment  for  the  three  months  and  years  ended 
December 31, 2018 and 2017: 

Volumes (barrels in thousands) 
Crude and other products ...........................................................  

Three months ended  
December 31 

20181 
2,778 

20171 
6,431 

Years ended  
December 31 

20181 
16,074 

20171 
26,848 

Three months ended  
December 31 

Years ended 
 December 31 

20181 

20171 

20181 

20171 

over period. 

Revenue ......................................................................................  
Cost of sales ................................................................................  
Operating expenses and other ....................................................  
Segment profit (loss) ...................................................................  

$      13,151    

8,698 
4,070 
383 

$  

$      16,609 
12,480 
7,137 
(3,008)   

$ 

$     48,520 
33,155 
22,878 
(7,513) 

$ 

$      74,705   
53,896 
24,912 
(4,103) 

$ 

1. 

The current period results include the impacts from the adoption of new accounting standards as discussed on pages 34. Comparative information has not been 
restated and, therefore, may not be comparable throughout the discussion on continuing operations. In addition, Comparative period segment information was 
represented to reflect the results of continuing operations separately from discontinued operations (see note 8 of the consolidated financial statements). 

Operational performance 

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

Crude and other product hauling barrels decreased by 57% and 40%, respectively. The decrease was primarily attributable to the 
limited availability of drivers as a result of significant competition for drivers and the decline in business with Logistics’ largest U.S. 
trucking customer triggered by the termination of the exclusive injection station access contract in November 2017. Trucking volumes 
with other customers are increasing due to the acceleration of the Company’s U.S. strategy in the Permian, however are not yet 
sufficient to overcome the overall effect of the decline with the former largest customer.  

Financial performance 

In the three months and year ended December 31, 2018 compared to the three month and year ended December 31, 2017: 

Crude and other revenue decreased by 21% and 35%, respectively. The decrease was primarily driven by lower volumes as discussed 
above. 

Segment profit increased by $3.4 million and decreased by $3.4 million, respectively. The quarter over quarter increase was mainly 
due to the reduction in overhead costs to align with the current fleet size and reduced repair and maintenance costs. The year over 
year decrease was mainly due to the decline in the U.S. crude hauling profit as a result of one-time expenses such as severance, 
relocation, and office move costs and the loss in volumes as discussed above, partially offset by lower operating expenses in the latter 
half of 2018.  

Management’s Discussion and Analysis 

      Gibson Energy Inc.                                                            11                                              Management’s Discussion and Analysis  
Gibson Energy

12 

The Wholesale segment involves the purchasing, selling, storing and optimizing of hydrocarbon products as part of supplying the 

Moose Jaw Facility and marketing its refined products as well as helping to drive volumes through the Company’s key infrastructure 

assets. The hydrocarbon products would include crude oil, NGLs, road asphalt, roofing flux, frac oils, light and heavy straight run 

distillates, CVGO and an oil-based mud product. The Wholesale segment’s opportunities are typically location, quality or time-based. 

The  Wholesale  segment  sources  the  majority  of  its  hydrocarbon  products  from  Western  Canada  and  markets  those  products 

throughout Canada and the U.S. 

The Wholesale segment is exposed to commodity price fluctuations arising between the time contracted volumes are purchased and 

the time they are sold, as well as being exposed to pricing differentials between different geographic markets and/or hydrocarbon 

qualities. These risks are managed by purchasing and selling products at prices based on the same or similar indices or benchmarks, 

and through physical and financial contracts that include energy-related forward contracts, swaps, futures, options and other hedging 

instruments. Fair values of these derivative contracts fluctuate depending on the commodity prices and can impact the segment 

profits in the form of realized or unrealized gains and losses, often offset by physical inventories, that can change significantly period 

Canadian road asphalt activity, related to refined products, is affected by the impact of weather conditions on road construction. 

Road asphalt demand peaks during the summer months when most of the road construction activity in Canada takes place. In the 

off-peak demand months for road asphalt, the demand for roofing flux continues. Demand for wellsite fluids is dependent on overall 

well drilling and completion activities, with activity normally the busiest in the winter months. Demand for propane and other NGLs 

is also highest in the colder months of the year. 

Western Taxes Intermediate (“WTI”) average price ($USD/bbl) ......  

Western Canadian Select (“WCS”) average differential ($USD/bbl) .  

Average foreign exchange rates ($CAD/$USD) .................................  

Propane average price ($USD/U.S. gallon)  .......................................  

Butane average price ($USD/U.S. gallon) ..........................................  

Three months ended 

 December 31 

Years ended  

December 31 

2018 

$58.81   

39.43   

1.32   

0.66   

0.75   

2017 

$55.40   

12.26   

1.27   

0.95   

1.05   

2018 

$64.777 

26.311 

1.300 

0.777 

0.933 

2017 

$50.95

11.98

1.30

0.73

0.91

The following tables set forth operating results from the Company’s Wholesale segment for the three months and years ended 

December 31, 2018 and 2017: 

Volumes (barrels in thousands) 

Crude and diluent ..........................................................................  

Propane and other NGL .................................................................  

Refined products ............................................................................  

Total ...............................................................................................  

Revenue 

     Propane and other NGL .............................................................  

     Refined products .......................................................................  

Total revenue .................................................................................  

Cost of sales ...................................................................................  

Operating expenses and other .......................................................  

Three months ended 

 December 31 

Years ended 

 December 31 

20181 

32,155 

2,855 

1,132 

36,142 

20171 

29,936 

3,524 

1,031 

34,491 

20181 

124,440 

9,985 

4,427 

138,852 

20171 

114,466 

11,154 

4,000 

129,620 

Three months ended  

December 31 

Years ended  

December 31 

20181 

20171 

20181 

20171 

138,293 

112,700 

1,366,269 

1,274,250 

10,545 

81,474 

195,913 

95,741 

1,714,250 

1,689,472 

6,120 

18,658 

530,155 

451,045 

7,142,713 

6,901,885 

29,717 

551,854 

358,387 

5,817,252 

5,761,215 

25,452 

30,585 

     Crude and diluent ......................................................................  

  $  1,115,276 

  $  1,422,596 

  $  6,161,513 

  $  4,907,011 

Segment profit (loss) ......................................................................  

  $ 

  $ 

  $ 

211,111 

  $ 

1. 

The current period results include the impacts from the adoption of new accounting standards as discussed on page 34. Comparative information has not been 

restated and, therefore, may not be comparable throughout the discussion on continuing operations. 

      Gibson Energy Inc.                                                            12                                              Management’s Discussion and Analysis  

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
LOGISTICS 

WHOLESALE 

The Wholesale segment involves the purchasing, selling, storing and optimizing of hydrocarbon products as part of supplying the 
Moose Jaw Facility and marketing its refined products as well as helping to drive volumes through the Company’s key infrastructure 
assets. The hydrocarbon products would include crude oil, NGLs, road asphalt, roofing flux, frac oils, light and heavy straight run 
distillates, CVGO and an oil-based mud product. The Wholesale segment’s opportunities are typically location, quality or time-based. 
The  Wholesale  segment  sources  the  majority  of  its  hydrocarbon  products  from  Western  Canada  and  markets  those  products 
throughout Canada and the U.S. 

The Wholesale segment is exposed to commodity price fluctuations arising between the time contracted volumes are purchased and 
the time they are sold, as well as being exposed to pricing differentials between different geographic markets and/or hydrocarbon 
qualities. These risks are managed by purchasing and selling products at prices based on the same or similar indices or benchmarks, 
and through physical and financial contracts that include energy-related forward contracts, swaps, futures, options and other hedging 
instruments. Fair values of these derivative contracts fluctuate depending on the commodity prices and can impact the segment 
profits in the form of realized or unrealized gains and losses, often offset by physical inventories, that can change significantly period 
over period. 

Canadian road asphalt activity, related to refined products, is affected by the impact of weather conditions on road construction. 
Road asphalt demand peaks during the summer months when most of the road construction activity in Canada takes place. In the 
off-peak demand months for road asphalt, the demand for roofing flux continues. Demand for wellsite fluids is dependent on overall 
well drilling and completion activities, with activity normally the busiest in the winter months. Demand for propane and other NGLs 
is also highest in the colder months of the year. 

Western Taxes Intermediate (“WTI”) average price ($USD/bbl) ......  
Western Canadian Select (“WCS”) average differential ($USD/bbl) .  
Average foreign exchange rates ($CAD/$USD) .................................  
Propane average price ($USD/U.S. gallon)  .......................................  
Butane average price ($USD/U.S. gallon) ..........................................  

Three months ended 
 December 31 
2018 
$58.81   
39.43   
1.32   
0.66   
0.75   

2017 
$55.40   
12.26   
1.27   
0.95   
1.05   

Years ended  
December 31 

2018 
$64.777 
26.311 
1.300 
0.777 
0.933 

2017 
$50.95
11.98
1.30
0.73
0.91

The following tables set forth operating results from the Company’s Wholesale segment for the three months and years ended 
December 31, 2018 and 2017: 

Volumes (barrels in thousands) 
Crude and diluent ..........................................................................  
Propane and other NGL .................................................................  
Refined products ............................................................................  
Total ...............................................................................................  

Three months ended 
 December 31 

Years ended 
 December 31 

20181 
32,155 
2,855 
1,132 
36,142 

20171 
29,936 
3,524 
1,031 
34,491 

20181 
124,440 
9,985 
4,427 
138,852 

20171 
114,466 
11,154 
4,000 
129,620 

Three months ended  
December 31 
20181 

Years ended  
December 31 

20171 

20181 

20171 

Revenue 
     Crude and diluent ......................................................................  
     Propane and other NGL .............................................................  
     Refined products .......................................................................  
Total revenue .................................................................................  
Cost of sales ...................................................................................  
Operating expenses and other .......................................................  
Segment profit (loss) ......................................................................  

  $  1,115,276 
138,293 
112,700 
1,366,269 
1,274,250 
10,545 
81,474 

  $ 

  $  1,422,596 
195,913 
95,741 
1,714,250 
1,689,472 
6,120 
18,658 

  $ 

  $  6,161,513 
530,155 
451,045 
7,142,713 
6,901,885 
29,717 
211,111 

  $ 

  $  4,907,011 
551,854 
358,387 
5,817,252 
5,761,215 
25,452 
30,585 

  $ 

1. 

The current period results include the impacts from the adoption of new accounting standards as discussed on page 34. Comparative information has not been 
restated and, therefore, may not be comparable throughout the discussion on continuing operations. 

The  Logistics  segment  represents  the  Company’s  U.S  Truck  Transportation  business  due  to  the  Canadian  Truck  Transportation 

business being classified as a discontinued operation during 2018. This segment provides truck transportation services in the Permian 

and SCOOP/STACK basins in the U.S. that enable oil production to access fixed midstream infrastructure. 

The  following  tables  set  forth  operating  results  from  the  Company’s  Logistics  segment  for  the  three  months  and  years  ended 

December 31, 2018 and 2017: 

Volumes (barrels in thousands) 

Crude and other products ...........................................................  

Three months ended  

December 31 

20181 

2,778 

20171 

6,431 

Years ended  

December 31 

20181 

16,074 

20171 

26,848 

Three months ended  

December 31 

Years ended 

 December 31 

20181 

20171 

20181 

20171 

Revenue ......................................................................................  

$      13,151    

$      16,609 

$     48,520 

$      74,705   

Cost of sales ................................................................................  

Operating expenses and other ....................................................  

12,480 

7,137 

33,155 

22,878 

53,896 

24,912 

Segment profit (loss) ...................................................................  

$  

$ 

(3,008)   

$ 

(7,513) 

$ 

(4,103) 

8,698 

4,070 

383 

1. 

The current period results include the impacts from the adoption of new accounting standards as discussed on pages 34. Comparative information has not been 

restated and, therefore, may not be comparable throughout the discussion on continuing operations. In addition, Comparative period segment information was 

represented to reflect the results of continuing operations separately from discontinued operations (see note 8 of the consolidated financial statements). 

Operational performance 

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

Crude and other product hauling barrels decreased by 57% and 40%, respectively. The decrease was primarily attributable to the 

limited availability of drivers as a result of significant competition for drivers and the decline in business with Logistics’ largest U.S. 

trucking customer triggered by the termination of the exclusive injection station access contract in November 2017. Trucking volumes 

with other customers are increasing due to the acceleration of the Company’s U.S. strategy in the Permian, however are not yet 

sufficient to overcome the overall effect of the decline with the former largest customer.  

Financial performance 

above. 

half of 2018.  

In the three months and year ended December 31, 2018 compared to the three month and year ended December 31, 2017: 

Crude and other revenue decreased by 21% and 35%, respectively. The decrease was primarily driven by lower volumes as discussed 

Segment profit increased by $3.4 million and decreased by $3.4 million, respectively. The quarter over quarter increase was mainly 

due to the reduction in overhead costs to align with the current fleet size and reduced repair and maintenance costs. The year over 

year decrease was mainly due to the decline in the U.S. crude hauling profit as a result of one-time expenses such as severance, 

relocation, and office move costs and the loss in volumes as discussed above, partially offset by lower operating expenses in the latter 

      Gibson Energy Inc.                                                            11                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            12                                              Management’s Discussion and Analysis  

13 

Management’s Discussion and Analysis

Gibson Energy 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Operational performance 

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

Sales  volumes  for  refined  products  increased  by  10%  and  11%,  respectively.  The  increase  was  primarily  due  to  higher  available 
volumes from the Moose Jaw Facility driven by higher efficiencies which supported increased sales volumes for drilling fluids and 
roofing flux. Sales volumes for drilling fluids have increased principally as a result of increased U.S. drilling activity, and the ability of 
the Company to gain market share in the Permian and Niobrara-Denver Julesburg basins, while the increase in sales volumes for 
roofing flux is supported by the Company’s ability to gain market share within the roofing flux market due to the closure of certain 
competing refineries in the U.S and the Company’s continued efforts to access new markets to maximize profitability.  

Sales volumes for crude and diluent increased by 7% and 9%, respectively. The increase was mainly due to additional opportunities 
to bring volumes into the Company’s integrated assets, primarily attributable to the addition of new storage tanks and common 
infrastructure added in 2018.  

Sales  volumes  for  propane  and  other  NGLs  decreased  by  19%  and  10%,  respectively  primarily  due  to  the  sale  of  the  Wholesale 
Propane business during 2018 and lower condensate sales in the current quarter, with the year over year results also being impacted 
by the constraint of rail service in the market place in the first quarter on 2018. 

EXPENSES 

General and administrative (“G&A”), excluding depreciation and amortization 

Three months ended  

December 31 

Years ended  

December 31 

2018 

2017 

2018 

2017 

General and administrative ...............................................................  

$           8,597  

$      22,975     

$      32,155  

$       50,016   

The quarter over quarter decrease was primarily due to the recognition of non-recurring reorganization and executive related costs 

incurred in the comparative period and lower head office lease costs due to the adoption of IFRS 16. The year over year comparative 

period decrease was due to lower payroll costs due to the continuing impact of our headcount rationalization efforts from the fourth 

quarter of 2017 and lower head office lease costs due to the adoption of IFRS 16. The lease cost reduction was related to the adoption 

of IFRS 16, as noted in the “Accounting Policies” section, which resulted in $2.0 million and $6.2 million reduction in expenses in the 

three months and year ended December 31, 2018, respectively.  

Depreciation and impairment 

Three months ended  

December 31 

Years ended  

December 31 

2018 

2017 

2018 

2017 

Financial performance 

Depreciation and impairment  ..........................................................  

$         25,265 

$    24,589  

 $      143,160     

$    100,837   

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

Revenue for refined products increased by 18% and 26%, respectively. The increase was primarily due to higher volumes sold for 
drilling fluids and roofing asphalt as discussed above as well as higher average crude oil prices which supported the increase in prices 
for these products.  

Right-of-use asset depreciation 

The increase in both periods was primarily due to impact of impairment related to assets held for sale and depreciation on asset 

additions in the current periods, partially offset by asset dispositions.  

Revenue for crude and diluent decreased by 22% and increased by 26%, respectively. The quarter over quarter decrease was largely 
due to lower realized pricing in the current quarter, partially offset by the increase in volumes in the current period as discussed 
above. The year over year increase was largely due to higher average prices and the increase in volumes in the current period as 
discussed above.  

Right-of-use depreciation .................................................................  

$        10,359 

$       - 

$       43,184  

$              - 

Three months ended  

December 31 

Years ended  

December 31 

2018 

2017 

2018 

2017 

Revenue for propane and other NGLs decreased by 29% and 4% respectively mainly due to lower volumes as discussed above, with 
the quarter over quarter period also being impacted by lower prices.  

The increase in both periods relates to right of use depreciation which represents the impact of the adoption of IFRS 16 as noted in 

the “Accounting Policies” section. The right-of-use assets are depreciated over the lease term.  

Segment profit increased significantly in both periods. The increase was attributable to higher refined product margins driven by a 
greater proportion of higher margin product sales and by the differentials which supported lower cost of sales in the current periods. 
The increase was also driven by higher crude margins due to crude pricing spreads and locational as well as blend quality differentials. 
Additionally, the increase was due to lower rail car lease expenses of $8.8 million and $40.1 million in the three months and year 
ended December 31, 2018, respectively, as a result of the adoption of IFRS 16 as discussed under “Accounting Policies” section. These 
increases were offset by lower margins earned on propane and other NGLs due to the sale of the Wholesale Propane business during 
the fourth quarter of 2018 and regional pricing constraints at certain distribution hubs.  

Management’s Discussion and Analysis 

      Gibson Energy Inc.                                                            13                                              Management’s Discussion and Analysis  
Gibson Energy

14 

Amortization and impairment 

Three months ended  

December 31 

Years ended 

December 31 

2018 

2017 

2018 

2017 

Amortization and impairment ...........................................................  

$        3,146  

$      2,898     

$        10,870  

$        23,340   

The decrease in the year ended comparative period was driven by the impact of certain intangible assets becoming fully amortized 

in prior year periods. No impairment related to intangibles was recorded in 2018. 

Goodwill impairment 

Three months ended  

December 31 

Years ended  

December 31 

2018 

2017 

2018 

2017 

Goodwill impairment  .......................................................................  

$                   -  

$     69,414  

 $          20,479 

$         69,414 

      Gibson Energy Inc.                                                            14                                              Management’s Discussion and Analysis  

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
  
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
  
 
 
 
 
Operational performance 

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

Sales  volumes  for  refined  products  increased  by  10%  and  11%,  respectively.  The  increase  was  primarily  due  to  higher  available 

volumes from the Moose Jaw Facility driven by higher efficiencies which supported increased sales volumes for drilling fluids and 

roofing flux. Sales volumes for drilling fluids have increased principally as a result of increased U.S. drilling activity, and the ability of 

the Company to gain market share in the Permian and Niobrara-Denver Julesburg basins, while the increase in sales volumes for 

roofing flux is supported by the Company’s ability to gain market share within the roofing flux market due to the closure of certain 

competing refineries in the U.S and the Company’s continued efforts to access new markets to maximize profitability.  

Sales volumes for crude and diluent increased by 7% and 9%, respectively. The increase was mainly due to additional opportunities 

to bring volumes into the Company’s integrated assets, primarily attributable to the addition of new storage tanks and common 

infrastructure added in 2018.  

Sales  volumes  for  propane  and  other  NGLs  decreased  by  19%  and  10%,  respectively  primarily  due  to  the  sale  of  the  Wholesale 

Propane business during 2018 and lower condensate sales in the current quarter, with the year over year results also being impacted 

by the constraint of rail service in the market place in the first quarter on 2018. 

EXPENSES 

General and administrative (“G&A”), excluding depreciation and amortization 

Three months ended  
December 31 
2018 

2017 

Years ended  
December 31 
2018 

2017 

General and administrative ...............................................................  

$           8,597  

$      22,975     

$      32,155  

$       50,016   

The quarter over quarter decrease was primarily due to the recognition of non-recurring reorganization and executive related costs 
incurred in the comparative period and lower head office lease costs due to the adoption of IFRS 16. The year over year comparative 
period decrease was due to lower payroll costs due to the continuing impact of our headcount rationalization efforts from the fourth 
quarter of 2017 and lower head office lease costs due to the adoption of IFRS 16. The lease cost reduction was related to the adoption 
of IFRS 16, as noted in the “Accounting Policies” section, which resulted in $2.0 million and $6.2 million reduction in expenses in the 
three months and year ended December 31, 2018, respectively.  

Depreciation and impairment 

Three months ended  
December 31 
2018 

2017 

Years ended  
December 31 
2018 

2017 

Financial performance 

Depreciation and impairment  ..........................................................  

$         25,265 

$    24,589  

 $      143,160     

$    100,837   

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

Revenue for refined products increased by 18% and 26%, respectively. The increase was primarily due to higher volumes sold for 

drilling fluids and roofing asphalt as discussed above as well as higher average crude oil prices which supported the increase in prices 

The increase in both periods was primarily due to impact of impairment related to assets held for sale and depreciation on asset 
additions in the current periods, partially offset by asset dispositions.  

Right-of-use asset depreciation 

Right-of-use depreciation .................................................................  

$        10,359 

$       - 

$       43,184  

$              - 

Three months ended  
December 31 
2018 

2017 

Years ended  
December 31 
2018 

2017 

Revenue for propane and other NGLs decreased by 29% and 4% respectively mainly due to lower volumes as discussed above, with 

the quarter over quarter period also being impacted by lower prices.  

The increase in both periods relates to right of use depreciation which represents the impact of the adoption of IFRS 16 as noted in 
the “Accounting Policies” section. The right-of-use assets are depreciated over the lease term.  

Amortization and impairment 

Three months ended  
December 31 
2018 

2017 

Years ended 
December 31 
2018 

2017 

Amortization and impairment ...........................................................  

$        3,146  

$      2,898     

$        10,870  

$        23,340   

The decrease in the year ended comparative period was driven by the impact of certain intangible assets becoming fully amortized 
in prior year periods. No impairment related to intangibles was recorded in 2018. 

Goodwill impairment 

Three months ended  
December 31 
2018 

2017 

Years ended  
December 31 
2018 

2017 

Goodwill impairment  .......................................................................  

$                   -  

$     69,414  

 $          20,479 

$         69,414 

for these products.  

discussed above.  

Revenue for crude and diluent decreased by 22% and increased by 26%, respectively. The quarter over quarter decrease was largely 

due to lower realized pricing in the current quarter, partially offset by the increase in volumes in the current period as discussed 

above. The year over year increase was largely due to higher average prices and the increase in volumes in the current period as 

Segment profit increased significantly in both periods. The increase was attributable to higher refined product margins driven by a 

greater proportion of higher margin product sales and by the differentials which supported lower cost of sales in the current periods. 

The increase was also driven by higher crude margins due to crude pricing spreads and locational as well as blend quality differentials. 

Additionally, the increase was due to lower rail car lease expenses of $8.8 million and $40.1 million in the three months and year 

ended December 31, 2018, respectively, as a result of the adoption of IFRS 16 as discussed under “Accounting Policies” section. These 

increases were offset by lower margins earned on propane and other NGLs due to the sale of the Wholesale Propane business during 

the fourth quarter of 2018 and regional pricing constraints at certain distribution hubs.  

      Gibson Energy Inc.                                                            13                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            14                                              Management’s Discussion and Analysis  

15 

Management’s Discussion and Analysis

Gibson Energy 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
  
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
  
 
 
 
 
In the year ended December 31, 2018, the impairment charge relates to the assets held for sale. In the three months and year ended 
December 31, 2017, the Company recorded goodwill impairment charges of $69.4 million related to the U.S. Truck Transportation 
and the U.S. Wholesale business.  

Net interest expense 

Stock based compensation 

Three months ended  
December 31 
2018 

2017 

Years ended  
December 31 
2018 

2017 

Stock based compensation ...............................................................  

$         8,050  

$          8,492 

$        19,124 

$      23,244   

The quarter over quarter decrease was primarily due to lower restricted share unit (“RSU”) expenses in the current quarter partially 
offset by the recognition of a mark to market loss of $2.4 million compared to a mark to market gain of $0.7 million related to equity 
swaps in the comparative period. The year ended comparative period decrease was primarily driven by lower RSU expense in the 
current year and the impact of the recognition of a mark to market gain of $0.9 million compared to a mark to market expense of 
$1.2 million related to equity swaps in the comparative year. 

Debt extinguishment costs 

During the year ended December 31, 2017 the Company incurred debt extinguishment costs related to the repayment of $211.1 
million principal amount of 7.00% Senior Unsecured Notes (the “C$ Notes”) and U.S.$338.8 million principal amount of 6.75% Senior 
Unsecured Notes (the “US$ Notes”) (collectively the “Retired Notes”) of $60.5 million. 

Loss on net assets held for sale 

During the three months and year ended December 31, 2018 the Company completed the sale of its Wholesale Propane business for 
gross proceeds of $42.8  million resulting  in recognition of a loss on  sale of  $5.0 million (see note 8 in the consolidated financial 
statements). 

Foreign exchange (gains) loss not affecting segment profit 

Three months ended  
December 31 
2018 

2017 

Years ended  
December 31 
2018 

2017 

RESULTS OF DISCONTINUED OPERATIONS 

Unrealized foreign exchange loss (gain) on the movement in 

exchange rates on U.S. dollar Revolving Credit Facility and long-
term debt ......................................................................................  
Realized foreign exchange gain on settlement of U.S. dollar Revolving 
Credit Facility and long-term debt ................................................  
Corporate foreign exchange (gain) loss  ............................................  
Total foreign exchange (gain) loss .....................................................  

$            -  

$  15,803  

$       4,403   

$    (3,564)  

Canadian Truck Transportation business 

- 

(1,723)   
$    (1,723)   

(12,514)   
(755)   
$     2,534     

-   
(2,089)   
$       2,314   

(15,224) 
652 
$  (18,136) 

During  the  three  months  ended  December  31,  2018,  the  gain  recorded  is  primarily  driven  by  the  net  favorable  movements  in 
exchange rates on the translation of corporate foreign exchange and during the year ended December 31, 2018, the gains and losses 
were primarily driven by the favorable and unfavorable movements in exchange rates on the translation of the Company’s U.S dollar 
denominated Revolving Credit Facility and long-term debt and corporate foreign exchange gain. During the three months and year 
ended December 31, 2017, the gains and losses were primarily driven by the favorable and unfavorable movements in exchange rates 
on the translation of the Company’s U.S dollar denominated Revolving Credit Facility and long-term debt.  

Three months ended  

December 31 

Years ended  

December 31 

2018 

2017 

2018 

2017 

Net interest expense .........................................................................  

$    17,669 

$   17,341  

$   74,089     

$ 77,081   

The quarter over quarter net interest expense increased due to higher finance lease interest costs of $1.4 million due to IFRS 16 

adoption as noted in the “Accounting Policies” section, partially offset by lower interest expense related to long-term debt and higher 

capitalized  interest  amounts  related  to  our  long-term  capital  projects.  The  year  ended  comparative  period  net  interest  expense 

decrease was due to lower interest expense related to long-term debt and higher capitalized interest amounts related to our long-

term capital projects, partially offset by finance lease interest costs of $6.5 million due to IFRS 16 adoption and by higher interest 

costs related to the Revolving Credit Facility. 

Income taxes 

Three months ended  

December 31 

Years ended  

December 31 

2018 

2017 

2018 

2017 

Current income tax expense (recovery)  ...........................................  

Deferred income tax expense (recovery) ..........................................  

$   22,396  

7,570 

$  (14,791)    

$  60,178 

(3,584)   

(4,565)   

Total income tax expense (recovery) ................................................  

$   29,966     

$  (18,375)   

$  55,613  

$  (35,702) 

(22,502) 

$ (58,204) 

Total  Income  tax  expense  from  continuing  operations  was  $30.0  million  and  $55.6  million  for  the  three  months  and  year  ended 

December 31, 2018 compared to an income tax recovery $18.4 million and $58.2 million, respectively for the three months and year 

ended December 31, 2017. The main driver for the increase in the total income tax expense for both comparative periods was the 

impact of higher taxable income. Furthermore, the year ended comparative period deferred income tax recovery decreased primarily 

due to the impact of realized and unrealized amounts relating to the net capital gains arising from foreign exchange movements, 

including repayments, on the Company’s U.S. dollar denominated long-term debt in the prior period. 

During the year ended December 31, 2018, the Company completed the assessment of various disposal groups that met the criteria 

under IFRS 5 – Non-Current Assets Held for Sale and Discontinued Operations (“IFRS 5”) as held for sale and/or discontinued operations 

(refer to note 8 in the 2018 consolidated financial statements).  

During 2018, the Canadian Truck Transportation business met the criterion for discontinued operation and held for sale. This business 

was historically reported under the Logistic segment. 

The Canadian Truck Transportation business includes a suite of logistical wellsite services that enable oil and liquids production to 

access fixed midstream infrastructure. This segment provides truck transportation and related services that allow the Company to 

service its customers’ needs between the wellhead and the end market and includes providing hauling services for crude, condensate, 

propane, butane, asphalt, methanol, sulfur, petroleum coke, emulsion, waste water and drilling fluids for many of Canada’s leading 

oil and gas producers. For certain services and geographical regions, the activity is generally the lowest in the winter months when 

daylight hours are shorter. 

Management’s Discussion and Analysis 

      Gibson Energy Inc.                                                            15                                              Management’s Discussion and Analysis  
Gibson Energy

16 

      Gibson Energy Inc.                                                            16                                              Management’s Discussion and Analysis  

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
In the year ended December 31, 2018, the impairment charge relates to the assets held for sale. In the three months and year ended 

Net interest expense 

December 31, 2017, the Company recorded goodwill impairment charges of $69.4 million related to the U.S. Truck Transportation 

Three months ended  
December 31 
2018 

2017 

Years ended  
December 31 
2018 

2017 

offset by the recognition of a mark to market loss of $2.4 million compared to a mark to market gain of $0.7 million related to equity 

Income taxes 

swaps in the comparative period. The year ended comparative period decrease was primarily driven by lower RSU expense in the 

current year and the impact of the recognition of a mark to market gain of $0.9 million compared to a mark to market expense of 

Three months ended  
December 31 
2018 

2017 

Years ended  
December 31 
2018 

2017 

Net interest expense .........................................................................  

$    17,669 

$   17,341  

$   74,089     

$ 77,081   

The quarter over quarter net interest expense increased due to higher finance lease interest costs of $1.4 million due to IFRS 16 
adoption as noted in the “Accounting Policies” section, partially offset by lower interest expense related to long-term debt and higher 
capitalized  interest  amounts  related  to  our  long-term  capital  projects.  The  year  ended  comparative  period  net  interest  expense 
decrease was due to lower interest expense related to long-term debt and higher capitalized interest amounts related to our long-
term capital projects, partially offset by finance lease interest costs of $6.5 million due to IFRS 16 adoption and by higher interest 
costs related to the Revolving Credit Facility. 

Current income tax expense (recovery)  ...........................................  
Deferred income tax expense (recovery) ..........................................  
Total income tax expense (recovery) ................................................  

$   22,396  
7,570 
$   29,966     

$  (14,791)    
(3,584)   
$  (18,375)   

$  60,178 

(4,565)   

$  55,613  

$  (35,702) 
(22,502) 
$ (58,204) 

Total  Income  tax  expense  from  continuing  operations  was  $30.0  million  and  $55.6  million  for  the  three  months  and  year  ended 
December 31, 2018 compared to an income tax recovery $18.4 million and $58.2 million, respectively for the three months and year 
ended December 31, 2017. The main driver for the increase in the total income tax expense for both comparative periods was the 
impact of higher taxable income. Furthermore, the year ended comparative period deferred income tax recovery decreased primarily 
due to the impact of realized and unrealized amounts relating to the net capital gains arising from foreign exchange movements, 
including repayments, on the Company’s U.S. dollar denominated long-term debt in the prior period. 

RESULTS OF DISCONTINUED OPERATIONS 

During the year ended December 31, 2018, the Company completed the assessment of various disposal groups that met the criteria 
under IFRS 5 – Non-Current Assets Held for Sale and Discontinued Operations (“IFRS 5”) as held for sale and/or discontinued operations 
(refer to note 8 in the 2018 consolidated financial statements).  

Canadian Truck Transportation business 

During 2018, the Canadian Truck Transportation business met the criterion for discontinued operation and held for sale. This business 
was historically reported under the Logistic segment. 

The Canadian Truck Transportation business includes a suite of logistical wellsite services that enable oil and liquids production to 
access fixed midstream infrastructure. This segment provides truck transportation and related services that allow the Company to 
service its customers’ needs between the wellhead and the end market and includes providing hauling services for crude, condensate, 
propane, butane, asphalt, methanol, sulfur, petroleum coke, emulsion, waste water and drilling fluids for many of Canada’s leading 
oil and gas producers. For certain services and geographical regions, the activity is generally the lowest in the winter months when 
daylight hours are shorter. 

and the U.S. Wholesale business.  

Stock based compensation 

Stock based compensation ...............................................................  

$         8,050  

$          8,492 

$        19,124 

$      23,244   

Three months ended  

December 31 

Years ended  

December 31 

2018 

2017 

2018 

2017 

The quarter over quarter decrease was primarily due to lower restricted share unit (“RSU”) expenses in the current quarter partially 

$1.2 million related to equity swaps in the comparative year. 

Debt extinguishment costs 

During the year ended December 31, 2017 the Company incurred debt extinguishment costs related to the repayment of $211.1 

million principal amount of 7.00% Senior Unsecured Notes (the “C$ Notes”) and U.S.$338.8 million principal amount of 6.75% Senior 

Unsecured Notes (the “US$ Notes”) (collectively the “Retired Notes”) of $60.5 million. 

Loss on net assets held for sale 

During the three months and year ended December 31, 2018 the Company completed the sale of its Wholesale Propane business for 

gross proceeds of $42.8  million resulting  in recognition of a loss on  sale of  $5.0 million (see note 8 in the consolidated financial 

statements). 

Foreign exchange (gains) loss not affecting segment profit 

Three months ended  

December 31 

Years ended  

December 31 

2018 

2017 

2018 

2017 

Unrealized foreign exchange loss (gain) on the movement in 

exchange rates on U.S. dollar Revolving Credit Facility and long-

term debt ......................................................................................  

$            -  

$  15,803  

$       4,403   

$    (3,564)  

Realized foreign exchange gain on settlement of U.S. dollar Revolving 

Credit Facility and long-term debt ................................................  

Corporate foreign exchange (gain) loss  ............................................  

- 

(1,723)   

(12,514)   

(755)   

-   

(2,089)   

(15,224) 

652 

Total foreign exchange (gain) loss .....................................................  

$    (1,723)   

$     2,534     

$       2,314   

$  (18,136) 

During  the  three  months  ended  December  31,  2018,  the  gain  recorded  is  primarily  driven  by  the  net  favorable  movements  in 

exchange rates on the translation of corporate foreign exchange and during the year ended December 31, 2018, the gains and losses 

were primarily driven by the favorable and unfavorable movements in exchange rates on the translation of the Company’s U.S dollar 

denominated Revolving Credit Facility and long-term debt and corporate foreign exchange gain. During the three months and year 

ended December 31, 2017, the gains and losses were primarily driven by the favorable and unfavorable movements in exchange rates 

on the translation of the Company’s U.S dollar denominated Revolving Credit Facility and long-term debt.  

      Gibson Energy Inc.                                                            15                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            16                                              Management’s Discussion and Analysis  

17 

Management’s Discussion and Analysis

Gibson Energy 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
The following tables set forth operating results from the discontinued operations of Canadian Truck Transportation for the three 
months and year ended December 31, 2018 and 2017: 

Volumes (barrels in thousands) 
Crude and other products ...................................................................  

Three months ended  
December 31 

20181 
11,887 

20171 
11,971 

Years ended  
December 31 
20181 
45,031  

20171 
46,815 

Three months ended  
December 31 

Years ended  
December 31 

20181 

20171 

20181 

20171 

Revenue 

Water hauling and disposal .......................................................  

$ 

$     26,890 

$ 

Revenue ............................................................................................  
Cost of sales ......................................................................................  
Segment profit ..................................................................................  
Depreciation, amortization, and impairment....................................  
Goodwill impairment ........................................................................  
Finance costs and other income, net ................................................  
Loss before taxes ..............................................................................  
Income tax (recovery) expense .........................................................  
Net income from discontinued operations, after tax ........................  

$            56,505       

50,027   
                6,478   
30,734   
19,988   
92   
(44,336)  
(12,310)  
  $         (32,026)  

$     57,860  
51,780 
             6,080 
5,138 
- 
- 
942 
249 
693 

$ 

$    217,408    
193,909 
            23,499 
44,215 
19,988 
295 
(40,999)   
(11,412)   
(29,587)   

$ 

$   236,340   
212,937 
           23,403   
22,321 
- 
- 
1,082 
287 
795 

$ 

1. 

The current period results include the impacts from the adoption of new accounting standards as discussed on pages 34. Comparative information has not been 
restated and, therefore, may not be comparable throughout the discussion on continuing operations. In addition, Comparative period segment information was 
represented to reflect the results of continuing operations separately from discontinued operations (see note 8 of the consolidated financial statements). 

Operational performance 

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

The Company derecognized the U.S. Environmental Services segment effective May 3, 2018. Accordingly, results for year ended December 31, 2018 represent the 

activity for the period January 1, 2018 to May 2, 2018.  

Crude and other product hauling barrels were consistent and decreased by 4%, respectively. The year ended comparative decrease 
in Liquid Petroleum Gas (“LPG”) mix and crude volumes hauled was partially offset by higher sulfur and propane volumes in the year.  

Financial performance 

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

Crude and other product revenue decreased by 2% and 8%, respectively. The quarter over quarter decrease was primarily due to 
lower hauling rates related to LPG mix, propane and sulfur. The year ended comparative period decrease was primarily due to lower 
volumes as discussed above and lower hauling rates for LPG mix and sulfur, partially offset by higher hauling rates for asphalt. 

Segment profit increased by 7% and was consistent, respectively. The quarter over quarter increase was mainly due to lower direct 
costs largely due to the continuation of the reduction in payroll related costs associated with overall headcount reductions.  

U.S. Environmental Services business 

On May 3, 2018, the Company completed the sale of its U.S. Environmental Services business for adjusted gross proceeds of $123.3 
million (US$96 million).  

The U.S. Environmental Services business included the provision of environmental and production services, such as emulsion hauling 
and treating, water hauling and disposal services and oilfield waste management, as well as industrial lift, exploration support services 
and accommodation facilities to the oil and gas industry. The U.S Environmental Services business was reported historically within 
Company’s Infrastructure, Logistics and Other reportable segments. Operating results related to the segment have been included in 
net  income  from  discontinued  operations  in  the  consolidated  statements  of  operations.  Comparative  period  balances  of  the 
consolidated statements of operations and cash flows have been restated. 

The following tables set forth operating results from discontinued operations of the U.S. Environmental Services business for the 

three months and years ended December 31, 2018 and 2017: 

Segment profit ..................................................................................  

                      - 

            7,716 

             9,207 

           25,131 

Other products and services .....................................................  

Total revenue ....................................................................................  

Cost of sales ......................................................................................  

Depreciation, amortization and impairment ....................................  

Finance costs and (other income), net ..............................................  

(Loss) income before taxes ...............................................................  

Income tax (recovery) provision  .......................................................  

Net (loss) income from discontinued operations, after tax ..............  

After tax (loss) gain on sale 2, 3 ..........................................................  

Three months ended  

December 31 

Years ended  

December 31 

2018 2 

2017 1 

2018 2 

2017 1 

- 

- 

- 

- 

- 

- 

- 

- 

- 

(816)   

(816)   

39,501 

66,391 

58,675 

44,301 

67 

(36,652) 

(23) 

(36,629) 

- 

42,207 

51,074 

93,281 

84,074 

3,493 

278 

5,436 

1,448 

3,988 

95,522 

99,510 

$  101,448 

135,386 

236,834 

211,703 

83,289 

277 

(58,435) 

(8,251) 

(50,184) 

- 

(Loss) gain on discontinued operations, after tax .............................  

$ 

$ 

(36,629) 

$ 

$ 

(50,184) 

The current period results include the impacts from the adoption of new accounting standards as discussed on page 34. Comparative information has not been 

restated and, therefore, may not be comparable throughout the discussion on discontinued operations. In addition, Comparative period segment information was 

represented to reflect the results of continuing operations separately from discontinued operations (see note 8 of the 2018 consolidated financial statements). 

1. 

2. 

3. 

December 31, 2018. 

Industrial Propane business 

statements). 

Income taxes  

The cash proceeds  of $123.3 million  and  transaction costs  of $13.6 million (including certain payments to employees), have been presented within investing 

activities from discontinued operations on the Company’s consolidated statements of cash flows.  

Operational and financial performance  

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

Revenue decreased by $66.4 million and $143.6 million, respectively, and segment profit decreased by $7.7 million and $15.9 million, 

respectively. The decrease in both comparative periods is a result of the current period being shorter than the prior period due to 

the sale of the business effective May 3, 2018. There was no contribution to results from this business during the three months ended 

During Q1 2017, the Company sold its Industrial Propane business for proceeds of $433.1 million resulting in the recognition of a 

post-tax gain on sale of $150.6 million. Accordingly, the results for the three months and year ended December 31, 2017 represent 

activity for the period between January 1, 2017 and February 28, 2017. During this period the Company had total revenues of $58.3 

million, segment profit of $13.6 million, and net income after tax of $159.9 million (see note 8 in the 2018 consolidated financial 

Including the tax impact of gains on discontinued operations, net income tax was a recovery of $8.7 million and an expense of $6.1 

million for the three months and year ended December 31, 2018 compared to an expense of $0.2 million and $22.6 million for the 

three months and year ended December 31, 2017, as disclosed in note 22 in the 2018 consolidated financial statements. The quarter 

over  quarter  change  in  current  income  tax  recovery  was  due  to  the  inclusion  of  Canadian  Truck  Transportation  in  discontinued 

operations while the year ended comparative period decrease in income tax expense was due to the recognition of tax on the gain 

on sale of the Industrial Propane business in 2017. The year ended comparative period increase in deferred tax expense was due 

      Gibson Energy Inc.                                                            18                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            17                                              Management’s Discussion and Analysis  
Gibson Energy

18 

Management’s Discussion and Analysis 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
The following tables set forth operating results from the discontinued operations of Canadian Truck Transportation for the three 

months and year ended December 31, 2018 and 2017: 

Volumes (barrels in thousands) 

Crude and other products ...................................................................  

Three months ended  

December 31 

20181 

11,887 

20171 

11,971 

Years ended  

December 31 

20181 

45,031  

20171 

46,815 

Three months ended  

December 31 

Years ended  

December 31 

20181 

20171 

20181 

20171 

Revenue ............................................................................................  

$            56,505       

$     57,860  

$    217,408    

$   236,340   

Cost of sales ......................................................................................  

50,027   

51,780 

193,909 

212,937 

Segment profit ..................................................................................  

                6,478   

             6,080 

            23,499 

           23,403   

Depreciation, amortization, and impairment....................................  

Goodwill impairment ........................................................................  

Finance costs and other income, net ................................................  

Loss before taxes ..............................................................................  

Income tax (recovery) expense .........................................................  

30,734   

19,988   

92   

(44,336)  

(12,310)  

5,138 

- 

- 

942 

249 

693 

44,215 

19,988 

295 

(40,999)   

(11,412)   

22,321 

- 

- 

1,082 

287 

795 

Net income from discontinued operations, after tax ........................  

  $         (32,026)  

$ 

$ 

(29,587)   

$ 

1. 

The current period results include the impacts from the adoption of new accounting standards as discussed on pages 34. Comparative information has not been 

restated and, therefore, may not be comparable throughout the discussion on continuing operations. In addition, Comparative period segment information was 

represented to reflect the results of continuing operations separately from discontinued operations (see note 8 of the consolidated financial statements). 

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

Crude and other product hauling barrels were consistent and decreased by 4%, respectively. The year ended comparative decrease 

in Liquid Petroleum Gas (“LPG”) mix and crude volumes hauled was partially offset by higher sulfur and propane volumes in the year.  

Operational performance 

Financial performance 

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

Crude and other product revenue decreased by 2% and 8%, respectively. The quarter over quarter decrease was primarily due to 

lower hauling rates related to LPG mix, propane and sulfur. The year ended comparative period decrease was primarily due to lower 

volumes as discussed above and lower hauling rates for LPG mix and sulfur, partially offset by higher hauling rates for asphalt. 

Segment profit increased by 7% and was consistent, respectively. The quarter over quarter increase was mainly due to lower direct 

costs largely due to the continuation of the reduction in payroll related costs associated with overall headcount reductions.  

U.S. Environmental Services business 

million (US$96 million).  

On May 3, 2018, the Company completed the sale of its U.S. Environmental Services business for adjusted gross proceeds of $123.3 

The U.S. Environmental Services business included the provision of environmental and production services, such as emulsion hauling 

and treating, water hauling and disposal services and oilfield waste management, as well as industrial lift, exploration support services 

and accommodation facilities to the oil and gas industry. The U.S Environmental Services business was reported historically within 

Company’s Infrastructure, Logistics and Other reportable segments. Operating results related to the segment have been included in 

net  income  from  discontinued  operations  in  the  consolidated  statements  of  operations.  Comparative  period  balances  of  the 

consolidated statements of operations and cash flows have been restated. 

      Gibson Energy Inc.                                                            17                                              Management’s Discussion and Analysis  

The following tables set forth operating results from discontinued operations of the U.S. Environmental Services business for the 
three months and years ended December 31, 2018 and 2017: 

Three months ended  
December 31 

Years ended  
December 31 

2018 2 

2017 1 

2018 2 

2017 1 

Revenue 

Water hauling and disposal .......................................................  
Other products and services .....................................................  
Total revenue ....................................................................................  
Cost of sales ......................................................................................  
Segment profit ..................................................................................  
Depreciation, amortization and impairment ....................................  
Finance costs and (other income), net ..............................................  
(Loss) income before taxes ...............................................................  
Income tax (recovery) provision  .......................................................  
Net (loss) income from discontinued operations, after tax ..............  
After tax (loss) gain on sale 2, 3 ..........................................................  
(Loss) gain on discontinued operations, after tax .............................  

$ 

- 
- 
- 
- 
                      - 
- 
- 
- 
- 
- 
(816)   
(816)   

$ 

$     26,890 
39,501 
66,391 
58,675 
            7,716 
44,301 
67 
(36,652) 
(23) 
(36,629) 
- 
(36,629) 

$ 

$ 

42,207 
51,074 
93,281 
84,074 
             9,207 
3,493 
278 
5,436 
1,448 
3,988 
95,522 
99,510 

$ 

$  101,448 
135,386 
236,834 
211,703 
           25,131 
83,289 
277 
(58,435) 
(8,251) 
(50,184) 
- 
(50,184) 

$ 

1. 

2. 

3. 

The current period results include the impacts from the adoption of new accounting standards as discussed on page 34. Comparative information has not been 
restated and, therefore, may not be comparable throughout the discussion on discontinued operations. In addition, Comparative period segment information was 
represented to reflect the results of continuing operations separately from discontinued operations (see note 8 of the 2018 consolidated financial statements). 

The Company derecognized the U.S. Environmental Services segment effective May 3, 2018. Accordingly, results for year ended December 31, 2018 represent the 
activity for the period January 1, 2018 to May 2, 2018.  

The cash proceeds  of $123.3 million  and  transaction costs  of $13.6 million (including certain payments to employees), have been presented within investing 
activities from discontinued operations on the Company’s consolidated statements of cash flows.  

Operational and financial performance  

In the three months and year ended December 31, 2018 compared to the three months and year ended December 31, 2017: 

Revenue decreased by $66.4 million and $143.6 million, respectively, and segment profit decreased by $7.7 million and $15.9 million, 
respectively. The decrease in both comparative periods is a result of the current period being shorter than the prior period due to 
the sale of the business effective May 3, 2018. There was no contribution to results from this business during the three months ended 
December 31, 2018. 

Industrial Propane business 

During Q1 2017, the Company sold its Industrial Propane business for proceeds of $433.1 million resulting in the recognition of a 
post-tax gain on sale of $150.6 million. Accordingly, the results for the three months and year ended December 31, 2017 represent 
activity for the period between January 1, 2017 and February 28, 2017. During this period the Company had total revenues of $58.3 
million, segment profit of $13.6 million, and net income after tax of $159.9 million (see note 8 in the 2018 consolidated financial 
statements). 

Income taxes  

Including the tax impact of gains on discontinued operations, net income tax was a recovery of $8.7 million and an expense of $6.1 
million for the three months and year ended December 31, 2018 compared to an expense of $0.2 million and $22.6 million for the 
three months and year ended December 31, 2017, as disclosed in note 22 in the 2018 consolidated financial statements. The quarter 
over  quarter  change  in  current  income  tax  recovery  was  due  to  the  inclusion  of  Canadian  Truck  Transportation  in  discontinued 
operations while the year ended comparative period decrease in income tax expense was due to the recognition of tax on the gain 
on sale of the Industrial Propane business in 2017. The year ended comparative period increase in deferred tax expense was due 

Gibson Energy 

      Gibson Energy Inc.                                                            18                                              Management’s Discussion and Analysis  

Management’s Discussion and Analysis

19 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
primarily due to the utilization of tax assets to offset the gain on the sale of the business.  

SUMMARY OF QUARTERLY RESULTS  

Cash flow summary – Discontinued operations 

The following table sets forth a summary of the Company’s quarterly results for each of the last eight quarters:  

The following table summarizes the sources and uses of funds for the years ended December 31, 2018 and 2017 from discontinued 
operations: 

Q4 

Q2 

Q1 

Q4 

Q2 

Q1 

20181 

Q3 

20171 

Q3 

Years ended  
December 31 
2018 

20171,2 

Statement of cash flows 
Cash flows (used in) provided by: 
Operating activities ..................................................................................................................................  
Investing activities ....................................................................................................................................  
Financing activities ...................................................................................................................................  

  $      36,652           $ 

107,777 

22,107 
416,016 

$     (3,056)                $                    -                   

Revenue  ....................................   $1,314,605 

$2,130,022 $ 1,716,612 $1,685,350 

  $1,650,445 

$1,293,863

$1,366,823 $1,348,515

Net income (loss) .......................  

Adjusted EBITDA (2)  ...................  

47,275 

134,001 

6,822 

140,448 

15,242        11,785 

96,113

86,753 

(55,851)

68,475

(5,410)

42,762

   (2,195)

52,525

(2,870)

65,439

Basic  ......................................  

$         0.33 

$         0.05                       

$         0.11                     

$        0.08              

  $       (0.40)              $     (0.04)             $      (0.01)       $       (0.02) 

Diluted  ..................................  

$         0.32 

$         0.05                

$         0.11              

$        0.08         $       (0.40)        $     (0.04)             $      (0.01)       $       (0.02) 

1. 

2. 

The Company derecognized the U.S. Environmental Services business effective May 3, 2018. Accordingly, cash flow related to this business for the year ended 
December 31, 2018 represent the activity for the period January 1, 2018 to May 2, 2018. Additionally, results for the three months and years ended December 31, 
2017 and 2018 include cash flows related to Canadian Truck Transportation business. 

The 2018 amounts relate to the activity up to the date of the sale of the U.S. Environmental Services business while the 2017 amounts relate to the activity up to 
the sale of the Industrial Propane business. 

Cash provided by operating activities 

Cash provided by operating activities in the year ended December 31, 2018 was $36.7 million compared to cash provided by operating 
activities of $22.1 million year ended December 31, 2017. The change was primarily due to the timing of discontinued operations 
classification  and  completion  of  the  sale  of  businesses  as  noted  above.  Additionally,  the  change  in  working  capital  requirements 
related to the sale of the U.S. Environmental Services business and the Industrial Propane business were driven by the fact that the 
Company is no longer required to fund working capital post the sale of those businesses.  

Cash provided by investing activities 

Cash  provided  by  investing  activities  was  $107.8  million  for  the  year  ended  December  31,  2018,  compared  to  cash  provided  by 
investing  activities  of  $416.0  million  in  the  year  ended  December  31,  2017.  The  change  was  primarily  due  to  the  cash  proceeds 
received on the sale of the U.S. Environmental Services during 2018 and the sale of Industrial Propane business during 2017. 

Cash used in financing activities 

Cash used in financing activities was $3.1 million in the year ended December 31, 2018, compared to $nil in the year ended December 
31, 2017. The increase was primarily due to the adoption of IFRS 16, as noted in the “Accounting Policies” section, which requires the 
recognition of net lease payments under financing activities. 

Continuing operations 

Earnings (loss) per share 

Discontinued operations 

Earnings (loss) per share 

Combined operations 

Earnings (loss) per share 

Revenue  ....................................  

$    49,643 

$  47,922               

$    66,222        $    120,137     $     116,442    $    110,331   $   113,373  

$159,343 

Net (loss) income .......................  

Adjusted EBITDA (2)  ...................  

(31,210) 

6,478 

(4,470) 

6,177 

122,693 

5,386 

(17,090) 

14,727 

(30,696) 

13,796 

(6,233)  

12,946 

(3,328)  

13,862 

 150,718 

   21,467 

     Basic  .....................................  

     Diluted ..................................  

$      (0.22) 

$      (0.22) 

$    (0.03)                     

$         0.85                     

$       (0.12)              $       (0.21)              

$      (0.04)             $      (0.03)         $       1.06 

$    (0.03)              

$         0.83              

$       (0.12)        $       (0.21)       $      (0.04)             $      (0.03)       $       1.04 

Revenue (1,3) ...............................   $1,364,248 

$2,177,944 $1,782,834 $1,805,487 

  $1,766,887 

$1,404,194

$1,480,196 $1,507,858

Net income (loss) .......................  

Adjusted EBITDA (2)  ...................  

16,065 

140,479 

2,352

146,625

137,935

101,499

(5,305) 

101,480 

(86,547)

82,271

(11,643)

55,708

(5,523)

 147,848

66,387         86,906

Basic  ......................................  

$         0.11 

$        0.02            $        0.96             

$      (0.04)         $       (0.61) 

$       (0.08)  

$       (0.04)        

$        1.04 

Diluted ...................................  

$         0.10 

$        0.02                   

$        0.94                   

$      (0.04)             

  $       (0.61)      $       (0.08)     $       (0.04)       $        1.02 

1. 

2. 

Comparative period information was represented to reflect the results of continuing operations separately from discontinued operations (see note 8 of the 2018 

consolidated financial statements). Furthermore, the 2018 period results include the impacts from the adoption of new accounting standards as discussed on 

page 34. Comparative information has not been restated and, therefore, may not be comparable.  

Adjusted EBITDA is defined as net income (loss) before interest expense, income taxes, depreciation, amortization, other non-cash expenses and charges deducted 

in  determining  consolidated  net  income  (loss),  including  movement  in  the  unrealized  gains  and  losses  on  the  Company’s  financial  instruments,  stock  based 

compensation expense, impairment of long-term assets and asset write-downs. It also removes the impact of foreign exchange movements in the Company’s U.S. 

dollar  denominated  long-term  debt,  debt  extinguishment  expenses  and  adjustments  that  are  considered  unusual,  non-recurring  or  non-operating  in  nature. 

Combined Adjusted EBITDA includes results from continuing and discontinued operations, while Adjusted EBITDA from continuing operations only includes results 

from continuing operations. 

3. 

Revenue from combined operations represents the aggregated results of both continuing and discontinued operations and is not a measure recognized under 

IFRS and does not have standardized meanings prescribed by IFRS. 

The Company presents Combined Adjusted EBITDA, and Adjusted EBITDA from continuing operations and discontinued operations 

because it considers these to be important supplemental measures of the Company’s performance and believes these measures are 

frequently used by securities analysts, investors and other interested parties in the evaluation of companies in industries with similar 

capital structures. Combined Adjusted EBITDA and Adjusted EBITDA from continuing and discontinued operations have limitations as 

analytical tools, and readers should not consider this item in isolation, or as a substitute for an analysis of the Company’s results as 

reported under IFRS. Some of these limitations are: 

      Gibson Energy Inc.                                                            20                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            19                                              Management’s Discussion and Analysis  
Gibson Energy

20 

Management’s Discussion and Analysis 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
      
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
primarily due to the utilization of tax assets to offset the gain on the sale of the business.  

SUMMARY OF QUARTERLY RESULTS  

Cash flow summary – Discontinued operations 

operations: 

The following table summarizes the sources and uses of funds for the years ended December 31, 2018 and 2017 from discontinued 

The following table sets forth a summary of the Company’s quarterly results for each of the last eight quarters:  

Q4 

20181 
Q3 

Q2 

Q1 

Q4 

20171 
Q3 

Q2 

Q1 

Statement of cash flows 

Cash flows (used in) provided by: 

Operating activities ..................................................................................................................................  

  $      36,652           $ 

Investing activities ....................................................................................................................................  

107,777 

22,107 

416,016 

Financing activities ...................................................................................................................................  

$     (3,056)                $                    -                   

Years ended  

December 31 

2018 

20171,2 

1. 

2. 

The Company derecognized the U.S. Environmental Services business effective May 3, 2018. Accordingly, cash flow related to this business for the year ended 

December 31, 2018 represent the activity for the period January 1, 2018 to May 2, 2018. Additionally, results for the three months and years ended December 31, 

2017 and 2018 include cash flows related to Canadian Truck Transportation business. 

The 2018 amounts relate to the activity up to the date of the sale of the U.S. Environmental Services business while the 2017 amounts relate to the activity up to 

the sale of the Industrial Propane business. 

Cash provided by operating activities 

Cash provided by operating activities in the year ended December 31, 2018 was $36.7 million compared to cash provided by operating 

activities of $22.1 million year ended December 31, 2017. The change was primarily due to the timing of discontinued operations 

classification  and  completion  of  the  sale  of  businesses  as  noted  above.  Additionally,  the  change  in  working  capital  requirements 

related to the sale of the U.S. Environmental Services business and the Industrial Propane business were driven by the fact that the 

Company is no longer required to fund working capital post the sale of those businesses.  

Cash  provided  by  investing  activities  was  $107.8  million  for  the  year  ended  December  31,  2018,  compared  to  cash  provided  by 

investing  activities  of  $416.0  million  in  the  year  ended  December  31,  2017.  The  change  was  primarily  due  to  the  cash  proceeds 

received on the sale of the U.S. Environmental Services during 2018 and the sale of Industrial Propane business during 2017. 

Cash provided by investing activities 

Cash used in financing activities 

Cash used in financing activities was $3.1 million in the year ended December 31, 2018, compared to $nil in the year ended December 

31, 2017. The increase was primarily due to the adoption of IFRS 16, as noted in the “Accounting Policies” section, which requires the 

recognition of net lease payments under financing activities. 

      Gibson Energy Inc.                                                            19                                              Management’s Discussion and Analysis  

Continuing operations 

Revenue  ....................................   $1,314,605 
Net income (loss) .......................  
47,275 
Adjusted EBITDA (2)  ...................  
134,001 
Earnings (loss) per share 

Basic  ......................................  
Diluted  ..................................  

$         0.33 
$         0.32 

Discontinued operations 

Revenue  ....................................  
Net (loss) income .......................  
Adjusted EBITDA (2)  ...................  
Earnings (loss) per share 
     Basic  .....................................  
     Diluted ..................................  

$    49,643 
(31,210) 
6,478 

$      (0.22) 
$      (0.22) 

Combined operations 

Revenue (1,3) ...............................   $1,364,248 
16,065 
Net income (loss) .......................  
Adjusted EBITDA (2)  ...................  
140,479 
Earnings (loss) per share 

Basic  ......................................  
Diluted ...................................  

$         0.11 
$         0.10 

$2,130,022 $ 1,716,612 $1,685,350 
15,242        11,785 
86,753 
96,113

6,822 
140,448 

  $1,650,445 
(55,851)
68,475

$1,293,863
(5,410)
42,762

$1,366,823 $1,348,515
(2,870)
65,439

   (2,195)
52,525

$         0.05                       
$         0.05                

$         0.11                     
$         0.11              

$        0.08              
  $       (0.40)              $     (0.04)             $      (0.01)       $       (0.02) 
$        0.08         $       (0.40)        $     (0.04)             $      (0.01)       $       (0.02) 

$  47,922               

(4,470) 
6,177 

$    66,222        $    120,137     $     116,442    $    110,331   $   113,373  
(3,328)  
13,862 

(17,090) 
14,727 

(30,696) 
13,796 

122,693 
5,386 

(6,233)  
12,946 

$159,343 
 150,718 
   21,467 

$    (0.03)                     
$    (0.03)              

$         0.85                     
$         0.83              

$       (0.12)              $       (0.21)              
$      (0.04)             $      (0.03)         $       1.06 
$       (0.12)        $       (0.21)       $      (0.04)             $      (0.03)       $       1.04 

$2,177,944 $1,782,834 $1,805,487 
(5,305) 
101,480 

137,935
101,499

2,352
146,625

  $1,766,887 
(86,547)
82,271

$1,404,194
(11,643)
55,708

$1,480,196 $1,507,858
 147,848
(5,523)
66,387         86,906

$        0.02            $        0.96             
$        0.02                   

$        0.94                   

$      (0.04)         $       (0.61) 
$      (0.04)             

$        1.04 
  $       (0.61)      $       (0.08)     $       (0.04)       $        1.02 

$       (0.04)        

$       (0.08)  

1. 

2. 

Comparative period information was represented to reflect the results of continuing operations separately from discontinued operations (see note 8 of the 2018 
consolidated financial statements). Furthermore, the 2018 period results include the impacts from the adoption of new accounting standards as discussed on 
page 34. Comparative information has not been restated and, therefore, may not be comparable.  

Adjusted EBITDA is defined as net income (loss) before interest expense, income taxes, depreciation, amortization, other non-cash expenses and charges deducted 
in  determining  consolidated  net  income  (loss),  including  movement  in  the  unrealized  gains  and  losses  on  the  Company’s  financial  instruments,  stock  based 
compensation expense, impairment of long-term assets and asset write-downs. It also removes the impact of foreign exchange movements in the Company’s U.S. 
dollar  denominated  long-term  debt,  debt  extinguishment  expenses  and  adjustments  that  are  considered  unusual,  non-recurring  or  non-operating  in  nature. 
Combined Adjusted EBITDA includes results from continuing and discontinued operations, while Adjusted EBITDA from continuing operations only includes results 
from continuing operations. 

3. 

Revenue from combined operations represents the aggregated results of both continuing and discontinued operations and is not a measure recognized under 
IFRS and does not have standardized meanings prescribed by IFRS. 

The Company presents Combined Adjusted EBITDA, and Adjusted EBITDA from continuing operations and discontinued operations 
because it considers these to be important supplemental measures of the Company’s performance and believes these measures are 
frequently used by securities analysts, investors and other interested parties in the evaluation of companies in industries with similar 
capital structures. Combined Adjusted EBITDA and Adjusted EBITDA from continuing and discontinued operations have limitations as 
analytical tools, and readers should not consider this item in isolation, or as a substitute for an analysis of the Company’s results as 
reported under IFRS. Some of these limitations are: 

Gibson Energy 

      Gibson Energy Inc.                                                            20                                              Management’s Discussion and Analysis  

Management’s Discussion and Analysis

21 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
      
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
- 

Adjusted EBITDA and Combined Adjusted EBITDA: 

- 

- 

- 

- 

- 

excludes certain income tax payments that may represent a reduction in cash available to the Company; 

includes the impact from the adoption of IFRS 16 effective January 1, 2018 without restating the prior periods as noted in 
the “Accounting Policies” section; 

does  not  reflect  the  Company’s  cash  expenditures,  or  future  requirements  for  capital  expenditures  or  contractual 
commitments; 

Continuing operations 

does not reflect changes in, or cash requirements for, the Company’s working capital needs; and 

does not reflect the significant interest expense, or the cash requirements necessary to service interest payments on the 
Company’s debt, including the Debentures, and Notes and Retired Notes (as defined herein) and the Revolving Credit Facility 
(as defined herein). 

- 

Although depreciation, amortization and impairment are non-cash charges, the assets being depreciated and amortized will often 
have to be replaced in the future and Adjusted EBITDA does not reflect any cash requirements for such replacements; and 

-  Other companies in the industry may calculate Combined Adjusted EBITDA and Adjusted EBITDA differently than the Company 

does, limiting its usefulness as a comparative measure.  

Because of these limitations, Combined Adjusted EBITDA and Adjusted EBITDA should not considered to be a measure of discretionary 
cash available to the Company to invest in the growth of the Company’s business. The Company compensates for these limitations 
by relying primarily on the Company’s IFRS results and using Combined Adjusted EBITDA and Adjusted EBITDA only as supplemental 
measures.  

The following tables reconciles segment profit to Adjusted EBITDA for continuing operations, discontinued operations and combined 
operations for each of the last eight quarters and for the twelve months ended December 31, 2018 and 2017: 

Continuing operations 
Segment profit .........................................................................  
Interest income ........................................................................  
Foreign exchange gain (loss) – corporate ................................  
General and administrative  .....................................................  
Net unrealized (gain) loss from financial instruments (1) ..........  
Adjusted EBITDA ......................................................................  

Discontinued operations 
Segment profit and adjusted EBITDA .......................................  

Combined operations 
Segment profit .........................................................................  
Interest income ........................................................................  
Foreign exchange gain (loss) – corporate ................................  
General and administrative  .....................................................  
Net unrealized (gain)loss  from financial instruments (1) ..........  
Combined Adjusted EBITDA .....................................................  

December 31, 
2018 

Three months ended (restated3) 
September 30, 
2018 

June 30, 
2018 

March 31, 
2018 

  $  153,569   $  142,227   $  95,802   $  95,489 
294 
170 
(8,468) 
(732) 
  $   134,001   $   140,448   $   96,113   $   86,753 

346
1,732
(8,597)
(13,049)

485
(2,357)
(6,804)
8,987

368
2,542
(8,286)
3,597

Twelve months 
ended 
(restated3) 
December 31, 
2018 

  $  487,087
1,493
2,087
(32,155)
(1,197)
  $   457,315

    $       6,478       $       6,177       $        5,386       $     14,727 

        $     32,768  

   $     160,047    $    148,404    $    101,188    $    110,216 
294 
170 
(8,468) 
(732) 

346
1,732
(8,597)
(13,049) 

485
(2,357)
(6,804)
8,987

368
2,542
(8,286)
3,597

   $    140,479        $     146,625       $    101,499       $   101,480      

         $   519,855 
1,493
2,087
(32,155)
(1,197)
         $   490,083  

Management’s Discussion and Analysis 

      Gibson Energy Inc.                                                            21                                              Management’s Discussion and Analysis  
Gibson Energy

22 

Three months ended (restated3) 

Twelve months 

ended 

(restated3) 

December 31, 

September 30, 

2017 

2017 

June 30, 

2017 

March 31, 

December 31, 

2017 

2017 

Segment profit .........................................................................  

  $  71,431   $  51,265   $  60,170

  $  78,936 

  $  261,802

Interest income ........................................................................  

Foreign exchange gain (loss) – corporate ................................  

General and administrative  .....................................................  

Net unrealized loss (gain) from financial instruments (1) ..........  

Restructuring, severance and other costs (2) ............................  

500

755

(22,316)

19

18,086

320

(1,031)

(6,428)

(1,364)

-

299

152

(13,155)

4,059

1,000

665 

(528) 

(9,305) 

(4,329) 

- 

1,784

(652)

(51,204)

(1,615)

19,086

Adjusted EBITDA ......................................................................  

  $   68,475   $   42,762   $  52,525   $  65,439 

  $  229,201

Discontinued operations 

Combined operations 

Segment profit and adjusted EBITDA .......................................  

    $       13,796     $     12,946   $  13,862

  $  21,467 

  $ 

62,071

Segment profit .........................................................................  

   $     85,227 

  $    64,211   $  74,032

  $  100,403 

  $  323,873

Interest income ........................................................................  

Foreign exchange gain (loss) – corporate ................................  

General and administrative  .....................................................  

Net unrealized loss (gain) from financial instruments (1) ..........  

Restructuring, severance and other costs (2) ............................  

500

755

(22,316)

19

18,086

320

(1,031)

(6,428)

(1,364)

-

299

152

(13,155)

4,059

1,000

665 

(528) 

(9,305) 

(4,329) 

- 

1,784

(652)

(51,204)

(1,615)

19,086

Combined Adjusted EBITDA .....................................................  

   $       82,271   $  55,708       $    66,387   $  86,906 

  $  291,272

1. 

Reflects the exclusion of the movement in the mark-to-market valuation of financial instruments used in risk management activities. The Company uses crude oil 

and NGL priced futures, options and swaps to manage the exposure to commodities price movements and foreign currency forward contracts and options to 

manage foreign exchange risks, although the Company does not formally designate these financial instruments as hedges for accounting purposes. Accordingly, 

the unrealized gains or losses on these financial instruments are recorded directly to the income statement. Management believes that this adjustment better 

correlates the effect of risk management activities to the underlying operating activities to which they relate. 

Represents the restructuring and severance costs incurred related to a headcount rationalization review, and executive payroll related costs. 

Comparative periods were restated to reflect the results of continuing operations separately from discontinued operations. Furthermore, the 2018 period results 

include the impacts from the adoption of new accounting standards as discussed on page 34. Comparative information has not been restated and, therefore, may 

2. 

3. 

not be comparable.  

The  results  of  Adjusted  EBITDA  are  driven  primarily  by  segment  profit  for  the  respective  reportable  segments  as  well  as  the 

adjustments discussed above in the tables. For more details on the specific factors driving the periodic movements in segment profit, 

refer  to  the  results  of  continuing  and  discontinued  operations  included  in  this  MD&A.  The  following  identifies  the  key  drivers  in 

segment profitability over the last eight quarters: 

Infrastructure – The Infrastructure segment has progressively commissioned new storage capacity and related infrastructure, with 

800,000 barrels of additional capacity and related take-or-pay and stable fee-based cash flows added in 2018. This increase in capacity 

was primarily driven by the sustained demand for crude terminalling and storage services combined with the effective operation, 

including cost management, of its current Hardisty and Edmonton Terminals and has provided for the increase in segment profits. 

Logistics – The Logistics segment provides logistical services that enable crude production to access fixed midstream infrastructure in 

the U.S. The segment’s results have been impacted by the decline in volumes due to the loss of an exclusive customer coupled with 

continued competition and availability of drivers within the Company’s service areas, and the impact of one-time expenses such as 

severance,  relocation,  and  office  move  costs  which  has  inhibited  the  ability  of  the  Company  to  deliver  consistent  results  in  this 

segment.  

Wholesale – The Wholesale segment earns margins by capturing; quality, locational or time-based arbitrage opportunities related to 

the purchasing; selling, storing, and optimization of hydrocarbon products, including crude oil and refined products. Accordingly, this 

segment has been impacted by commodity price fluctuations in the pricing differentials between different geographic markets and 

product grades, most notably related to crude oil and NGLs. These fluctuations have been managed by purchasing and selling products 

through physical and financial contracts that include energy-related derivatives which have both supported and reduced segment 

      Gibson Energy Inc.                                                            22                                              Management’s Discussion and Analysis  

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
- 

- 

- 

- 

- 

- 

Adjusted EBITDA and Combined Adjusted EBITDA: 

excludes certain income tax payments that may represent a reduction in cash available to the Company; 

includes the impact from the adoption of IFRS 16 effective January 1, 2018 without restating the prior periods as noted in 

the “Accounting Policies” section; 

commitments; 

does  not  reflect  the  Company’s  cash  expenditures,  or  future  requirements  for  capital  expenditures  or  contractual 

does not reflect changes in, or cash requirements for, the Company’s working capital needs; and 

does not reflect the significant interest expense, or the cash requirements necessary to service interest payments on the 

Company’s debt, including the Debentures, and Notes and Retired Notes (as defined herein) and the Revolving Credit Facility 

(as defined herein). 

- 

Although depreciation, amortization and impairment are non-cash charges, the assets being depreciated and amortized will often 

have to be replaced in the future and Adjusted EBITDA does not reflect any cash requirements for such replacements; and 

-  Other companies in the industry may calculate Combined Adjusted EBITDA and Adjusted EBITDA differently than the Company 

does, limiting its usefulness as a comparative measure.  

Because of these limitations, Combined Adjusted EBITDA and Adjusted EBITDA should not considered to be a measure of discretionary 

cash available to the Company to invest in the growth of the Company’s business. The Company compensates for these limitations 

by relying primarily on the Company’s IFRS results and using Combined Adjusted EBITDA and Adjusted EBITDA only as supplemental 

measures.  

The following tables reconciles segment profit to Adjusted EBITDA for continuing operations, discontinued operations and combined 

operations for each of the last eight quarters and for the twelve months ended December 31, 2018 and 2017: 

Three months ended (restated3) 

December 31, 

September 30, 

2018 

2018 

June 30, 

2018 

March 31, 

December 31, 

2018 

2018 

Twelve months 

ended 

(restated3) 

Continuing operations 

Segment profit .........................................................................  

  $  153,569   $  142,227   $  95,802   $  95,489 

  $  487,087

Interest income ........................................................................  

Foreign exchange gain (loss) – corporate ................................  

General and administrative  .....................................................  

Net unrealized (gain) loss from financial instruments (1) ..........  

346

1,732

(8,597)

(13,049)

368

2,542

(8,286)

3,597

485

(2,357)

(6,804)

8,987

294 

170 

(8,468) 

(732) 

1,493

2,087

(32,155)

(1,197)

Adjusted EBITDA ......................................................................  

  $   134,001   $   140,448   $   96,113   $   86,753 

  $   457,315

Discontinued operations 

Combined operations 

Segment profit and adjusted EBITDA .......................................  

    $       6,478       $       6,177       $        5,386       $     14,727 

        $     32,768  

Segment profit .........................................................................  

   $     160,047    $    148,404    $    101,188    $    110,216 

         $   519,855 

Interest income ........................................................................  

Foreign exchange gain (loss) – corporate ................................  

General and administrative  .....................................................  

Net unrealized (gain)loss  from financial instruments (1) ..........  

346

1,732

(8,597)

(13,049) 

368

2,542

(8,286)

3,597

485

(2,357)

(6,804)

8,987

294 

170 

(8,468) 

(732) 

1,493

2,087

(32,155)

(1,197)

Combined Adjusted EBITDA .....................................................  

   $    140,479        $     146,625       $    101,499       $   101,480      

         $   490,083  

      Gibson Energy Inc.                                                            21                                              Management’s Discussion and Analysis  

Continuing operations 
Segment profit .........................................................................  
Interest income ........................................................................  
Foreign exchange gain (loss) – corporate ................................  
General and administrative  .....................................................  
Net unrealized loss (gain) from financial instruments (1) ..........  
Restructuring, severance and other costs (2) ............................  
Adjusted EBITDA ......................................................................  

Discontinued operations 
Segment profit and adjusted EBITDA .......................................  

Combined operations 
Segment profit .........................................................................  
Interest income ........................................................................  
Foreign exchange gain (loss) – corporate ................................  
General and administrative  .....................................................  
Net unrealized loss (gain) from financial instruments (1) ..........  
Restructuring, severance and other costs (2) ............................  
Combined Adjusted EBITDA .....................................................  

Three months ended (restated3) 

Twelve months 
ended 
(restated3) 

December 31, 
2017 

September 30, 
2017 

June 30, 
2017 

March 31, 
2017 

December 31, 
2017 

  $  71,431   $  51,265   $  60,170
299
152
(13,155)
4,059
1,000

320
(1,031)
(6,428)
(1,364)
-
  $   68,475   $   42,762   $  52,525   $  65,439 

  $  78,936 
665 
(528) 
(9,305) 
(4,329) 
- 

500
755
(22,316)
19
18,086

  $  261,802
1,784
(652)
(51,204)
(1,615)
19,086
  $  229,201

    $       13,796     $     12,946   $  13,862

  $  21,467 

  $ 

62,071

   $     85,227 
500
755
(22,316)
19
18,086

  $  100,403 
665 
(528) 
(9,305) 
(4,329) 
- 
   $       82,271   $  55,708       $    66,387   $  86,906 

  $    64,211   $  74,032
299
152
(13,155)
4,059
1,000

320
(1,031)
(6,428)
(1,364)
-

  $  323,873
1,784
(652)
(51,204)
(1,615)
19,086
  $  291,272

1. 

2. 

3. 

Reflects the exclusion of the movement in the mark-to-market valuation of financial instruments used in risk management activities. The Company uses crude oil 
and NGL priced futures, options and swaps to manage the exposure to commodities price movements and foreign currency forward contracts and options to 
manage foreign exchange risks, although the Company does not formally designate these financial instruments as hedges for accounting purposes. Accordingly, 
the unrealized gains or losses on these financial instruments are recorded directly to the income statement. Management believes that this adjustment better 
correlates the effect of risk management activities to the underlying operating activities to which they relate. 

Represents the restructuring and severance costs incurred related to a headcount rationalization review, and executive payroll related costs. 

Comparative periods were restated to reflect the results of continuing operations separately from discontinued operations. Furthermore, the 2018 period results 
include the impacts from the adoption of new accounting standards as discussed on page 34. Comparative information has not been restated and, therefore, may 
not be comparable.  

The  results  of  Adjusted  EBITDA  are  driven  primarily  by  segment  profit  for  the  respective  reportable  segments  as  well  as  the 
adjustments discussed above in the tables. For more details on the specific factors driving the periodic movements in segment profit, 
refer  to  the  results  of  continuing  and  discontinued  operations  included  in  this  MD&A.  The  following  identifies  the  key  drivers  in 
segment profitability over the last eight quarters: 

Infrastructure – The Infrastructure segment has progressively commissioned new storage capacity and related infrastructure, with 
800,000 barrels of additional capacity and related take-or-pay and stable fee-based cash flows added in 2018. This increase in capacity 
was primarily driven by the sustained demand for crude terminalling and storage services combined with the effective operation, 
including cost management, of its current Hardisty and Edmonton Terminals and has provided for the increase in segment profits. 

Logistics – The Logistics segment provides logistical services that enable crude production to access fixed midstream infrastructure in 
the U.S. The segment’s results have been impacted by the decline in volumes due to the loss of an exclusive customer coupled with 
continued competition and availability of drivers within the Company’s service areas, and the impact of one-time expenses such as 
severance,  relocation,  and  office  move  costs  which  has  inhibited  the  ability  of  the  Company  to  deliver  consistent  results  in  this 
segment.  

Wholesale – The Wholesale segment earns margins by capturing; quality, locational or time-based arbitrage opportunities related to 
the purchasing; selling, storing, and optimization of hydrocarbon products, including crude oil and refined products. Accordingly, this 
segment has been impacted by commodity price fluctuations in the pricing differentials between different geographic markets and 
product grades, most notably related to crude oil and NGLs. These fluctuations have been managed by purchasing and selling products 
through physical and financial contracts that include energy-related derivatives which have both supported and reduced segment 

Gibson Energy 

      Gibson Energy Inc.                                                            22                                              Management’s Discussion and Analysis  

Management’s Discussion and Analysis

23 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
profits from quarter to quarter in the form of realized or unrealized gains and losses. The three months and year-end 2018 results 
also include the impacts of lower rail car lease expenses as a result of the adoption of IFRS 16 as noted in the “Accounting Policies” 
section. 

Company’s disclosure under “Forward-Looking Information” included at the end of this MD&A. 

Cash flow summary – Continuing operations 

Discontinued operations – The results for discontinued operations include results from both the Canadian Truck Transportation and 
the U.S Environmental Services businesses. The Canadian Truck Transportation business earns margins by providing transportation 
and related services which includes providing hauling services for crude, condensate, sulfur, waste water and drilling fluids for many 
of the Western Canadian Sedimentary Basin leading oil and gas producers. The U.S. Environmental Services business earns margins 
by providing environmental and production services, such as emulsion hauling and treating, water hauling and disposal services and 
oilfield waste management services to the oil and gas industry. Accordingly, results have been impacted by the reduction and volatility 
in crude oil and other related commodity prices which has reduced production and exploration activities thus lowering available 
demand from these producers. However, the more recent gradual increase in the price of crude oil which has translated into slowly 
increasing activity and production coupled with the availability of other commodity hauling, such as sulphur, as well as the recovery 
of demand for the Company’s U.S. Environmental Service business as activity levels strengthened over the last year has provided 
support for the segment’s earnings. 

Adjusted  EBITDA  for  continuing,  discontinued,  and  combined  operations  is  presented  in  the  table  above  because  the  Company 
believes it facilitates investors’ use of operating performance comparisons from period to period and company to company by backing 
out  potential  differences  caused  by  variations  in  capital  structures  (affecting  relative  interest  expense  and  foreign  exchange 
differences on the Company’s long-term debt and Debentures), the book amortization of intangibles (affecting relative amortization 
expense) and the age and book value of property, plant and equipment (affecting relative depreciation expense). The Company also 
presents Adjusted EBITDA because it believes such measure is frequently used by securities analysts, investors and other interested 
parties as measures of financial performance. Adjusted EBITDA, as presented herein, is not a recognized measure under IFRS and 
should not be considered as an alternative to operating income or net income as measures of operating results or an alternative to 
cash flows as measures of liquidity. Adjusted EBITDA is defined as consolidated net income (loss) before interest expense, income 
taxes, depreciation, amortization, other non-cash expenses and charges deducted in determining consolidated net income (loss), 
including movement in the unrealized gains and losses on the Company’s financial instruments, stock based compensation expense, 
impairment of long-term assets and asset write-downs. It also removes the impact of foreign exchange movements in the Company’s 
U.S. dollar denominated long-term debt, debt extinguishment expenses and other adjustments that are considered unusual, non-
recurring or non-operating in nature. 

The Company’s calculation of Adjusted EBITDA may not be comparable to such calculations used by other companies. In addition, in 
evaluating Adjusted EBITDA, readers should be aware that in the future the Company may incur expenses similar to those eliminated 
in the presentation herein. 

LIQUIDITY AND CAPITAL RESOURCES 
Liquidity Sources 

The Company’s primary liquidity and capital resource needs are to fund ongoing capital expenditures, growth opportunities, and its 
dividend.  In  addition,  the  Company  must  service  its  debt,  including  interest  payments,  and  finance  working  capital  needs.  The 
Company’s short-term and long-term liquidity needs are met through cash flow from operations, its revolving credit facility, and debt 
and equity financings. 

As at December 31, 2018, the Company had a positive working capital position, with an available cash balance of $95.3 million, and 
the ability to utilize borrowings under the Revolving Credit Facility. Also, the anticipated proceeds from the sale of the Canadian Truck 
Transportation and non-core ESN businesses are expected to reduce debt and lower net debt to Adjusted EBITDA ratios which will 
allow the  Company to fund its ongoing capital  expenditures, debt  service requirements, dividend payments, and working capital 
needs.  Accordingly,  over  the  short-term  the  Company  expects  to  maintain  sufficient  liquidity  sources  to  fund  its  ongoing  capital 
expenditures, debt service requirements, dividend payments and working capital needs.  

Over the medium to long term, the Company’s ability to generate meaningful contributions from cash from operations combined 
with the Company’s extended maturity profile and low interest cost of the Company’s debt, will provide support for the Company’s 
funding of liquidity requirements.  

While the Company remains confident in its ability to execute these divestitures, there are no assurances that the timing, the amount 
of proceeds from the sale of non-core businesses and the execution of planned capital programs will occur as planned. Please refer 

The Company’s operating cash flow is generally impacted by the overall profitability within the Company’s segments, the Company’s 

ability to invoice and collect from customers in a timely manner and the Company’s ability to efficiently implement the Company’s 

The following table summarizes the Company’s sources and uses of funds for the years ended December 31, 2018 and 2017 from 

Years ended  

December 31 

20181 

20171 

growth strategy and manage costs.  

continuing operations: 

Statement of cash flows 

Cash flows provided by (used in): 

Operating activities ..................................................................................................................................  

  $        527,086          $ 

175,272 

Investing activities ....................................................................................................................................  

(214,502) 

(160,196) 

Financing activities ...................................................................................................................................  

$     (392,197)              $     (477,933) 

1. 

The current period results include the impacts from the adoption of new accounting standards as discussed on page 34. Comparative information has not been 

restated and, therefore, may not be comparable. 

Cash provided by operating activities 

Cash  provided  by  operating  activities  was  $527.1  million  in  the  year  ended  December  31,  2018,  compared  to  cash  provided  by 

operating activities of $175.3 million in the year ended December 31, 2017. The increase was primarily due to higher segment profit 

related to the Infrastructure and Wholesale segments (refer to the respective section in “Results of Continuing Operations” for more 

details). Additionally, cash from operating activities increased by $49.8 million during the year ended December 31, 2018, due to the 

adoption of IFRS 16 whereby the lease payments are classified as financing activities as noted in the “Accounting Policies” section. 

Furthermore, the increase was supported by cash generated by the working capital of $50.2 million in the current year compared to 

cash used to fund working capital of $27.3 million in the prior year, primarily driven by higher inventory purchases in the prior period.  

Cash provided by operating activities and working capital requirements for the Wholesale segment are strongly influenced by the 

amount of inventory purchased and subsequently held in storage, as well as by the commodity prices at which inventory is bought 

and sold. Commodity prices and inventory demand fluctuate over the course of the year in relation to general market forces and 

seasonal demand for certain products like propane, and, accordingly, working capital requirements related to inventory also fluctuate 

with changes in commodity prices and demand. The primary drivers of working capital requirements are the collection of amounts 

related to sales of products such as crude oil, NGLs, asphalt and other products and fees for services associated with the Company’s 

Logistics  and  Infrastructure  segments.  Offsetting  these  collections  are  payments  for  purchases  of  crude  oil  and  other  products, 

primarily within the Wholesale segment, and other expenses. Historically, the Wholesale segment has been the most variable with 

respect to generating cash flows and working capital due to the impact of crude oil price levels and the volatility that price changes 

and crude oil grade basis changes have on the cash flows and working capital requirements of this segment. Working capital is also 

influenced by the timing of certain financing activities related to the Revolver Credit Facility, interest payments on long-term debt, as 

well as payments of dividends and leases as discussed below under cash used in financing activities. 

Cash used in investing activities 

Cash used in investing activities was $214.5 million in the year ended December 31, 2018, compared to $160.2 million in the year 

ended December 31, 2017 and consists primarily of capital expenditures and acquisitions . For a summary of capital expenditures 

including acquisitions, see “Capital expenditures” discussion throughout this MD&A. 

      Gibson Energy Inc.                                                            24                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            23                                              Management’s Discussion and Analysis  
Gibson Energy

24 

Management’s Discussion and Analysis 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
profits from quarter to quarter in the form of realized or unrealized gains and losses. The three months and year-end 2018 results 

Company’s disclosure under “Forward-Looking Information” included at the end of this MD&A. 

also include the impacts of lower rail car lease expenses as a result of the adoption of IFRS 16 as noted in the “Accounting Policies” 

Cash flow summary – Continuing operations 

section. 

The Company’s operating cash flow is generally impacted by the overall profitability within the Company’s segments, the Company’s 
ability to invoice and collect from customers in a timely manner and the Company’s ability to efficiently implement the Company’s 
growth strategy and manage costs.  

The following table summarizes the Company’s sources and uses of funds for the years ended December 31, 2018 and 2017 from 
continuing operations: 

Years ended  
December 31 

20181 

20171 

Statement of cash flows 
Cash flows provided by (used in): 
Operating activities ..................................................................................................................................  
Investing activities ....................................................................................................................................  
Financing activities ...................................................................................................................................  

  $        527,086          $ 
(214,502) 

175,272 
(160,196) 
$     (392,197)              $     (477,933) 

1. 

The current period results include the impacts from the adoption of new accounting standards as discussed on page 34. Comparative information has not been 
restated and, therefore, may not be comparable. 

parties as measures of financial performance. Adjusted EBITDA, as presented herein, is not a recognized measure under IFRS and 

Cash provided by operating activities 

Cash  provided  by  operating  activities  was  $527.1  million  in  the  year  ended  December  31,  2018,  compared  to  cash  provided  by 
operating activities of $175.3 million in the year ended December 31, 2017. The increase was primarily due to higher segment profit 
related to the Infrastructure and Wholesale segments (refer to the respective section in “Results of Continuing Operations” for more 
details). Additionally, cash from operating activities increased by $49.8 million during the year ended December 31, 2018, due to the 
adoption of IFRS 16 whereby the lease payments are classified as financing activities as noted in the “Accounting Policies” section. 
Furthermore, the increase was supported by cash generated by the working capital of $50.2 million in the current year compared to 
cash used to fund working capital of $27.3 million in the prior year, primarily driven by higher inventory purchases in the prior period.  

Cash provided by operating activities and working capital requirements for the Wholesale segment are strongly influenced by the 
amount of inventory purchased and subsequently held in storage, as well as by the commodity prices at which inventory is bought 
and sold. Commodity prices and inventory demand fluctuate over the course of the year in relation to general market forces and 
seasonal demand for certain products like propane, and, accordingly, working capital requirements related to inventory also fluctuate 
with changes in commodity prices and demand. The primary drivers of working capital requirements are the collection of amounts 
related to sales of products such as crude oil, NGLs, asphalt and other products and fees for services associated with the Company’s 
Logistics  and  Infrastructure  segments.  Offsetting  these  collections  are  payments  for  purchases  of  crude  oil  and  other  products, 
primarily within the Wholesale segment, and other expenses. Historically, the Wholesale segment has been the most variable with 
respect to generating cash flows and working capital due to the impact of crude oil price levels and the volatility that price changes 
and crude oil grade basis changes have on the cash flows and working capital requirements of this segment. Working capital is also 
influenced by the timing of certain financing activities related to the Revolver Credit Facility, interest payments on long-term debt, as 
well as payments of dividends and leases as discussed below under cash used in financing activities. 

Transportation and non-core ESN businesses are expected to reduce debt and lower net debt to Adjusted EBITDA ratios which will 

Cash used in investing activities 

Cash used in investing activities was $214.5 million in the year ended December 31, 2018, compared to $160.2 million in the year 
ended December 31, 2017 and consists primarily of capital expenditures and acquisitions . For a summary of capital expenditures 
including acquisitions, see “Capital expenditures” discussion throughout this MD&A. 

Discontinued operations – The results for discontinued operations include results from both the Canadian Truck Transportation and 

the U.S Environmental Services businesses. The Canadian Truck Transportation business earns margins by providing transportation 

and related services which includes providing hauling services for crude, condensate, sulfur, waste water and drilling fluids for many 

of the Western Canadian Sedimentary Basin leading oil and gas producers. The U.S. Environmental Services business earns margins 

by providing environmental and production services, such as emulsion hauling and treating, water hauling and disposal services and 

oilfield waste management services to the oil and gas industry. Accordingly, results have been impacted by the reduction and volatility 

in crude oil and other related commodity prices which has reduced production and exploration activities thus lowering available 

demand from these producers. However, the more recent gradual increase in the price of crude oil which has translated into slowly 

increasing activity and production coupled with the availability of other commodity hauling, such as sulphur, as well as the recovery 

of demand for the Company’s U.S. Environmental Service business as activity levels strengthened over the last year has provided 

support for the segment’s earnings. 

Adjusted  EBITDA  for  continuing,  discontinued,  and  combined  operations  is  presented  in  the  table  above  because  the  Company 

believes it facilitates investors’ use of operating performance comparisons from period to period and company to company by backing 

out  potential  differences  caused  by  variations  in  capital  structures  (affecting  relative  interest  expense  and  foreign  exchange 

differences on the Company’s long-term debt and Debentures), the book amortization of intangibles (affecting relative amortization 

expense) and the age and book value of property, plant and equipment (affecting relative depreciation expense). The Company also 

presents Adjusted EBITDA because it believes such measure is frequently used by securities analysts, investors and other interested 

should not be considered as an alternative to operating income or net income as measures of operating results or an alternative to 

cash flows as measures of liquidity. Adjusted EBITDA is defined as consolidated net income (loss) before interest expense, income 

taxes, depreciation, amortization, other non-cash expenses and charges deducted in determining consolidated net income (loss), 

including movement in the unrealized gains and losses on the Company’s financial instruments, stock based compensation expense, 

impairment of long-term assets and asset write-downs. It also removes the impact of foreign exchange movements in the Company’s 

U.S. dollar denominated long-term debt, debt extinguishment expenses and other adjustments that are considered unusual, non-

recurring or non-operating in nature. 

The Company’s calculation of Adjusted EBITDA may not be comparable to such calculations used by other companies. In addition, in 

evaluating Adjusted EBITDA, readers should be aware that in the future the Company may incur expenses similar to those eliminated 

in the presentation herein. 

LIQUIDITY AND CAPITAL RESOURCES 

Liquidity Sources 

The Company’s primary liquidity and capital resource needs are to fund ongoing capital expenditures, growth opportunities, and its 

dividend.  In  addition,  the  Company  must  service  its  debt,  including  interest  payments,  and  finance  working  capital  needs.  The 

Company’s short-term and long-term liquidity needs are met through cash flow from operations, its revolving credit facility, and debt 

and equity financings. 

As at December 31, 2018, the Company had a positive working capital position, with an available cash balance of $95.3 million, and 

the ability to utilize borrowings under the Revolving Credit Facility. Also, the anticipated proceeds from the sale of the Canadian Truck 

allow the  Company to fund its ongoing capital  expenditures, debt  service requirements, dividend payments, and working capital 

needs.  Accordingly,  over  the  short-term  the  Company  expects  to  maintain  sufficient  liquidity  sources  to  fund  its  ongoing  capital 

expenditures, debt service requirements, dividend payments and working capital needs.  

Over the medium to long term, the Company’s ability to generate meaningful contributions from cash from operations combined 

with the Company’s extended maturity profile and low interest cost of the Company’s debt, will provide support for the Company’s 

funding of liquidity requirements.  

While the Company remains confident in its ability to execute these divestitures, there are no assurances that the timing, the amount 

of proceeds from the sale of non-core businesses and the execution of planned capital programs will occur as planned. Please refer 

      Gibson Energy Inc.                                                            23                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            24                                              Management’s Discussion and Analysis  

25 

Management’s Discussion and Analysis

Gibson Energy 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Cash used in financing activities 

Capital structure 

Cash used in financing activities was $392.2 million in year ended December 31, 2018 compared to cash used in financing activities 
of $477.9 million in the year ended December 31, 2017. The decrease was primarily due to lower net interest costs of $68.9 million 
in the year ended December 31, 2018 compared $87.2 million in the year ended December 31, 2017, finance lease payments of $49.8 
million that are classified as financing activities due to the adoption of IFRS 16 effective January 1, 2018 (as noted in the “Accounting 
Policies” section), and a net repayment on Revolving Credit Facility of $84.7 million in the year ended December 31, 2018 compared 
to a net repayment on the Company’s borrowings of $203.4 million in the year ended December 31, 2017. Dividend payments were 
fairly consistent year over year. 

Capital expenditures and acquisitions 

The following table summarizes growth and replacement capital expenditures for the years ended December 31, 2018 and 2017: 

Growth capital (1) .......................................................................................................................................  
Replacement capital (2) ..............................................................................................................................  
Acquisitions (3) ...........................................................................................................................................  
Total ..........................................................................................................................................................  

  $ 

  $ 

Years ended  
December 31 
2018 
221,198 
25,225 
80,844 
327,267 

2017 
  $  151,154 
20,901 
- 

  $  172,055   

1.  Growth  capital  expenditures  in  the  year  ended  December  31,  2018  include  Corporate  and  discontinued  operations  expenditures  of  $0.8  million  $3.8  million 
compared to $3.3 million and $6.0 million in the years ended December 31, 2017, respectively. These expenditures mainly relate to growth capital expenditure 
costs associated with the Company’s information and operational systems. The remainder of the growth capital expenditures have been discussed in continuing 
operations earlier in the MD&A.  

2. 

Replacement capital expenditures in the years ended December 31, 2018 include Corporate and discontinued operations of $3.1 million and $1.6 million compared 
to $2.8 million and $7.3 million in the years ended December 31, 2017, respectively. These expenditures mainly relate to replacement costs associated with the 
Company’s information and operational systems. The remainder of the replacement capital expenditures have been discussed in continuing operations earlier in 
the MD&A.  

3. 

Acquisitions include the purchase of a pipeline gathering network within the U.S. Infrastructure business and the purchase of the remaining interests in the Plato 
Pipeline. 

2019 Planned capital expenditures 

On December 4, 2018, the Company announced the approval of the 2019 growth capital expenditure budget in the range of $200 
million  to  $250  million  and  an  additional  $30  to  $35  million  allocated  to  replacement  capital  expenditures.  While  the  Company 
anticipates that these planned capital expenditures will occur, certain capital projects are subject to general  economic, financial, 
competitive,  legislative,  regulatory  and  other  factors,  some  of  which  are  beyond  the  Company’s  control  and  could  impact  the 
Company’s ability to complete such activities as planned. 

Management’s Discussion and Analysis 

      Gibson Energy Inc.                                                            25                                              Management’s Discussion and Analysis  
Gibson Energy

26 

As at  

December 31,  

December 31, 

2018 

2017 

Revolving Credit Facility ..........................................................................................................................  

 $       150,000

  $     230,180              

$300 million 5.375% Notes due July 15, 2022 .........................................................................................  

$600 million 5.25% Notes due July 15, 2024 ...........................................................................................  

Unamortized issue discount and debt issue costs ...................................................................................  

$100 million Debentures 5.25% due July 15, 2021 (liability component) (1) ............................................  

Lease liability ...........................................................................................................................................  

Total debt outstanding ............................................................................................................................  

Cash and cash equivalents .......................................................................................................................  

Net debt ..................................................................................................................................................  

Total share capital (including Debentures – equity component) ............................................................  

300,000

600,000

(10,422)

89,765

109,071

1,238,414

(95,301)

1,143,113

1,962,169

300,000 

600,000 

(12,061) 

89,765

-

1,207,884

(32,138)

1,175,746

1,939,126

Total capital .............................................................................................................................................  

  $  3,105,282

  $     3,114,872 

1. 

The Debentures are included in the above total capital calculation in accordance with the Company’s view of its capital structure which includes shareholders’ 

equity, long-term debt, the Debentures, the Revolving Credit Facility, lease liabilities and working capital. The Debentures and associated interest payments 

are excluded from the definition of net debt included in the consolidated senior and total debt covenant ratios as well as the consolidated interest coverage 

covenant ratio. 

Notes 

During 2017, the Company completed a tender offer on its Retired Notes and also issued the $600 million 5.25% Notes. The indentures 

governing  the  terms  of  the  $600  million  5.25%  Notes  and  the  $300  million  5.375%  notes  (collectively  “Notes”)  including  the 

supplemental indenture thereto, contain certain redemption options whereby the Company can redeem all or part of the Notes at 

prices set forth in the applicable Indenture from proceeds of an equity offering or on the dates specified in the Indentures. In addition, 

the holders of Notes have the right to require the Company to redeem the Notes at the redemption prices set forth in the respective 

indebtedness in the event of a change in control or in the event certain asset sale proceeds are not re-invested in the time and manner 

specified in the applicable Indenture. 

Debentures  

On  June  2,  2016,  the  Company  issued  $100.0  million  aggregate  principal  amount  of  debentures  (the  “Debentures”)  at  a price  of 

$1,000 per Debenture for net proceeds of approximately $96.3 million, including debt issuance costs of $3.7 million. The Debentures, 

issued at par, bear interest at a rate of 5.25% per annum, payable semi-annually on January 15 and July 15 in each year commencing 

January 15, 2017, mature on July 15, 2021, and may be redeemed, in certain circumstances, on or after July 15, 2019. The Debentures 

are convertible at the holder's option into common shares at any time prior to the earlier of July 15, 2021 and the business day 

immediately preceding the date fixed for redemption by the Company at a conversion price of $21.65 per common share, being a 

ratio of approximately 46.1894 common shares per $1,000 principal amount of the Debenture. The Debentures are subordinated to 

the Company's senior indebtedness.  

Credit facility 

The Revolving Credit Facility, available to provide financing for working capital, fund capital expenditures and other general corporate 

purposes, has an extendible term of five years, expiring on March 31, 2023. The Revolving Credit Facility permits letters of credit, 

swingline loans and borrowings in Canadian dollars and U.S. dollars. Borrowings under the Revolving Credit Facility bear interest at a 

rate equal to Canadian Prime Rate or U.S. Base Rate or U.S. LIBOR or Canadian Bankers Acceptance Rate, as the case may be, plus an 

applicable margin. The applicable margin for borrowings under the Revolving Credit Facility is subject to step up and step down based 

on the Company’s total debt leverage ratio. In addition, the Company must pay standby fees on the unused portion of the Revolving 

Credit Facility and customary letter of credit fees equal to the applicable margins determined in a manner similar to the interest. In 

addition, the Company has three bilateral demand letter of credit facilities totaling $150.0 million. The Company had $150.0 million 

drawn on its $560.0 million Revolving Credit Facility as of December 31, 2018 and had issued letters of credit totaling $70.9 million 

under its bilateral demand letter of credit facilities as at December 31, 2018.  

      Gibson Energy Inc.                                                            26                                              Management’s Discussion and Analysis  

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Cash used in financing activities 

Capital structure 

As at  

December 31,  
2018 

December 31, 
2017 

Revolving Credit Facility ..........................................................................................................................  
$300 million 5.375% Notes due July 15, 2022 .........................................................................................  
$600 million 5.25% Notes due July 15, 2024 ...........................................................................................  
Unamortized issue discount and debt issue costs ...................................................................................  
$100 million Debentures 5.25% due July 15, 2021 (liability component) (1) ............................................  
Lease liability ...........................................................................................................................................  
Total debt outstanding ............................................................................................................................  
Cash and cash equivalents .......................................................................................................................  
Net debt ..................................................................................................................................................  
Total share capital (including Debentures – equity component) ............................................................  
Total capital .............................................................................................................................................  

 $       150,000
300,000
600,000
(10,422)
89,765
109,071
1,238,414
(95,301)
1,143,113
1,962,169
  $  3,105,282

  $     230,180              
300,000 
600,000 
(12,061) 
89,765
-
1,207,884
(32,138)
1,175,746
1,939,126
  $     3,114,872 

1. 

The Debentures are included in the above total capital calculation in accordance with the Company’s view of its capital structure which includes shareholders’ 
equity, long-term debt, the Debentures, the Revolving Credit Facility, lease liabilities and working capital. The Debentures and associated interest payments 
are excluded from the definition of net debt included in the consolidated senior and total debt covenant ratios as well as the consolidated interest coverage 
covenant ratio. 

Notes 

During 2017, the Company completed a tender offer on its Retired Notes and also issued the $600 million 5.25% Notes. The indentures 
governing  the  terms  of  the  $600  million  5.25%  Notes  and  the  $300  million  5.375%  notes  (collectively  “Notes”)  including  the 
supplemental indenture thereto, contain certain redemption options whereby the Company can redeem all or part of the Notes at 
prices set forth in the applicable Indenture from proceeds of an equity offering or on the dates specified in the Indentures. In addition, 
the holders of Notes have the right to require the Company to redeem the Notes at the redemption prices set forth in the respective 
indebtedness in the event of a change in control or in the event certain asset sale proceeds are not re-invested in the time and manner 
specified in the applicable Indenture. 

Debentures  

On  June  2,  2016,  the  Company  issued  $100.0  million  aggregate  principal  amount  of  debentures  (the  “Debentures”)  at  a price  of 
$1,000 per Debenture for net proceeds of approximately $96.3 million, including debt issuance costs of $3.7 million. The Debentures, 
issued at par, bear interest at a rate of 5.25% per annum, payable semi-annually on January 15 and July 15 in each year commencing 
January 15, 2017, mature on July 15, 2021, and may be redeemed, in certain circumstances, on or after July 15, 2019. The Debentures 
are convertible at the holder's option into common shares at any time prior to the earlier of July 15, 2021 and the business day 
immediately preceding the date fixed for redemption by the Company at a conversion price of $21.65 per common share, being a 
ratio of approximately 46.1894 common shares per $1,000 principal amount of the Debenture. The Debentures are subordinated to 
the Company's senior indebtedness.  

Credit facility 

The Revolving Credit Facility, available to provide financing for working capital, fund capital expenditures and other general corporate 
purposes, has an extendible term of five years, expiring on March 31, 2023. The Revolving Credit Facility permits letters of credit, 
swingline loans and borrowings in Canadian dollars and U.S. dollars. Borrowings under the Revolving Credit Facility bear interest at a 
rate equal to Canadian Prime Rate or U.S. Base Rate or U.S. LIBOR or Canadian Bankers Acceptance Rate, as the case may be, plus an 
applicable margin. The applicable margin for borrowings under the Revolving Credit Facility is subject to step up and step down based 
on the Company’s total debt leverage ratio. In addition, the Company must pay standby fees on the unused portion of the Revolving 
Credit Facility and customary letter of credit fees equal to the applicable margins determined in a manner similar to the interest. In 
addition, the Company has three bilateral demand letter of credit facilities totaling $150.0 million. The Company had $150.0 million 
drawn on its $560.0 million Revolving Credit Facility as of December 31, 2018 and had issued letters of credit totaling $70.9 million 
under its bilateral demand letter of credit facilities as at December 31, 2018.  

Cash used in financing activities was $392.2 million in year ended December 31, 2018 compared to cash used in financing activities 

of $477.9 million in the year ended December 31, 2017. The decrease was primarily due to lower net interest costs of $68.9 million 

in the year ended December 31, 2018 compared $87.2 million in the year ended December 31, 2017, finance lease payments of $49.8 

million that are classified as financing activities due to the adoption of IFRS 16 effective January 1, 2018 (as noted in the “Accounting 

Policies” section), and a net repayment on Revolving Credit Facility of $84.7 million in the year ended December 31, 2018 compared 

to a net repayment on the Company’s borrowings of $203.4 million in the year ended December 31, 2017. Dividend payments were 

fairly consistent year over year. 

Capital expenditures and acquisitions 

The following table summarizes growth and replacement capital expenditures for the years ended December 31, 2018 and 2017: 

Growth capital (1) .......................................................................................................................................  

  $ 

221,198 

  $  151,154 

Replacement capital (2) ..............................................................................................................................  

Acquisitions (3) ...........................................................................................................................................  

25,225 

80,844 

20,901 

- 

Total ..........................................................................................................................................................  

  $ 

327,267 

  $  172,055   

Years ended  

December 31 

2018 

2017 

1.  Growth  capital  expenditures  in  the  year  ended  December  31,  2018  include  Corporate  and  discontinued  operations  expenditures  of  $0.8  million  $3.8  million 

compared to $3.3 million and $6.0 million in the years ended December 31, 2017, respectively. These expenditures mainly relate to growth capital expenditure 

costs associated with the Company’s information and operational systems. The remainder of the growth capital expenditures have been discussed in continuing 

operations earlier in the MD&A.  

2. 

Replacement capital expenditures in the years ended December 31, 2018 include Corporate and discontinued operations of $3.1 million and $1.6 million compared 

to $2.8 million and $7.3 million in the years ended December 31, 2017, respectively. These expenditures mainly relate to replacement costs associated with the 

Company’s information and operational systems. The remainder of the replacement capital expenditures have been discussed in continuing operations earlier in 

3. 

Acquisitions include the purchase of a pipeline gathering network within the U.S. Infrastructure business and the purchase of the remaining interests in the Plato 

the MD&A.  

Pipeline. 

2019 Planned capital expenditures 

On December 4, 2018, the Company announced the approval of the 2019 growth capital expenditure budget in the range of $200 

million  to  $250  million  and  an  additional  $30  to  $35  million  allocated  to  replacement  capital  expenditures.  While  the  Company 

anticipates that these planned capital expenditures will occur, certain capital projects are subject to general  economic, financial, 

competitive,  legislative,  regulatory  and  other  factors,  some  of  which  are  beyond  the  Company’s  control  and  could  impact  the 

Company’s ability to complete such activities as planned. 

      Gibson Energy Inc.                                                            25                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            26                                              Management’s Discussion and Analysis  

27 

Management’s Discussion and Analysis

Gibson Energy 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
The Revolving Credit Facility contains certain covenants, including financial covenants requiring the Company to maintain ratios of 
maximum consolidated senior and total debt leverage as well as to maintain a minimum interest coverage ratio. Effective March 31, 
2018, the Company amended certain covenants related to its Revolving Credit Facility including, amongst other revisions, revising the 
maximum consolidated senior and the maximum consolidated total debt leverage ratios to 4.85 to 1.0 for the 2018 fiscal year, 4.5 to 
1.0 for 2019 fiscal year and 4.0 to 1.0 thereafter. Furthermore, the maturity date of the Revolving Credit Facility was extended from 
March 2022 to March 2023.  

In addition, the Company is also required to maintain a minimum interest coverage ratio of no less than 2.5 to 1.0. The consolidated 
senior debt ratio represents the ratio of all senior debt obligations to Adjusted EBITDA. The consolidated total debt ratio represents 
the  ratio  of  total  debt  to  Adjusted  EBITDA.  The  consolidated  interest  coverage  ratio  represents  the  ratio  of  Adjusted  EBITDA  to 
consolidated cash interest expense.  

As at December 31, 2018, the Company was in compliance with the financial ratios with the senior debt leverage ratio at 2.3 to 1.0, 
total debt leverage ratio at 2.3 to 1.0, and the interest coverage ratio at 6.7 to 1.0. If the Company fails to comply with the financial 
covenants, the lenders may declare an event of default. An event of default resulting from a breach of a financial covenant may result, 
at the option of lenders holding a majority of the loans, in an acceleration of repayment of the principal and interest outstanding and 
a termination of the Revolving Credit Facility. Both the leverage ratio and interest coverage ratio are based on calculations using 
adjusted EBITDA calculated in accordance with the Company’s debt agreements. See “Accounting Policies” section for discussion on 
adoption of new accounting standard which did not have a material impact on the covenants calculations.  

The Notes and the Revolving Credit Facility contain non-financial covenants that restrict, subject to certain thresholds, some of the 
Company’s activities, including the Company’s ability to dispose of assets, incur additional debt, pay dividends, create liens, make 
investments and engage in specified transactions with affiliates. The Notes and the Revolving Credit Facility also contain customary 
events of default, including defaults based on events of bankruptcy and insolvency, non-payment of principal, interest or fees when 
due, breach of covenants, change in control and material inaccuracy of representations and warranties, subject to specified grace 
periods. As of December 31, 2018, the Company was in compliance with all of its covenants under the Notes and the Revolving Credit 
Facility. 

Dividends 

The Company is currently paying quarterly dividends to holders of common shares. The amount and timing of any future dividends 
payable by Gibson will be at the discretion of the Board and to be established on the basis of, among other things, Gibson’s earnings, 
financial requirements for operations, the satisfaction of a solvency calculation and the terms of the Company’s debt agreements. In 
addition, in connection with Company’s dividend policy, after each fiscal year end the Board will formally review the annual dividend 
amount. During the year ended December 31, 2018, the Board declares dividends of $1.32 per share.  

Distributable cash flow  

Distributable cash flow is not a standard measure under IFRS and, therefore, may not be comparable to similar measures reported 
by other entities. Distributable cash flow from continuing and combined operations is used to assess the level of cash flow generated 
and  to  evaluate  the  adequacy  of  internally  generated  cash  flow  to  fund  dividends  and  is  frequently  used  by  securities  analysts, 
investors and other interested parties. Changes in non-cash working capital are excluded from the determination of distributable 
cash  flow  because  they  are  primarily  the  result  of  fluctuations  in  product  inventories  or  other  temporary  changes.  Replacement 
capital  expenditures  are  deducted  from  distributable  cash  flow  as  there  is  an  ongoing  requirement  to  incur  these  types  of 
expenditures. Lease payments are also deducted for the period starting January 1, 2018 due to the adoption of IFRS 16 as noted in 
the “Accounting Policies” section. The Company may deduct or include additional items in its calculation of distributable cash flow. 
These items would generally, but not necessarily, be items of an unusual, non-recurring, or non-operating in nature. In 2017, the 
Company reflected non-recurring items relating to severance costs in distributable cash flow to approximate the internally generated 
cash flow available to the Company within its normal operating cycle. The Company has provided the distributable cash flow from 
combined operations on a trailing twelve-month basis to reflect the total cash flow available to fund dividends which includes cash 
available from discontinued operations. 

Management’s Discussion and Analysis 

      Gibson Energy Inc.                                                            27                                              Management’s Discussion and Analysis  
Gibson Energy

28 

The following is a reconciliation of distributable cash flow from combined operations to its most closely related IFRS measure, cash 

flow from operating activities for the years ended December 31, 2018 and 2017 and three months ended December 31, 2018 and 

2017. 

Continuing operations 

Adjustments: 

Years ended December 31 

2018 

2017  

(restated)1

$     175,272

27,325

(21,011)

(73,939)

-

34,016

19,086

2017 

(restated)1

$   197,379

52,147

(28,291)

(73,939)

- 

          3,608 

19,086

10,503

Cash flow from operating activities ....................................................................  

$     527,086 

Changes in non-cash working capital ..............................................................  

Replacement capital ........................................................................................  

Cash interest expense, including capitalized interest .....................................  

Lease payments (2) ...........................................................................................  

Current income tax ..........................................................................................  

Other charges (3) ..............................................................................................  

(64,298) 

(25,225) 

(68,474) 

(49,785) 

(60,178) 

- 

Distributable cash flow from continuing operations ..........................................  

       $    259,126              

       $     160,749              

Years ended December 31 

2018 

Combined operations  

Adjustments: 

Combined cash flow from operating activities ...................................................  

$    563,738 

Combined changes in non-cash working capital .............................................  

Combined replacement capital .......................................................................  

Cash interest expense, including capitalized interest .....................................  

Lease payments (2) ...........................................................................................  

Current income tax ..........................................................................................  

Other charges (3) ..............................................................................................  

Working capital adjustment (4) ........................................................................  

(69,489) 

(26,800) 

(68,474) 

(52,870) 

(63,588) 

- 

- 

Distributable cash flow from combined operations ...........................................  

$     282,517         

$     180,493        

Dividends declared to shareholders ........................................................................  

$  190,326 

$  188,470

Cash flow from operating activities ....................................................................  

$         262,044

     $       37,371          

Continuing operations 

Adjustments: 

Changes in non-cash working capital ..............................................................  

Replacement capital ........................................................................................  

Cash interest expense, including capitalized interest .....................................  

Lease payments (2) ...........................................................................................  

Current income tax ..........................................................................................  

Other charges (3) ..............................................................................................  

Quarter ended December 31 

2018  

2017 

(restated)1 

(123,954)

(9,604)

(16,713)

(11,187)

(22,396)

-

7,070 

(9,097) 

(17,398) 

- 

14,149 

18,086 

Distributable cash flow from continuing operations ..........................................  

              $         78,190                 

$      50,181            

      Gibson Energy Inc.                                                            28                                              Management’s Discussion and Analysis  

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
The Revolving Credit Facility contains certain covenants, including financial covenants requiring the Company to maintain ratios of 

maximum consolidated senior and total debt leverage as well as to maintain a minimum interest coverage ratio. Effective March 31, 

2018, the Company amended certain covenants related to its Revolving Credit Facility including, amongst other revisions, revising the 

maximum consolidated senior and the maximum consolidated total debt leverage ratios to 4.85 to 1.0 for the 2018 fiscal year, 4.5 to 

1.0 for 2019 fiscal year and 4.0 to 1.0 thereafter. Furthermore, the maturity date of the Revolving Credit Facility was extended from 

March 2022 to March 2023.  

In addition, the Company is also required to maintain a minimum interest coverage ratio of no less than 2.5 to 1.0. The consolidated 

senior debt ratio represents the ratio of all senior debt obligations to Adjusted EBITDA. The consolidated total debt ratio represents 

the  ratio  of  total  debt  to  Adjusted  EBITDA.  The  consolidated  interest  coverage  ratio  represents  the  ratio  of  Adjusted  EBITDA  to 

consolidated cash interest expense.  

As at December 31, 2018, the Company was in compliance with the financial ratios with the senior debt leverage ratio at 2.3 to 1.0, 

total debt leverage ratio at 2.3 to 1.0, and the interest coverage ratio at 6.7 to 1.0. If the Company fails to comply with the financial 

covenants, the lenders may declare an event of default. An event of default resulting from a breach of a financial covenant may result, 

at the option of lenders holding a majority of the loans, in an acceleration of repayment of the principal and interest outstanding and 

a termination of the Revolving Credit Facility. Both the leverage ratio and interest coverage ratio are based on calculations using 

adjusted EBITDA calculated in accordance with the Company’s debt agreements. See “Accounting Policies” section for discussion on 

adoption of new accounting standard which did not have a material impact on the covenants calculations.  

The Notes and the Revolving Credit Facility contain non-financial covenants that restrict, subject to certain thresholds, some of the 

Company’s activities, including the Company’s ability to dispose of assets, incur additional debt, pay dividends, create liens, make 

investments and engage in specified transactions with affiliates. The Notes and the Revolving Credit Facility also contain customary 

events of default, including defaults based on events of bankruptcy and insolvency, non-payment of principal, interest or fees when 

due, breach of covenants, change in control and material inaccuracy of representations and warranties, subject to specified grace 

periods. As of December 31, 2018, the Company was in compliance with all of its covenants under the Notes and the Revolving Credit 

Facility. 

Dividends 

The Company is currently paying quarterly dividends to holders of common shares. The amount and timing of any future dividends 

payable by Gibson will be at the discretion of the Board and to be established on the basis of, among other things, Gibson’s earnings, 

financial requirements for operations, the satisfaction of a solvency calculation and the terms of the Company’s debt agreements. In 

addition, in connection with Company’s dividend policy, after each fiscal year end the Board will formally review the annual dividend 

amount. During the year ended December 31, 2018, the Board declares dividends of $1.32 per share.  

Distributable cash flow  

Distributable cash flow is not a standard measure under IFRS and, therefore, may not be comparable to similar measures reported 

by other entities. Distributable cash flow from continuing and combined operations is used to assess the level of cash flow generated 

and  to  evaluate  the  adequacy  of  internally  generated  cash  flow  to  fund  dividends  and  is  frequently  used  by  securities  analysts, 

investors and other interested parties. Changes in non-cash working capital are excluded from the determination of distributable 

cash  flow  because  they  are  primarily  the  result  of  fluctuations  in  product  inventories  or  other  temporary  changes.  Replacement 

capital  expenditures  are  deducted  from  distributable  cash  flow  as  there  is  an  ongoing  requirement  to  incur  these  types  of 

expenditures. Lease payments are also deducted for the period starting January 1, 2018 due to the adoption of IFRS 16 as noted in 

the “Accounting Policies” section. The Company may deduct or include additional items in its calculation of distributable cash flow. 

These items would generally, but not necessarily, be items of an unusual, non-recurring, or non-operating in nature. In 2017, the 

Company reflected non-recurring items relating to severance costs in distributable cash flow to approximate the internally generated 

cash flow available to the Company within its normal operating cycle. The Company has provided the distributable cash flow from 

combined operations on a trailing twelve-month basis to reflect the total cash flow available to fund dividends which includes cash 

available from discontinued operations. 

      Gibson Energy Inc.                                                            27                                              Management’s Discussion and Analysis  

The following is a reconciliation of distributable cash flow from combined operations to its most closely related IFRS measure, cash 
flow from operating activities for the years ended December 31, 2018 and 2017 and three months ended December 31, 2018 and 
2017. 

Continuing operations 

Cash flow from operating activities ....................................................................  
Adjustments: 

Changes in non-cash working capital ..............................................................  
Replacement capital ........................................................................................  
Cash interest expense, including capitalized interest .....................................  
Lease payments (2) ...........................................................................................  
Current income tax ..........................................................................................  
Other charges (3) ..............................................................................................  
Distributable cash flow from continuing operations ..........................................  

Years ended December 31 

2018 

$     527,086 

(64,298) 
(25,225) 
(68,474) 
(49,785) 
(60,178) 
- 

       $    259,126              

2017  
(restated)1
$     175,272

27,325
(21,011)
(73,939)
-
34,016
19,086
       $     160,749              

Combined operations  

Combined cash flow from operating activities ...................................................  
Adjustments: 

Combined changes in non-cash working capital .............................................  
Combined replacement capital .......................................................................  
Cash interest expense, including capitalized interest .....................................  
Lease payments (2) ...........................................................................................  
Current income tax ..........................................................................................  
Other charges (3) ..............................................................................................  
Working capital adjustment (4) ........................................................................  
Distributable cash flow from combined operations ...........................................  

Years ended December 31 

2018 

$    563,738 

(69,489) 
(26,800) 
(68,474) 
(52,870) 
(63,588) 
- 
- 

$     282,517         

2017 
(restated)1
$   197,379

52,147
(28,291)
(73,939)
- 
          3,608 
19,086
10,503
$     180,493        

Dividends declared to shareholders ........................................................................  

$  190,326 

$  188,470

Continuing operations 

Cash flow from operating activities ....................................................................  
Adjustments: 

Changes in non-cash working capital ..............................................................  
Replacement capital ........................................................................................  
Cash interest expense, including capitalized interest .....................................  
Lease payments (2) ...........................................................................................  
Current income tax ..........................................................................................  
Other charges (3) ..............................................................................................  
Distributable cash flow from continuing operations ..........................................  

Quarter ended December 31 

2018  

$         262,044

2017 
(restated)1 
     $       37,371          

(123,954)
(9,604)
(16,713)
(11,187)
(22,396)
-

              $         78,190                 

7,070 
(9,097) 
(17,398) 
- 
14,149 
18,086 
$      50,181            

Gibson Energy 

      Gibson Energy Inc.                                                            28                                              Management’s Discussion and Analysis  

Management’s Discussion and Analysis

29 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Combined operations  

Combined cash flow from operating activities ............................................................  
Adjustments: 

Combined changes in non-cash working capital ......................................................  
Combined replacement capital ................................................................................  
Cash interest expense, including capitalized interest ..............................................  
Lease payments (2) ....................................................................................................  
Current income tax ...................................................................................................  
Other charges (3) .......................................................................................................  
Working capital adjustment (4) .................................................................................  
Distributable cash flow from combined operations ....................................................  

Quarter ended December 31 

2018 

$   272,337 

    (127,628) 
(9,676) 
(16,713) 
(11,588) 
(22,609) 
- 
- 

$       84,123             

2017 
(restated)1
45,312
$ 

13,564
(10,660)
(17,398)
-
14,149
18,086
10,503
$       73,556

Dividends declared to shareholders ............................................................................  

$ 

47,704 

$ 

47,257

1.  During the third quarter of 2018, the Company revised its distributable cash flow calculations whereby income taxes were adjusted to include the impact of current 
income tax expense (recovery), instead of cash taxes paid (refunds). In management’s view the revised calculation provides a more representative measure of 
distributable cash flow to the users of the MD&A. 

2.  Due to the adoption of IFRS 16, lease payments are shown within cash flow from financing activity effective January 1, 2018. Therefore, distributable cash flow 

has been adjusted to deduct lease payments for the period starting January 1, 2018 to make the calculations consistent with the prior periods. 

3. 

4. 

Represents restructuring, severance and executive payroll related costs incurred during the respective periods. 

Contingencies 

Represents a one-time adjustment related to working capital at the close of Industrial Propane segment sale whereby $10.5 million cash balance was required to 
be left in the businesses prior to close and was repaid back to the Company as part of the sale proceeds. Absent this requirement, the cash flow from operations 
would have been higher and cash flow from investing activity would be lower by the same amount. 

Dividends declared in the twelve months ended December 31, 2018 were $190.3 million, of which the entire amount was paid in 
cash. In the twelve months ended December 31, 2018, dividends declared represented 67% of the combined distributable cash flow 
generated.  

Management’s Discussion and Analysis 

      Gibson Energy Inc.                                                            29                                              Management’s Discussion and Analysis  
Gibson Energy

30 

Contractual obligations and contingencies 

contracts and contingent commitments: 

The following table presents, at December 31, 2018, the Company’s obligations and commitments to make future payments under 

Long-term debt  .......................................................................  

   $   900,000 

 $ 

 $ 

 $  300,000 

 $ 

600,000 

Convertible debentures ..........................................................  

Interest payments on long-term debt and Debentures ..........  

Credit facilities ........................................................................  

Lease liabilities and other commitments ................................  

Payments due by period 

Less than 

1 year 

1-3 years 

3-5 years 

More than 

5 years 

- 

- 

- 

- 

- 

- 

52,875 

103,330 

39,824 

40,151 

100,000 

71,734 

150,000 

19,476 

- 

- 

18,375 

26,373 

Total 

100,000 

246,314 

150,000 

125,824 

Total contractual obligations ..................................................     $  1,522,138  

 $  92,699 

 $  143,481 

 $  641,210 

 $ 

644,748 

1. 

Lease and other commitments relate to an office lease for the Company’s Calgary head office, rail tank cars, vehicles, field buildings, various equipment leases 

and terminal services arrangements. 

As at December 31, 2018, the Company had previously identified and approved capital expenditure commitments of $290 million 

that the Company expects to undertake over the next 12 to 24 months. In addition, the Company had accrued liabilities for obligations 

with respect to the Company’s defined benefit plans of $16.4 million and provisions associated with site restoration on the retirement 

of  assets  and  environmental  costs  of  $162.8  million  but  the  timing  of  such  payments  is  uncertain  due  to  the  estimates  used  to 

calculate  these  amounts  and  the  long-term  nature  of  these  balances.  The  Company  also  has  commitments  relating  to  its  risk 

management contracts which are discussed further in “Quantitative and Qualitative Disclosures about Market Risks”. 

The Company is involved in various claims and actions arising in the course of operations and is subject to various legal actions and 

exposures. Although the outcome of these claims is uncertain, the Company does not expect these matters to have a material adverse 

effect on the Company’s financial position, cash flows or operational results. If an unfavorable outcome were to occur, there exists 

the possibility of a material adverse impact on the Company’s consolidated net income or loss in the period in which the outcome is 

determined. Accruals for litigation, claims and assessments are recognized if the Company determines that the loss is probable and 

the amount can be reasonably estimated. The Company believes it has made adequate provision for such legal claims. While fully 

supportable in the Company’s view, some of these positions, if challenged may not be fully sustained on review. 

The  Company  is  subject  to  various  regulatory  and  statutory  requirements  relating  to  the  protection  of  the  environment.  These 

requirements,  in  addition  to  the  contractual  agreements  and  management  decisions,  result  in  the  recognition  of  estimated 

decommissioning  obligations  and  environmental  remediation.  Estimates  of  decommissioning  obligations  and  environmental 

remediation costs can change significantly based on such factors as operating experience and changes in legislation and regulations.  

OFF-BALANCE SHEET ARRANGEMENTS 

The Company does not have any off-balance sheet arrangements that have or are reasonably likely to have a current or future effect 

on the Company’s financial performance or financial condition. 

OUTSTANDING SHARE DATA 

The Company is authorized to issue an unlimited number of common shares and an unlimited number of preferred shares. As at 

December 31, 2018, there were 144.6 million common shares outstanding and no preferred shares outstanding. In addition, under 

the Company’s equity incentive plan, there  were an  aggregate of 2.0  million restricted  share units, performance  share units and 

deferred share units outstanding and 2.3 million stock options outstanding as at December 31, 2018.  

At December 31, 2018, awards available to grant under the equity incentive plan were approximately 10.1 million. 

As at March 1, 2019, 144.6 million common shares, 2.0 million restricted share units, performance share units and deferred share 

units and 2.3 million stock options were outstanding. 

      Gibson Energy Inc.                                                            30                                              Management’s Discussion and Analysis  

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Contractual obligations and contingencies 

The following table presents, at December 31, 2018, the Company’s obligations and commitments to make future payments under 
contracts and contingent commitments: 

 $ 

 $ 

More than 
5 years 
600,000 
- 
18,375 
- 
26,373 
644,748 

Total 
Long-term debt  .......................................................................  
   $   900,000 
100,000 
Convertible debentures ..........................................................  
Interest payments on long-term debt and Debentures ..........  
246,314 
150,000 
Credit facilities ........................................................................  
Lease liabilities and other commitments ................................  
125,824 
Total contractual obligations ..................................................     $  1,522,138  

Payments due by period 

 $ 

Less than 
1 year 
- 
- 
52,875 
- 
39,824 
 $  92,699 

 $ 

1-3 years 
- 
- 
103,330 
- 
40,151 
 $  143,481 

3-5 years 
 $  300,000 
100,000 
71,734 
150,000 
19,476 
 $  641,210 

Quarter ended December 31 

2018 

Combined operations  

Adjustments: 

Combined cash flow from operating activities ............................................................  

$   272,337 

Combined changes in non-cash working capital ......................................................  

    (127,628) 

Combined replacement capital ................................................................................  

Cash interest expense, including capitalized interest ..............................................  

Lease payments (2) ....................................................................................................  

Current income tax ...................................................................................................  

Other charges (3) .......................................................................................................  

Working capital adjustment (4) .................................................................................  

(9,676) 

(16,713) 

(11,588) 

(22,609) 

- 

- 

2017 

(restated)1

$ 

45,312

13,564

(10,660)

(17,398)

-

14,149

18,086

10,503

Distributable cash flow from combined operations ....................................................  

$       84,123             

$       73,556

Dividends declared to shareholders ............................................................................  

$ 

47,704 

$ 

47,257

1.  During the third quarter of 2018, the Company revised its distributable cash flow calculations whereby income taxes were adjusted to include the impact of current 

income tax expense (recovery), instead of cash taxes paid (refunds). In management’s view the revised calculation provides a more representative measure of 

distributable cash flow to the users of the MD&A. 

2.  Due to the adoption of IFRS 16, lease payments are shown within cash flow from financing activity effective January 1, 2018. Therefore, distributable cash flow 

has been adjusted to deduct lease payments for the period starting January 1, 2018 to make the calculations consistent with the prior periods. 

3. 

4. 

generated.  

Represents a one-time adjustment related to working capital at the close of Industrial Propane segment sale whereby $10.5 million cash balance was required to 

be left in the businesses prior to close and was repaid back to the Company as part of the sale proceeds. Absent this requirement, the cash flow from operations 

would have been higher and cash flow from investing activity would be lower by the same amount. 

Dividends declared in the twelve months ended December 31, 2018 were $190.3 million, of which the entire amount was paid in 

cash. In the twelve months ended December 31, 2018, dividends declared represented 67% of the combined distributable cash flow 

      Gibson Energy Inc.                                                            29                                              Management’s Discussion and Analysis  

Represents restructuring, severance and executive payroll related costs incurred during the respective periods. 

Contingencies 

1. 

Lease and other commitments relate to an office lease for the Company’s Calgary head office, rail tank cars, vehicles, field buildings, various equipment leases 
and terminal services arrangements. 

As at December 31, 2018, the Company had previously identified and approved capital expenditure commitments of $290 million 
that the Company expects to undertake over the next 12 to 24 months. In addition, the Company had accrued liabilities for obligations 
with respect to the Company’s defined benefit plans of $16.4 million and provisions associated with site restoration on the retirement 
of  assets  and  environmental  costs  of  $162.8  million  but  the  timing  of  such  payments  is  uncertain  due  to  the  estimates  used  to 
calculate  these  amounts  and  the  long-term  nature  of  these  balances.  The  Company  also  has  commitments  relating  to  its  risk 
management contracts which are discussed further in “Quantitative and Qualitative Disclosures about Market Risks”. 

The Company is involved in various claims and actions arising in the course of operations and is subject to various legal actions and 
exposures. Although the outcome of these claims is uncertain, the Company does not expect these matters to have a material adverse 
effect on the Company’s financial position, cash flows or operational results. If an unfavorable outcome were to occur, there exists 
the possibility of a material adverse impact on the Company’s consolidated net income or loss in the period in which the outcome is 
determined. Accruals for litigation, claims and assessments are recognized if the Company determines that the loss is probable and 
the amount can be reasonably estimated. The Company believes it has made adequate provision for such legal claims. While fully 
supportable in the Company’s view, some of these positions, if challenged may not be fully sustained on review. 

The  Company  is  subject  to  various  regulatory  and  statutory  requirements  relating  to  the  protection  of  the  environment.  These 
requirements,  in  addition  to  the  contractual  agreements  and  management  decisions,  result  in  the  recognition  of  estimated 
decommissioning  obligations  and  environmental  remediation.  Estimates  of  decommissioning  obligations  and  environmental 
remediation costs can change significantly based on such factors as operating experience and changes in legislation and regulations.  

OFF-BALANCE SHEET ARRANGEMENTS 

The Company does not have any off-balance sheet arrangements that have or are reasonably likely to have a current or future effect 
on the Company’s financial performance or financial condition. 

OUTSTANDING SHARE DATA 

The Company is authorized to issue an unlimited number of common shares and an unlimited number of preferred shares. As at 
December 31, 2018, there were 144.6 million common shares outstanding and no preferred shares outstanding. In addition, under 
the Company’s equity incentive plan, there  were an  aggregate of 2.0  million restricted  share units, performance  share units and 
deferred share units outstanding and 2.3 million stock options outstanding as at December 31, 2018.  

At December 31, 2018, awards available to grant under the equity incentive plan were approximately 10.1 million. 

As at March 1, 2019, 144.6 million common shares, 2.0 million restricted share units, performance share units and deferred share 
units and 2.3 million stock options were outstanding. 

      Gibson Energy Inc.                                                            30                                              Management’s Discussion and Analysis  

31 

Management’s Discussion and Analysis

Gibson Energy 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK 

The Company is involved in various commodity related marketing activities that are intended to enhance the Company’s operations 
and increase profitability. These activities often create exposure to price risk between the time contracted volumes are purchased 
and sold and to foreign exchange risk when contracts are in different currencies (Canadian dollar versus U.S. dollar). The Company is 
also exposed to various market risks, including volatility in (i) crude oil, refined products, natural gas and NGL prices, (ii) interest rates, 
(iii) currency exchange rates and (iv) equity prices. The Company utilizes various derivative instruments from time to time to manage 
commodity  price,  interest  rate,  currency  exchange  rate,  and  equity  price  exposure  and,  in  certain  circumstances,  to  realize 
incremental  margin  during  volatile  market  conditions.  The  Company’s  commodity  trading  and  risk  management  policies  and 
procedures  are  designed  to  establish  and  manage  to  an  approved  level  of  value  at  risk.  The  Company  has  a  Commodity  Risk 
Management  Committee  that  has  direct  responsibility  and  authority  for  the  Company’s  risk  policies  and  the  Company’s  trading 
controls and procedures. Additionally, certain aspects of corporate risk management are handled within the Risk Management Group. 
The Company’s approved strategies are intended to mitigate risks that are inherent in the Company’s core businesses of aggregating, 
marketing and distribution. To hedge the risks discussed above the Company engages in risk management activities that the Company 
categorizes  by  the  risks  the  Company  is  hedging  and  by  the  physical  product  that  is  creating  the  risk.  The  following  discussion 
addresses each category of risk. 

Commodity Price Risk. The Company hedges its exposure to price fluctuations with respect to crude oil, refined products, natural gas, 
differentials and NGLs, and expected purchases and sales of these commodities (relating primarily to crude oil, roofing flux, propane 
sales and purchases of natural gasoline). The derivative instruments utilized consist primarily of futures and option contracts traded 
on the New York Mercantile Exchange, the Intercontinental Exchange and over-the-counter transactions, including swap and option 
contracts entered into with financial institutions and other energy companies. The Company’s policy is to transact only in commodity 
derivative  products  for  which  the  Company  physically  transacts,  and  to  structure  the  Company’s  hedging  activities  so  that  price 
fluctuations for those products do not materially affect the net cash the Company ultimately receives from its commodity related 
marketing activities. 

Although the Company seeks to maintain a position that is substantially balanced within the Company’s various commodity purchase 
and sales activities, the Company may experience net unbalanced positions as a result of production, transportation and delivery 
variances as well as logistical issues associated with inclement weather conditions. 

The intent of the Company’s risk management strategy is to hedge the Company’s margin. However, the Company has not designated 
nor attempted to qualify for hedge accounting. Thus, changes in the fair values of all of the Company’s derivatives are recognized in 
earnings and result in greater potential for earnings volatility. 

The fair value of futures contracts is based on quoted market prices obtained from the Chicago Mercantile Exchange. The fair value 
of swaps and option contracts is estimated based on quoted prices from various sources, such as independent reporting services, 
industry publications and brokers. These quotes are compared to the contract price of the swap, which approximates the gain or loss 
that would have been realized if the contracts had been closed out at the period end. For positions where independent quotations 
are not available, an estimate is provided, or the prevailing market price at which the positions could be liquidated is used. No such 
positions existed as at December 31, 2018 and December 31, 2017. All derivative positions offset existing or anticipated physical 
exposures.  Price-risk  sensitivities  were  calculated  by  assuming  15%  volatility  in  crude  oil,  differentials  and  NGL  related  prices, 
regardless of term or historical relationships between the contractual price of the instruments and the underlying commodity price. 
In the event of an increase or decrease in prices, the fair value of the Company’s derivative portfolio would typically increase or 
decrease, offsetting changes in the Company’s physical positions. A 15% favorable change would increase the Company’s net income 
by $7.3 million and $6.2 million as of December 31, 2018 and 2017, respectively. A 15% unfavorable change would decrease the 
Company’s net income by $7.3 million and $6.2 million as of December 31, 2018 and 2017, respectively. However, these changes may 
be offset by the use of one or more risk management strategies. 

Interest rate risk. The Company’s long-term debt, excluding the Revolving Credit Facility, accrues interest at fixed interest rates and 
accordingly, changes in market interest rates do not expose the Company to future interest cash outflow variability. At December 31, 
2018, the Company had $150.0 million drawn under the Revolving Credit Facility which is subject to interest rate risk, as borrowings 
bear interest at a rate equal to, at the Company’s option, either the Canadian Prime Rate, U.S. LIBOR, U.S. Base Rate or Canadian 
Bankers’ Acceptance Rate, plus an applicable margin based on the Company’s total leverage ratio. At current balances and rates the 
interest rate risk is not significant. 

Currency exchange risks. The Company’s monetary assets and liabilities in foreign currencies are translated at the period-end rate. 
Exchange  differences  arising  from  this  translation  are  recorded  in  the  Company’s  statement  of  operations.  In  addition,  currency 

Management’s Discussion and Analysis 

      Gibson Energy Inc.                                                            31                                              Management’s Discussion and Analysis  
Gibson Energy

32 

exposures can arise from revenues and purchase transactions denominated in foreign currencies. Generally, transactional currency 

exposures are naturally hedged (i.e., revenues and expenses are approximately matched), but, where appropriate, are covered using 

forward exchange contracts. All of the foreign currency forward exchange contracts entered into by the Company, although effective 

hedges from an economic perspective, have not been designated as hedges for accounting purposes, and therefore any gains and 

losses on such forward exchange contracts impact the Company’s earnings. A 5% unfavorable change in the value of the Canadian 

dollar relative to the U.S. dollar would affect the fair value of the Company’s outstanding forward currency contracts and options and 

would decrease the Company’s net income by $1.9 million and $3.4 million as at December 31, 2018 and 2017, respectively. A 5% 

favorable change would increase the Company’s net income by $1.9 million and $3.4 million as at December 31, 2018 and 2017, 

respectively.  The  Company  expects  to  continue  to  enter  into  financial  derivatives,  primarily  forward  contracts,  to  reduce  foreign 

exchange volatility.  

As at December 31, 2018, the Company had $nil U.S. dollar denominated debt as part of its draw on its Revolving Credit Facility. Due 

to the repayment of US$ Notes in 2017 and repayment of U.S dollar Revolving Credit Facility in 2018, the Company has no debt in 

foreign currency and as such the currency risk is minimal.  

Equity price risk. The Company has equity price and dilution exposure to shares that it issues under its stock based compensation 

programs. Gibson uses equity derivatives to manage volatility derived from its stock based compensation programs. These contracts 

will mature at the prevailing share prices in accordance with the specific maturities of each contract over a three-year period. As at 

December 31, 2018 and 2017, the Company estimates that a 10% increase in the Company’s share price would have resulted in an 

increase in the Company’s income of $2.0 million and $1.9 million, respectively. A corresponding decrease in the Company’s share 

price would decrease the Company’s net income by $2.0 million and $1.9 million, respectively.  

ACCOUNTING POLICIES 

Critical accounting estimates 

The  preparation  of  consolidated  financial  statements  in  conformity  with  IFRS  requires  management  to  make  estimates  and 

assumptions. Predicting future events is inherently an imprecise activity and, as such, requires the use of judgment. Actual results 

may vary from estimates in amounts that may be material. An accounting policy is deemed to be critical if it requires an accounting 

estimate to be made based on assumptions about matters that are highly uncertain at the time the estimate is made, and if different 

estimates  that  reasonably  could  have  been  used,  or  changes  in  the  accounting  estimates  that  are  reasonably  likely  to  occur 

periodically, could materially impact the Company’s consolidated financial statements. The Company’s critical accounting policies 

and estimates are as follows: 

Recoverability of asset carrying values. The Company carries out impairment reviews in respect of goodwill at least annually or if 

indicators of impairment exist. The Company also assesses during each reporting period whether there have been any events or 

changes in circumstances that indicate that property, plant and equipment, inventories and other intangible assets may be impaired 

and an impairment review is carried out whenever such an assessment indicates that the carrying amount may not be recoverable. 

Such indicators include changes in the Company’s business plans, changes in activity levels, an increase in the discount rate, the 

intention of “holding” versus “selling” and evidence of physical damage. For the purposes of impairment testing, assets are grouped 

at the lowest levels for which there are separately identifiable cash flows. Where impairment exists, the asset is written down to its 

recoverable amount, which is the higher of the fair value less costs to sell and value in use. Impairments are recognized immediately 

in the consolidated statement of operations.  

The assessment for impairment entails comparing the carrying value of the asset or cash-generating unit with its recoverable amount; 

that  is,  the  higher  of  fair  value  less  costs  to  sell  and  value  in  use.  Value  in  use  is  usually  determined  on  the  basis  of  discounted 

estimated future net cash flows. However, the determination as to whether and how much an asset is impaired involves management 

estimates  on  highly  uncertain  matters,  such  as  the  outlook  for  global  or  regional  market  supply-and-demand  conditions,  future 

commodity prices, the effects of inflation on operating expenses and discount rates. 

Income  tax.  Income  tax  expense  represents  the  sum  of  the  income  tax  currently  payable  and  deferred  income  tax.  Interest  and 

penalties relating to income tax are also included in income tax expense. Deferred income tax is provided for using the liability method 

of accounting. Deferred income tax assets and liabilities are determined based on differences between the financial reporting and 

income tax basis of assets and liabilities. These differences are then measured using enacted or substantially enacted income tax 

rates and laws that will be in effect when these differences are expected to reverse. The effect of a change in income tax rates on 

deferred tax assets and liabilities is recognized in income in the period that the change occurs.  

      Gibson Energy Inc.                                                            32                                              Management’s Discussion and Analysis  

 
 
 
 
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK 

The Company is involved in various commodity related marketing activities that are intended to enhance the Company’s operations 

and increase profitability. These activities often create exposure to price risk between the time contracted volumes are purchased 

and sold and to foreign exchange risk when contracts are in different currencies (Canadian dollar versus U.S. dollar). The Company is 

also exposed to various market risks, including volatility in (i) crude oil, refined products, natural gas and NGL prices, (ii) interest rates, 

(iii) currency exchange rates and (iv) equity prices. The Company utilizes various derivative instruments from time to time to manage 

commodity  price,  interest  rate,  currency  exchange  rate,  and  equity  price  exposure  and,  in  certain  circumstances,  to  realize 

incremental  margin  during  volatile  market  conditions.  The  Company’s  commodity  trading  and  risk  management  policies  and 

procedures  are  designed  to  establish  and  manage  to  an  approved  level  of  value  at  risk.  The  Company  has  a  Commodity  Risk 

Management  Committee  that  has  direct  responsibility  and  authority  for  the  Company’s  risk  policies  and  the  Company’s  trading 

controls and procedures. Additionally, certain aspects of corporate risk management are handled within the Risk Management Group. 

The Company’s approved strategies are intended to mitigate risks that are inherent in the Company’s core businesses of aggregating, 

marketing and distribution. To hedge the risks discussed above the Company engages in risk management activities that the Company 

categorizes  by  the  risks  the  Company  is  hedging  and  by  the  physical  product  that  is  creating  the  risk.  The  following  discussion 

addresses each category of risk. 

Commodity Price Risk. The Company hedges its exposure to price fluctuations with respect to crude oil, refined products, natural gas, 

differentials and NGLs, and expected purchases and sales of these commodities (relating primarily to crude oil, roofing flux, propane 

sales and purchases of natural gasoline). The derivative instruments utilized consist primarily of futures and option contracts traded 

on the New York Mercantile Exchange, the Intercontinental Exchange and over-the-counter transactions, including swap and option 

contracts entered into with financial institutions and other energy companies. The Company’s policy is to transact only in commodity 

derivative  products  for  which  the  Company  physically  transacts,  and  to  structure  the  Company’s  hedging  activities  so  that  price 

fluctuations for those products do not materially affect the net cash the Company ultimately receives from its commodity related 

marketing activities. 

Although the Company seeks to maintain a position that is substantially balanced within the Company’s various commodity purchase 

and sales activities, the Company may experience net unbalanced positions as a result of production, transportation and delivery 

variances as well as logistical issues associated with inclement weather conditions. 

The intent of the Company’s risk management strategy is to hedge the Company’s margin. However, the Company has not designated 

nor attempted to qualify for hedge accounting. Thus, changes in the fair values of all of the Company’s derivatives are recognized in 

earnings and result in greater potential for earnings volatility. 

The fair value of futures contracts is based on quoted market prices obtained from the Chicago Mercantile Exchange. The fair value 

of swaps and option contracts is estimated based on quoted prices from various sources, such as independent reporting services, 

industry publications and brokers. These quotes are compared to the contract price of the swap, which approximates the gain or loss 

that would have been realized if the contracts had been closed out at the period end. For positions where independent quotations 

are not available, an estimate is provided, or the prevailing market price at which the positions could be liquidated is used. No such 

positions existed as at December 31, 2018 and December 31, 2017. All derivative positions offset existing or anticipated physical 

exposures.  Price-risk  sensitivities  were  calculated  by  assuming  15%  volatility  in  crude  oil,  differentials  and  NGL  related  prices, 

regardless of term or historical relationships between the contractual price of the instruments and the underlying commodity price. 

In the event of an increase or decrease in prices, the fair value of the Company’s derivative portfolio would typically increase or 

decrease, offsetting changes in the Company’s physical positions. A 15% favorable change would increase the Company’s net income 

by $7.3 million and $6.2 million as of December 31, 2018 and 2017, respectively. A 15% unfavorable change would decrease the 

Company’s net income by $7.3 million and $6.2 million as of December 31, 2018 and 2017, respectively. However, these changes may 

be offset by the use of one or more risk management strategies. 

Interest rate risk. The Company’s long-term debt, excluding the Revolving Credit Facility, accrues interest at fixed interest rates and 

accordingly, changes in market interest rates do not expose the Company to future interest cash outflow variability. At December 31, 

2018, the Company had $150.0 million drawn under the Revolving Credit Facility which is subject to interest rate risk, as borrowings 

bear interest at a rate equal to, at the Company’s option, either the Canadian Prime Rate, U.S. LIBOR, U.S. Base Rate or Canadian 

Bankers’ Acceptance Rate, plus an applicable margin based on the Company’s total leverage ratio. At current balances and rates the 

interest rate risk is not significant. 

Currency exchange risks. The Company’s monetary assets and liabilities in foreign currencies are translated at the period-end rate. 

Exchange  differences  arising  from  this  translation  are  recorded  in  the  Company’s  statement  of  operations.  In  addition,  currency 

      Gibson Energy Inc.                                                            31                                              Management’s Discussion and Analysis  

exposures can arise from revenues and purchase transactions denominated in foreign currencies. Generally, transactional currency 
exposures are naturally hedged (i.e., revenues and expenses are approximately matched), but, where appropriate, are covered using 
forward exchange contracts. All of the foreign currency forward exchange contracts entered into by the Company, although effective 
hedges from an economic perspective, have not been designated as hedges for accounting purposes, and therefore any gains and 
losses on such forward exchange contracts impact the Company’s earnings. A 5% unfavorable change in the value of the Canadian 
dollar relative to the U.S. dollar would affect the fair value of the Company’s outstanding forward currency contracts and options and 
would decrease the Company’s net income by $1.9 million and $3.4 million as at December 31, 2018 and 2017, respectively. A 5% 
favorable change would increase the Company’s net income by $1.9 million and $3.4 million as at December 31, 2018 and 2017, 
respectively.  The  Company  expects  to  continue  to  enter  into  financial  derivatives,  primarily  forward  contracts,  to  reduce  foreign 
exchange volatility.  

As at December 31, 2018, the Company had $nil U.S. dollar denominated debt as part of its draw on its Revolving Credit Facility. Due 
to the repayment of US$ Notes in 2017 and repayment of U.S dollar Revolving Credit Facility in 2018, the Company has no debt in 
foreign currency and as such the currency risk is minimal.  

Equity price risk. The Company has equity price and dilution exposure to shares that it issues under its stock based compensation 
programs. Gibson uses equity derivatives to manage volatility derived from its stock based compensation programs. These contracts 
will mature at the prevailing share prices in accordance with the specific maturities of each contract over a three-year period. As at 
December 31, 2018 and 2017, the Company estimates that a 10% increase in the Company’s share price would have resulted in an 
increase in the Company’s income of $2.0 million and $1.9 million, respectively. A corresponding decrease in the Company’s share 
price would decrease the Company’s net income by $2.0 million and $1.9 million, respectively.  

ACCOUNTING POLICIES 

Critical accounting estimates 

The  preparation  of  consolidated  financial  statements  in  conformity  with  IFRS  requires  management  to  make  estimates  and 
assumptions. Predicting future events is inherently an imprecise activity and, as such, requires the use of judgment. Actual results 
may vary from estimates in amounts that may be material. An accounting policy is deemed to be critical if it requires an accounting 
estimate to be made based on assumptions about matters that are highly uncertain at the time the estimate is made, and if different 
estimates  that  reasonably  could  have  been  used,  or  changes  in  the  accounting  estimates  that  are  reasonably  likely  to  occur 
periodically, could materially impact the Company’s consolidated financial statements. The Company’s critical accounting policies 
and estimates are as follows: 

Recoverability of asset carrying values. The Company carries out impairment reviews in respect of goodwill at least annually or if 
indicators of impairment exist. The Company also assesses during each reporting period whether there have been any events or 
changes in circumstances that indicate that property, plant and equipment, inventories and other intangible assets may be impaired 
and an impairment review is carried out whenever such an assessment indicates that the carrying amount may not be recoverable. 
Such indicators include changes in the Company’s business plans, changes in activity levels, an increase in the discount rate, the 
intention of “holding” versus “selling” and evidence of physical damage. For the purposes of impairment testing, assets are grouped 
at the lowest levels for which there are separately identifiable cash flows. Where impairment exists, the asset is written down to its 
recoverable amount, which is the higher of the fair value less costs to sell and value in use. Impairments are recognized immediately 
in the consolidated statement of operations.  

The assessment for impairment entails comparing the carrying value of the asset or cash-generating unit with its recoverable amount; 
that  is,  the  higher  of  fair  value  less  costs  to  sell  and  value  in  use.  Value  in  use  is  usually  determined  on  the  basis  of  discounted 
estimated future net cash flows. However, the determination as to whether and how much an asset is impaired involves management 
estimates  on  highly  uncertain  matters,  such  as  the  outlook  for  global  or  regional  market  supply-and-demand  conditions,  future 
commodity prices, the effects of inflation on operating expenses and discount rates. 

Income  tax.  Income  tax  expense  represents  the  sum  of  the  income  tax  currently  payable  and  deferred  income  tax.  Interest  and 
penalties relating to income tax are also included in income tax expense. Deferred income tax is provided for using the liability method 
of accounting. Deferred income tax assets and liabilities are determined based on differences between the financial reporting and 
income tax basis of assets and liabilities. These differences are then measured using enacted or substantially enacted income tax 
rates and laws that will be in effect when these differences are expected to reverse. The effect of a change in income tax rates on 
deferred tax assets and liabilities is recognized in income in the period that the change occurs.  

Gibson Energy 

      Gibson Energy Inc.                                                            32                                              Management’s Discussion and Analysis  

Management’s Discussion and Analysis

33 

 
 
 
 
The computation of the Company’s income tax expense involves the interpretation of applicable tax laws and regulations in many 
jurisdictions.  The resolution  of tax positions taken by the Company can take significant time to complete and in  some cases it is 
difficult to predict the ultimate outcome. In addition, the Company has carry-forward tax losses in certain taxing jurisdictions that are 
available to offset against future taxable profit. However, deferred income tax assets are recognized only to the extent that it is 
probable that taxable profit will be available against which the unused tax losses can be utilized. Management judgement is exercised 
in assessing whether this is the case. To the extent that actual outcomes differ from management’s estimates, income tax charges or 
credits may arise in future periods. 

Provisions and accrued liabilities. The Company uses estimates to record liabilities for obligations associated with site restoration on 
the retirement of assets and environmental costs, taxes, potential legal claims and other accruals and liabilities. 

Liabilities for site restoration on the retirement of assets are recognized when the Company has an obligation to restore the site and 
when a reliable estimate of that liability can be made. An obligation may also crystallize during the period of operation of a facility 
through a change in legislation or through a decision to terminate operations. The amount recognized is the present value of the 
estimated future expenditure determined in accordance with local conditions and requirements. The present value is determined by 
discounting  the  expenditures  expected  to  be  required  to  settle  the  obligation  using  a  risk-free  discount  rate.  Estimated  future 
expenditure is based on all known facts at the time and current expected plans for decommissioning. Among the many uncertainties 
that  may  impact  the  estimates  are  changes  in  laws  and  regulations,  public  expectations,  prices  and  changes  in  technology.  A 
corresponding item of property, plant and equipment of an amount equivalent to the provision is also recorded. This is subsequently 
depreciated as part of the asset. Other than the unwinding discount on the provision, any change in the present value of the estimated 
expenditure is reflected as an adjustment to the provision and the corresponding item of property, plant and equipment.  

Liabilities for environmental costs are recognized when a clean-up is probable and the associated costs can be reliably estimated. 
Generally, the timing of recognition of these provisions coincides with the completion of a feasibility study or a commitment to a 
formal plan of action. The amount recognized is the best estimate of the expenditure required. Where the liability will not be settled 
for a number of years, the amount recognized is the present value of the estimated future expenditure. Estimated future expenditure 
is  based  on  all  known  facts  at  the  time  and  an  assessment  of  the  ultimate  outcome.  A  number  of  factors  affect  the  cost  of 
environmental remediation, including the determination of the extent of contamination, the length of time remediation may require, 
the complexity of environmental regulations and the advancement of remediation technology. 

Other provisions and accrued liabilities are recognized in the period when it becomes probable that there will be a future outflow of 
funds resulting from past operations or events and the amount of cash outflow can be reliably estimated. The timing of recognition 
and quantification of the liability require the application of judgment to existing facts and circumstances, which can be subject to 
change. Since the actual cash outflows can take place many years in the future, the carrying amounts of provisions and liabilities are 
reviewed regularly and adjusted to take account of changing facts and circumstances. A change in estimate of a recognized provision 
or accrued liability would result in a charge or credit to net income in the period in which the change occurs. 

Assets held for sale and discontinued operations. As at December 31, 2018, the Company considered certain businesses and assets as 
held-for-sale and discontinued operations (refer to note 8 in the consolidated financial statements). In making these determinations, 
the Company used significant judgment in evaluating whether a sale was considered highly probable and considered the progress of 
negotiations specific to significant terms of the sales, including the structure of the transaction and if the buyer has substantially 
completed their due diligence review. For these businesses and assets these conditions were all met during the year ended December 
31, 2018. The Company also used significant judgment in evaluating whether a disposal group represented a major line of business 
or geographical area of operations to be reported within discontinued operations, considering if the disposal group is a component 
of an entity and its materiality in relation to the reportable segment. These criteria were met for certain disposal groups. 

Critical accounting estimates and judgements from adoption of new accounting standards  

Critical judgements in determining lease terms 

The Company uses hindsight in determining the lease term where a contract contains options to extend or terminate the lease. In 
determining the lease term,  management considers all facts and circumstances that create an economic incentive to exercise an 
extension option, or not exercise a termination option. The assessment is reviewed upon a trigger by a significant event or a significant 
change in circumstances.  

Management’s Discussion and Analysis 

      Gibson Energy Inc.                                                            33                                              Management’s Discussion and Analysis  
Gibson Energy

34 

Impairment provision for financial assets 

The impairment provisions for financial assets are based on assumptions related to the risk of default and expected loss. The Company 

uses judgement in making these assumptions and selecting the inputs to the impairment calculation, based on the Company’s history, 

existing market conditions as well as forward looking estimates at the end of each reporting period.  

Estimation uncertainty arising from variable lease payments  

Certain leases contain variable payment terms that are linked to the Company’s owner operator costs within our Logistics segment. 

Judgment  is  applied  in  determination  of  whether  the  owner  operator  arrangement  contain  variable  payment  terms.  All  owner 

operator costs that are dependent upon the activity levels are classified as variable payments and all such costs are accounted for as 

a single lease component and charged to the consolidated statements of operations as incurred.   

Initial adoption of accounting policies 

New and amended standards adopted by the Company: 

The Company adopted the following new and revised standards, along with any consequential amendments. These changes were 

made in accordance with applicable transitional provisions. 

• 

IFRS 2 – Share-based payments (“IFRS 2”), has been amended to address (i) certain issues related to the accounting for cash 

settled  awards,  and  (ii)  the  accounting  for  equity  settled  awards  that  include  a  “net  settlement”  feature  in  respect  of 

employee withholding taxes. IFRS 2 is effective for annual periods beginning on or after January 1, 2018. The Company has 

determined that the adoption of this interpretation did not have a material impact on its consolidated financial statements. 

• 

IFRIC 22 – Foreign currency transactions and advance consideration (“IFRIC 22”), provides guidance on how to determine 

the  date  of  the  transaction  when  an  entity  either  pays  or  receives  consideration  in  advance  for  foreign  currency-

denominated contracts. IFRIC 22 is effective for annual periods beginning on or after January 1, 2018. The Company has 

determined that the adoption of this interpretation did not have a material impact on its consolidated financial statements. 

• 

IAS 28 – Investments in associates and joint ventures (“IAS 28”), has been amended to clarify that an entity applies IFRS 9, 

including its impairment requirements, to long-term interests in associate or joint venture to which the equity method is 

not  applied.  The  amendment  to  IAS  28  is  effective  for  years  beginning  on  or  after  January  1,  2018.  The  Company  has 

determined that the adoption of this interpretation did not have a material impact on its consolidated financial statements. 

• 

The annual improvements process addresses issues in the 2014-2016 reporting cycles include changes to IFRS 1 – First time 

adoption of IFRS, IFRS 7 – Financial instruments: Disclosures, IAS 19 – Employee benefits, IFRS 10 – Consolidated financial 

statements and IAS 28 – Investment in associates and joint ventures. This improvement is effective for periods beginning 

on  or  after  January  1,  2018.  The  adoption  of  these  improvements  did  not  have  a  material  impact  on  the  consolidated 

financial statements. 

Adoption of IFRS 16, IFRS 15, “Revenue from Contracts with Customers” (“IFRS 15”) and IFRS 9, “Financial Instruments” (“IFRS 9”)  

As disclosed in the 2018 consolidated financial statements, the Company has evaluated the impact of IFRS 9, IFRS 15, and IFRS 16 and 

adopted all three standards as at January 1, 2018.  

The  Company  has  taken  pro-active  measures  to  review  the  impacts  of  the  adoption  of  these  standards  on  our  debt  covenants 

including certain amendments to our covenants which provides an option to adjust for the impact of these standards or to provide a 

grandfathering approach. Currently the Company includes the lease liability in the total debt balance and uses the new accounting 

standards as a basis to calculate the covenants. Accordingly, the impact of adoption is not considered material on the Company’s 

debt covenant calculations. 

On January 1, 2018, the Company’s policies and business practices were updated to reflect the changes required by the adoption of 

these new standards (refer to note 3 and 4 in the 2018 consolidated financial statements for the updated policies). 

IFRS 16 is effective for years beginning on or after January 1, 2019, however the Company has adopted IFRS 16 effective January 1, 

2018, concurrent with the adoption date of IFRS 9, and IFRS 15. These standards have been applied retrospectively using the modified 

retrospective approach. The modified retrospective approach does not require restatement of prior period financial information as 

      Gibson Energy Inc.                                                            34                                              Management’s Discussion and Analysis  

 
 
 
 
 
 
 
The computation of the Company’s income tax expense involves the interpretation of applicable tax laws and regulations in many 

Impairment provision for financial assets 

The impairment provisions for financial assets are based on assumptions related to the risk of default and expected loss. The Company 
uses judgement in making these assumptions and selecting the inputs to the impairment calculation, based on the Company’s history, 
existing market conditions as well as forward looking estimates at the end of each reporting period.  

Estimation uncertainty arising from variable lease payments  

Certain leases contain variable payment terms that are linked to the Company’s owner operator costs within our Logistics segment. 
Judgment  is  applied  in  determination  of  whether  the  owner  operator  arrangement  contain  variable  payment  terms.  All  owner 
operator costs that are dependent upon the activity levels are classified as variable payments and all such costs are accounted for as 
a single lease component and charged to the consolidated statements of operations as incurred.   

Initial adoption of accounting policies 

New and amended standards adopted by the Company: 

The Company adopted the following new and revised standards, along with any consequential amendments. These changes were 
made in accordance with applicable transitional provisions. 

• 

• 

• 

• 

IFRS 2 – Share-based payments (“IFRS 2”), has been amended to address (i) certain issues related to the accounting for cash 
settled  awards,  and  (ii)  the  accounting  for  equity  settled  awards  that  include  a  “net  settlement”  feature  in  respect  of 
employee withholding taxes. IFRS 2 is effective for annual periods beginning on or after January 1, 2018. The Company has 
determined that the adoption of this interpretation did not have a material impact on its consolidated financial statements. 

IFRIC 22 – Foreign currency transactions and advance consideration (“IFRIC 22”), provides guidance on how to determine 
the  date  of  the  transaction  when  an  entity  either  pays  or  receives  consideration  in  advance  for  foreign  currency-
denominated contracts. IFRIC 22 is effective for annual periods beginning on or after January 1, 2018. The Company has 
determined that the adoption of this interpretation did not have a material impact on its consolidated financial statements. 

IAS 28 – Investments in associates and joint ventures (“IAS 28”), has been amended to clarify that an entity applies IFRS 9, 
including its impairment requirements, to long-term interests in associate or joint venture to which the equity method is 
not  applied.  The  amendment  to  IAS  28  is  effective  for  years  beginning  on  or  after  January  1,  2018.  The  Company  has 
determined that the adoption of this interpretation did not have a material impact on its consolidated financial statements. 

The annual improvements process addresses issues in the 2014-2016 reporting cycles include changes to IFRS 1 – First time 
adoption of IFRS, IFRS 7 – Financial instruments: Disclosures, IAS 19 – Employee benefits, IFRS 10 – Consolidated financial 
statements and IAS 28 – Investment in associates and joint ventures. This improvement is effective for periods beginning 
on  or  after  January  1,  2018.  The  adoption  of  these  improvements  did  not  have  a  material  impact  on  the  consolidated 
financial statements. 

Adoption of IFRS 16, IFRS 15, “Revenue from Contracts with Customers” (“IFRS 15”) and IFRS 9, “Financial Instruments” (“IFRS 9”)  

As disclosed in the 2018 consolidated financial statements, the Company has evaluated the impact of IFRS 9, IFRS 15, and IFRS 16 and 
adopted all three standards as at January 1, 2018.  

The  Company  has  taken  pro-active  measures  to  review  the  impacts  of  the  adoption  of  these  standards  on  our  debt  covenants 
including certain amendments to our covenants which provides an option to adjust for the impact of these standards or to provide a 
grandfathering approach. Currently the Company includes the lease liability in the total debt balance and uses the new accounting 
standards as a basis to calculate the covenants. Accordingly, the impact of adoption is not considered material on the Company’s 
debt covenant calculations. 

On January 1, 2018, the Company’s policies and business practices were updated to reflect the changes required by the adoption of 
these new standards (refer to note 3 and 4 in the 2018 consolidated financial statements for the updated policies). 

IFRS 16 is effective for years beginning on or after January 1, 2019, however the Company has adopted IFRS 16 effective January 1, 
2018, concurrent with the adoption date of IFRS 9, and IFRS 15. These standards have been applied retrospectively using the modified 
retrospective approach. The modified retrospective approach does not require restatement of prior period financial information as 

jurisdictions.  The resolution  of tax positions taken by the Company can take significant time to complete and in  some cases it is 

difficult to predict the ultimate outcome. In addition, the Company has carry-forward tax losses in certain taxing jurisdictions that are 

available to offset against future taxable profit. However, deferred income tax assets are recognized only to the extent that it is 

probable that taxable profit will be available against which the unused tax losses can be utilized. Management judgement is exercised 

in assessing whether this is the case. To the extent that actual outcomes differ from management’s estimates, income tax charges or 

credits may arise in future periods. 

Provisions and accrued liabilities. The Company uses estimates to record liabilities for obligations associated with site restoration on 

the retirement of assets and environmental costs, taxes, potential legal claims and other accruals and liabilities. 

Liabilities for site restoration on the retirement of assets are recognized when the Company has an obligation to restore the site and 

when a reliable estimate of that liability can be made. An obligation may also crystallize during the period of operation of a facility 

through a change in legislation or through a decision to terminate operations. The amount recognized is the present value of the 

estimated future expenditure determined in accordance with local conditions and requirements. The present value is determined by 

discounting  the  expenditures  expected  to  be  required  to  settle  the  obligation  using  a  risk-free  discount  rate.  Estimated  future 

expenditure is based on all known facts at the time and current expected plans for decommissioning. Among the many uncertainties 

that  may  impact  the  estimates  are  changes  in  laws  and  regulations,  public  expectations,  prices  and  changes  in  technology.  A 

corresponding item of property, plant and equipment of an amount equivalent to the provision is also recorded. This is subsequently 

depreciated as part of the asset. Other than the unwinding discount on the provision, any change in the present value of the estimated 

expenditure is reflected as an adjustment to the provision and the corresponding item of property, plant and equipment.  

Liabilities for environmental costs are recognized when a clean-up is probable and the associated costs can be reliably estimated. 

Generally, the timing of recognition of these provisions coincides with the completion of a feasibility study or a commitment to a 

formal plan of action. The amount recognized is the best estimate of the expenditure required. Where the liability will not be settled 

for a number of years, the amount recognized is the present value of the estimated future expenditure. Estimated future expenditure 

is  based  on  all  known  facts  at  the  time  and  an  assessment  of  the  ultimate  outcome.  A  number  of  factors  affect  the  cost  of 

environmental remediation, including the determination of the extent of contamination, the length of time remediation may require, 

the complexity of environmental regulations and the advancement of remediation technology. 

Other provisions and accrued liabilities are recognized in the period when it becomes probable that there will be a future outflow of 

funds resulting from past operations or events and the amount of cash outflow can be reliably estimated. The timing of recognition 

and quantification of the liability require the application of judgment to existing facts and circumstances, which can be subject to 

change. Since the actual cash outflows can take place many years in the future, the carrying amounts of provisions and liabilities are 

reviewed regularly and adjusted to take account of changing facts and circumstances. A change in estimate of a recognized provision 

or accrued liability would result in a charge or credit to net income in the period in which the change occurs. 

Assets held for sale and discontinued operations. As at December 31, 2018, the Company considered certain businesses and assets as 

held-for-sale and discontinued operations (refer to note 8 in the consolidated financial statements). In making these determinations, 

the Company used significant judgment in evaluating whether a sale was considered highly probable and considered the progress of 

negotiations specific to significant terms of the sales, including the structure of the transaction and if the buyer has substantially 

completed their due diligence review. For these businesses and assets these conditions were all met during the year ended December 

31, 2018. The Company also used significant judgment in evaluating whether a disposal group represented a major line of business 

or geographical area of operations to be reported within discontinued operations, considering if the disposal group is a component 

of an entity and its materiality in relation to the reportable segment. These criteria were met for certain disposal groups. 

Critical accounting estimates and judgements from adoption of new accounting standards  

Critical judgements in determining lease terms 

The Company uses hindsight in determining the lease term where a contract contains options to extend or terminate the lease. In 

determining the lease term,  management considers all facts and circumstances that create an economic incentive to exercise an 

extension option, or not exercise a termination option. The assessment is reviewed upon a trigger by a significant event or a significant 

change in circumstances.  

      Gibson Energy Inc.                                                            33                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            34                                              Management’s Discussion and Analysis  

35 

Management’s Discussion and Analysis

Gibson Energy 

 
 
 
 
 
 
 
it recognizes the cumulative effect as an adjustment to opening retained earnings and applies the standard prospectively. Accordingly, 
comparative information in the Company’s consolidated balance sheets, statements of operations, and statements of cash flows is 
not restated.  

(ii) Revenue recognition 

For the three months and year ended December 31, 2018, the following is a summary of material impacts on the results from 
continuing and discontinued operations: 

In previous reporting periods, wholesale product revenues associated with the sales of roofing flux products owned by the Company 

were recognized at the time of shipment when the risk of ownership and loss are passed to the customer. Under IFRS 15, where the 

revenue contract provides a right to invoice prior to the physical delivery of the product, the Company will defer such revenues and 

recognize a contract liability, until such time when the product has been physically delivered and the transfer of control has occurred.  

- 

- 

Segment profit from continuing operations increased by $11.2 million and $49.7 million, respectively, segment profit from 
discontinued operations increased by $0.4 million and $3.1 million, respectively, and G&A expenses decreased by $2.0 
million and $8.2 million, respectively with a total increase of $11.6 million and $52.8 million, respectively in combined 
Adjusted EBITDA.  

(iii)  Leases 

This was substantially offset by the additional depreciation charge on the right-of use-assets and interest expense for the 
lease liabilities. 

In addition, the impacts of IFRS 9, 15 and 16, including the new accounting policies adopted as at January 1, 2018 on the balance 
sheet are as follows: 

New standards and interpretations issued but not yet adopted: 

Accounts receivable .......................................................  
Inventories ......................................................................  
Trade payables and accrued charges .............................  
Right-of-use asset ...........................................................  
Contract liabilities ...........................................................  
Deferred revenue ...........................................................  
Lease liability – current portion ......................................  
Lease liability – non-current portion ..............................  
Retained deficit (earnings) .............................................  
Total  ...............................................................................  

As reported as 
at December 
31, 2017 

  $   494,901
    169,957
   (500,662)
-
-
(7,013)
-
-
  1,251,416
$ 1,408,599

Adjustments 

Footnote 

 $     

  484
4,765
3,329
170,548
(12,676)
7,013
(43,490)
(129,344)
(629)
$                -

(i) 
(ii) 
(ii & iii) 
(iii) 
(ii) 
(ii) 
(iii) 
(iii) 
(i & ii) 

Restated 
balance as at 
January 1, 2018 

  $       495,385
    174,722
   (497,333)
170,548
    (12,676)
-
    (43,490)
(129,344)
  1,250,787
$    1,408,599

Footnotes 

(i)  Financial instruments 

The Company carries the following categories of financial assets subject to IFRS 9’s expected credit losses model: 

Trade receivables 

 
  Net investments in finance leases 

The Company has revised its impairment methodology under IFRS 9 for the above noted classes of assets and applied the simplified 
approach on all trade receivables which requires the use of the lifetime expected loss provisions for expected credit losses. For lease 
receivables, the Company used the general approach which requires the recognition of twelve-month expected loss provisions for 
expected credit losses on lease receivables subject to credit risk as at January 1, 2018. Where such lease receivables have had a 
significant increase in credit risk since initial recognition but no objective evidence of impairment, lifetime expected loss provisions 
are used with interest calculated on the gross carrying amount of the receivable balance. Where objective evidence of impairment 
exists, interest is calculated on the carrying amount, net of the impairment. At December 31, 2018, there were no material changes 
to the credit risk on lease receivables. 

There was no impact to the classification of the Company’s financial assets from the adoption of IFRS 9. 

On adoption of IFRS 16, the Company has recognised lease liabilities in relation to all lease arrangements measured at the present 

value of the remaining lease payments from commitments disclosed as at December 31, 2017, adjusted by commitments in relation 

to arrangements not containing leases, short-term and low-value leases, discounted using the Company’s incremental borrowing rate 

as of January 1, 2018. The associated right-of-use assets were measured at the amount equal to the lease liability on January 1, 2018, 

adjusted by the amount of any prepaid or accrued lease payments relating to that lease recognised in the statement of financial 

position immediately before the date of transition, with no impact on retained earnings. 

• 

The annual improvements IAS 19 – Employee benefits (“IAS 19”), has been amended to (i) require current service cost and 

net interest for the period after the re-measurement to be determined using the assumptions used for the re-measurement, 

and (ii) clarify the effect of a plan amendment, curtailment or settlement on the requirements regarding the asset ceiling. 

The amendment to IAS 19 is effective for the years beginning on or after January 1, 2019. The Company is currently assessing 

the impact of this amendment. 

• 

IFRS 3 – Business Combinations (“IFRS 3”), has been amended to revise the definition of a business to include an input and 

a substantive process that together significantly contribute to the ability to create outputs. The amendment to IFRS 3 is 

effective  for  the  years  beginning  on  or  after  January  1,  2020.  The  Company  is  currently  assessing  the  impact  of  this 

• 

IAS 1 – Presentation of financial statements (“IAS 1”) and IAS 8 – Accounting policies, changes in accounting estimates and 

errors (“IAS 8”), have been amended to (i) use a consistent definition of materiality throughout IFRSs and the Conceptual 

Framework for Financial Reporting; (ii) clarify the explanation of the definition of material; and iii) incorporate guidance in 

IAS 1 regarding immaterial information. The amendments to IAS 1 and IAS 8 are effective for the years beginning on or after 

amendment.  

January 1, 2020. 

DISCLOSURE CONTROLS & PROCEDURES  

As  part  of  the  requirements  mandated  by  the  Canadian  securities  regulatory  authorities  under  National  Instrument  52-109-

Certification of Disclosure in Issuers' Annual and Interim Filings ("NI 52-109"), the Company’s Chief Executive Officer ("CEO") and the 

Chief  Financial  Officer  ("CFO")  have  evaluated  the  design  and  operation  of  the  Company's  disclosure  controls  and  procedures 

("DC&P"), as such term is defined in NI 52-109, as at December 31, 2018. The CEO and CFO are also responsible for establishing and 

maintaining  internal  controls  over  financial  reporting,  ("ICFR"),  as  such  term  is  defined  in  NI  52-109.  In  making  its  assessment, 

management  used  the  Committee  of  Sponsoring  Organizations  of  the  Treadway  Commission  framework  in  Internal  Control  – 

Integrated Framework (2013) to evaluate the design and effectiveness of internal control over financial reporting. These controls are 

designed to provide reasonable assurance regarding the reliability of the Company’s financial reporting and compliance with IFRS. 

The  Company’s  CEO  and  CFO  have  evaluated,  or  caused  to  be  evaluated  under  their  supervision,  the  design  and  operational 

effectiveness of such controls as at December 31, 2018. 

Based on the evaluation of the design and operating effectiveness of the Company’s DC&P and ICFR, the CEO and the CFO concluded 

that Gibson DC&P and ICFR were effective as at December 31, 2018. There have been no changes in ICFR that occurred during the 

period beginning January 1, 2018 and ended on December 31, 2018 that has materially affected or is reasonably likely to materially 

affect Gibson ICFR. 

      Gibson Energy Inc.                                                            36                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            35                                              Management’s Discussion and Analysis  
Gibson Energy

36 

Management’s Discussion and Analysis 

 
 
  
 
 
 
 
 
 
 
 
 
 
 
   
   
   
   
   
   
   
   
   
 
 
 
 
 
 
 
 
it recognizes the cumulative effect as an adjustment to opening retained earnings and applies the standard prospectively. Accordingly, 

(ii) Revenue recognition 

comparative information in the Company’s consolidated balance sheets, statements of operations, and statements of cash flows is 

not restated.  

continuing and discontinued operations: 

For the three months and year ended December 31, 2018, the following is a summary of material impacts on the results from 

In previous reporting periods, wholesale product revenues associated with the sales of roofing flux products owned by the Company 
were recognized at the time of shipment when the risk of ownership and loss are passed to the customer. Under IFRS 15, where the 
revenue contract provides a right to invoice prior to the physical delivery of the product, the Company will defer such revenues and 
recognize a contract liability, until such time when the product has been physically delivered and the transfer of control has occurred.  

(iii)  Leases 

On adoption of IFRS 16, the Company has recognised lease liabilities in relation to all lease arrangements measured at the present 
value of the remaining lease payments from commitments disclosed as at December 31, 2017, adjusted by commitments in relation 
to arrangements not containing leases, short-term and low-value leases, discounted using the Company’s incremental borrowing rate 
as of January 1, 2018. The associated right-of-use assets were measured at the amount equal to the lease liability on January 1, 2018, 
adjusted by the amount of any prepaid or accrued lease payments relating to that lease recognised in the statement of financial 
position immediately before the date of transition, with no impact on retained earnings. 

New standards and interpretations issued but not yet adopted: 

• 

• 

• 

The annual improvements IAS 19 – Employee benefits (“IAS 19”), has been amended to (i) require current service cost and 
net interest for the period after the re-measurement to be determined using the assumptions used for the re-measurement, 
and (ii) clarify the effect of a plan amendment, curtailment or settlement on the requirements regarding the asset ceiling. 
The amendment to IAS 19 is effective for the years beginning on or after January 1, 2019. The Company is currently assessing 
the impact of this amendment. 

IFRS 3 – Business Combinations (“IFRS 3”), has been amended to revise the definition of a business to include an input and 
a substantive process that together significantly contribute to the ability to create outputs. The amendment to IFRS 3 is 
effective  for  the  years  beginning  on  or  after  January  1,  2020.  The  Company  is  currently  assessing  the  impact  of  this 
amendment.  

IAS 1 – Presentation of financial statements (“IAS 1”) and IAS 8 – Accounting policies, changes in accounting estimates and 
errors (“IAS 8”), have been amended to (i) use a consistent definition of materiality throughout IFRSs and the Conceptual 
Framework for Financial Reporting; (ii) clarify the explanation of the definition of material; and iii) incorporate guidance in 
IAS 1 regarding immaterial information. The amendments to IAS 1 and IAS 8 are effective for the years beginning on or after 
January 1, 2020. 

DISCLOSURE CONTROLS & PROCEDURES  

As  part  of  the  requirements  mandated  by  the  Canadian  securities  regulatory  authorities  under  National  Instrument  52-109-
Certification of Disclosure in Issuers' Annual and Interim Filings ("NI 52-109"), the Company’s Chief Executive Officer ("CEO") and the 
Chief  Financial  Officer  ("CFO")  have  evaluated  the  design  and  operation  of  the  Company's  disclosure  controls  and  procedures 
("DC&P"), as such term is defined in NI 52-109, as at December 31, 2018. The CEO and CFO are also responsible for establishing and 
maintaining  internal  controls  over  financial  reporting,  ("ICFR"),  as  such  term  is  defined  in  NI  52-109.  In  making  its  assessment, 
management  used  the  Committee  of  Sponsoring  Organizations  of  the  Treadway  Commission  framework  in  Internal  Control  – 
Integrated Framework (2013) to evaluate the design and effectiveness of internal control over financial reporting. These controls are 
designed to provide reasonable assurance regarding the reliability of the Company’s financial reporting and compliance with IFRS. 
The  Company’s  CEO  and  CFO  have  evaluated,  or  caused  to  be  evaluated  under  their  supervision,  the  design  and  operational 
effectiveness of such controls as at December 31, 2018. 

Based on the evaluation of the design and operating effectiveness of the Company’s DC&P and ICFR, the CEO and the CFO concluded 
that Gibson DC&P and ICFR were effective as at December 31, 2018. There have been no changes in ICFR that occurred during the 
period beginning January 1, 2018 and ended on December 31, 2018 that has materially affected or is reasonably likely to materially 
affect Gibson ICFR. 

- 

Segment profit from continuing operations increased by $11.2 million and $49.7 million, respectively, segment profit from 

discontinued operations increased by $0.4 million and $3.1 million, respectively, and G&A expenses decreased by $2.0 

million and $8.2 million, respectively with a total increase of $11.6 million and $52.8 million, respectively in combined 

- 

This was substantially offset by the additional depreciation charge on the right-of use-assets and interest expense for the 

In addition, the impacts of IFRS 9, 15 and 16, including the new accounting policies adopted as at January 1, 2018 on the balance 

Adjusted EBITDA.  

lease liabilities. 

sheet are as follows: 

31, 2017 

Adjustments 

Footnote 

Accounts receivable .......................................................  

Inventories ......................................................................  

Trade payables and accrued charges .............................  

Right-of-use asset ...........................................................  

Contract liabilities ...........................................................  

Deferred revenue ...........................................................  

(7,013)

Lease liability – current portion ......................................  

Lease liability – non-current portion ..............................  

Retained deficit (earnings) .............................................  

Total  ...............................................................................  

  1,251,416

$ 1,408,599

 $     

  484

4,765

3,329

170,548

(12,676)

7,013

(43,490)

(129,344)

(629)

$                -

(ii & iii) 

(i) 

(ii) 

(iii) 

(ii) 

(ii) 

(iii) 

(iii) 

(i & ii) 

As reported as 

at December 

  $   494,901

    169,957

   (500,662)

-

-

-

-

Restated 

balance as at 

January 1, 2018 

  $       495,385

    174,722

   (497,333)

170,548

    (12,676)

-

    (43,490)

(129,344)

  1,250,787

$    1,408,599

Footnotes 

(i)  Financial instruments 

 

Trade receivables 

  Net investments in finance leases 

The Company carries the following categories of financial assets subject to IFRS 9’s expected credit losses model: 

The Company has revised its impairment methodology under IFRS 9 for the above noted classes of assets and applied the simplified 

approach on all trade receivables which requires the use of the lifetime expected loss provisions for expected credit losses. For lease 

receivables, the Company used the general approach which requires the recognition of twelve-month expected loss provisions for 

expected credit losses on lease receivables subject to credit risk as at January 1, 2018. Where such lease receivables have had a 

significant increase in credit risk since initial recognition but no objective evidence of impairment, lifetime expected loss provisions 

are used with interest calculated on the gross carrying amount of the receivable balance. Where objective evidence of impairment 

exists, interest is calculated on the carrying amount, net of the impairment. At December 31, 2018, there were no material changes 

to the credit risk on lease receivables. 

There was no impact to the classification of the Company’s financial assets from the adoption of IFRS 9. 

      Gibson Energy Inc.                                                            35                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            36                                              Management’s Discussion and Analysis  

37 

Management’s Discussion and Analysis

Gibson Energy 

 
 
  
 
 
 
 
 
 
 
 
 
 
 
   
   
   
   
   
   
   
   
   
 
 
 
 
 
 
 
 
RISK FACTORS  

Shareholders and prospective investors should carefully consider the risk factors noted below before investing in Gibson securities, 
as each of these risks may negatively affect the trading price of Gibson securities, the amount of dividends paid to shareholders and 
the ability of Gibson to fund its debt obligations, including debt obligations under its outstanding Debentures and any other debt 
securities that Gibson may issue from time to time. For a further discussion of the risks identified in this MD&A, other risks and trends 
that could affect Gibson performance and the steps that Gibson takes to mitigate these risks, readers are referred to Gibson AIF, 
which is available on SEDAR at www.sedar.com.  

Reputation 

Hazards and Operational Risks 

The  Company’s  operations  are  subject  to  the  many  hazards  inherent  in  the  transportation,  storage,  processing,  treating  and 
distribution of crude oil, NGLs and petroleum products, including: 

 
 
 
 
 

explosions, fires and accidents, including road and rail accidents; 
damage to the Company’s tanker trucks, pipelines, storage tanks, terminals and related equipment; 
ruptures, leaks or releases of crude oil or petroleum products into the environment; 
acts of terrorism or vandalism; and 
other accident or hazards that may occur at or during transport to, or from, commercial or industrial sites.  

If any of these events were to occur, the Company could suffer substantial losses because of the resulting impact on the Company’s 
reputation, personal injury or loss of life, severe damage to and destruction of property, equipment, information technology systems, 
related data and control systems, environmental damage, which may include polluting water, land or air, resulting in curtailment or 
suspension of the related operations. Mechanical malfunctions, faulty measurement or other errors may also result in significant 
costs or lost revenues. 

Market and Commodity Price Risk 

The Company’s business includes activities related to product storage, terminalling and hub services.  These activities  expose the 
Company to certain risks including that the Company may experience volatility in revenue and impairments related to the book value 
of stored product, due to the fluctuations in commodity prices. Primarily, the Company enters into contracts to purchase and sell 
crude oil, NGLs and refined products at floating market prices. The prices of the products that are marketed by the Company are 
subject to volatility as a result of factors such as seasonal demand changes, extreme weather conditions, market inventory levels, 
general economic conditions, changes in crude oil markets and other factors. The Company manages its risk exposure by balancing 
purchases and sales to lock-in margins; however, the Company may not be successful in balancing its purchases and sales. Also, in 
certain situations, a producer or supplier could fail to deliver contracted volumes or could deliver in excess of contracted volumes or 
a purchaser could purchase less than contracted volumes. Any of these actions could cause the Company’s purchases and sales to be 
unbalanced. While the Company attempts to balance its purchases and sales, if its purchases and sales are unbalanced, the Company 
will face increased exposure to commodity price risks and could have increased volatility in its operating income and cash flow. 
Notwithstanding the Company’s management of price and quality risk, marketing margins for commodities can vary and have varied 
significantly from period to period. This variability could have an adverse effect on the results of the Company.  

Since  crude  oil  margins  can  be  earned  by  capturing  spreads  between  different  qualities  of  crude  oil,  the  Company’s  crude  oil 
marketing business is subject to volatility in price differentials between crude oil streams and blending agents. Due to this volatility, 
the Company’s margins and profitability can vary significantly. The Company expects that commodity prices will continue to fluctuate 
significantly in the future. The Company utilizes financial derivative instruments as part of its overall risk management strategy to 
assist in managing the exposure to commodity prices, as well as interest rates and foreign exchange risks. For example, as NGL and 
refined product prices are somewhat related to the price of crude oil, crude oil financial contracts are one of the more common price 
risk management strategies that the Company uses. Also, with respect to crude oil, the Company manages its exposure using WTI 
based futures, options and swaps. These strategies are subject to basis risk between the prices of crude oil streams, WTI, NGL and 
refined product values and, therefore, may not fully offset future price movements. Furthermore, there is no guarantee that these 
strategies and other efforts to manage marketing and inventory risks will generate profits or mitigate all the market and inventory 
risk associated with these activities. If the Company utilizes price risk management strategies, the Company may forego the benefits 
that  may  otherwise  be  experienced  if  commodity  prices  were  to  increase.  In  addition,  any  non-compliance  with  the  Company’s 
trading  policies  could  result  in  significantly  adverse  financial  effects.  To  the  extent  that  the  Company  engages  in  these  kinds  of 

Management’s Discussion and Analysis 

      Gibson Energy Inc.                                                            37                                              Management’s Discussion and Analysis  
Gibson Energy

38 

activities, the Company is also subject to credit risks associated with counterparties  with whom the Company has contracts. The 

Company does not trade financial instruments for speculative purposes. 

The Company relies on its reputation to build and maintain positive relationships with its stakeholders, to recruit and retain staff, and 

to be a credible, trusted company. Reputational risk is the potential for negative impacts that could result from the deterioration of 

the  Company’s  reputation  with  key  stakeholders.  The  potential  for  harming  the  Company’s  corporate  reputation  exists  in  every 

business decision and public interaction, which in turn can negatively impact the Company’s business and its securities. Reputational 

risk  cannot  be  managed  in  isolation  from  other  forms  of  risk.  Credit,  market,  operational,  insurance,  liquidity,  regulatory, 

environmental  and  legal  risks  must  all  be  managed  effectively  to  safeguard  the  Company’s  reputation.  Negative  impacts  from  a 

compromised reputation could include revenue loss, reduction in customer base and diminution of share price. 

Decommissioning, Abandonment and Reclamation Costs 

The Company is responsible for compliance with all applicable laws and regulations regarding the decommissioning, abandonment 

and reclamation of the Company’s facilities and pipelines at the end of their economic life, the costs of which may be substantial. It 

is  not  possible  to  predict  these  costs  with  certainty  since  they  will  be  a  function  of  regulatory  requirements  at  the  time  of 

decommissioning, abandonment and reclamation. The Company may, in the future, be required by applicable laws or regulations to 

establish and fund one or more decommissioning, abandonment and reclamation reserve funds to provide for payment of future 

decommissioning, abandonment and reclamation costs, which could decrease funds available to the Company to execute its business 

plan  and  service  its  debt  obligations.  In  addition,  such  reserves,  if  established,  may  not  be  sufficient  to  satisfy  such  future 

decommissioning, abandonment and reclamation costs and the Company will be responsible for the payment of the balance of such 

costs. 

Legislative and Regulatory Changes 

The Company’s industry is highly regulated. There can be no guarantee that laws and other government programs relating to the oil 

and gas industry, the energy services industry and the transportation industry will not be changed in a manner which directly and 

adversely affects the Company’s business. There can also be no assurance that the laws, regulations or rules governing the Company’s 

customers will not be changed in a manner which adversely affects the Company’s customers and, therefore, the Company’s business. 

In addition, the Company’s pipelines and facilities are potentially subject to common carrier and common processor applications and 

to rate setting by regulatory authorities in the event agreement on fees or tariffs cannot be reached with producers. To the extent 

that producers believe processing fees or tariffs with respect to pipelines and facilities are too high, they may seek rate relief through 

regulatory  means.  If  regulations  were  passed  lowering  or  capping  the  Company’s  rates  and  tariffs,  the  Company’s  results  of 

operations and cash flows could be adversely affected. 

Petroleum products that the Company stores and transports are sold by the Company’s customers for consumption into the public 

market. Various federal, provincial, state and local agencies have the authority to prescribe specific product quality specifications for 

commodities  sold  into  the  public  market.  Changes  in  product  quality  specifications  or  blending  requirements  could  reduce  the 

Company’s throughput volume, require the Company to incur additional handling costs or require capital expenditures. For instance, 

different product specifications for different markets impact the fungibility of the products in the Company’s system and could require 

the construction of additional storage. If the Company is unable to recover these costs through increased revenues, the Company’s 

cash flows could be adversely affected. In addition, changes in the quality of the products the Company receives on its petroleum 

products pipeline system could reduce or eliminate the Company’s ability to blend products. 

The Company’s cross-border activities are subject to additional regulation, including import and export licenses, tariffs, Canadian and 

U.S.  customs  and  tax  issues  and  toxic  substance  certifications.  Such  regulations  include  the  Short  Supply  Controls  of  the  Export 

Administration Act, the United States-Mexico-Canada Agreement, the Toxic Substances Control Act and the Canadian Environmental 

Protection Act, 1999. Violations of these licensing, tariff and tax reporting requirements could result in the imposition of significant 

administrative, civil and criminal penalties. 

In addition, local, consumption and income tax laws relating to the Company may be changed in a manner which adversely affects 

the Company. 

      Gibson Energy Inc.                                                            38                                              Management’s Discussion and Analysis  

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
RISK FACTORS  

Shareholders and prospective investors should carefully consider the risk factors noted below before investing in Gibson securities, 

as each of these risks may negatively affect the trading price of Gibson securities, the amount of dividends paid to shareholders and 

the ability of Gibson to fund its debt obligations, including debt obligations under its outstanding Debentures and any other debt 

securities that Gibson may issue from time to time. For a further discussion of the risks identified in this MD&A, other risks and trends 

that could affect Gibson performance and the steps that Gibson takes to mitigate these risks, readers are referred to Gibson AIF, 

which is available on SEDAR at www.sedar.com.  

Hazards and Operational Risks 

The  Company’s  operations  are  subject  to  the  many  hazards  inherent  in  the  transportation,  storage,  processing,  treating  and 

distribution of crude oil, NGLs and petroleum products, including: 

explosions, fires and accidents, including road and rail accidents; 

damage to the Company’s tanker trucks, pipelines, storage tanks, terminals and related equipment; 

ruptures, leaks or releases of crude oil or petroleum products into the environment; 

acts of terrorism or vandalism; and 

other accident or hazards that may occur at or during transport to, or from, commercial or industrial sites.  

 

 

 

 

 

If any of these events were to occur, the Company could suffer substantial losses because of the resulting impact on the Company’s 

reputation, personal injury or loss of life, severe damage to and destruction of property, equipment, information technology systems, 

related data and control systems, environmental damage, which may include polluting water, land or air, resulting in curtailment or 

suspension of the related operations. Mechanical malfunctions, faulty measurement or other errors may also result in significant 

costs or lost revenues. 

Market and Commodity Price Risk 

The Company’s business includes activities related to product storage, terminalling and hub services.  These activities  expose the 

Company to certain risks including that the Company may experience volatility in revenue and impairments related to the book value 

of stored product, due to the fluctuations in commodity prices. Primarily, the Company enters into contracts to purchase and sell 

crude oil, NGLs and refined products at floating market prices. The prices of the products that are marketed by the Company are 

subject to volatility as a result of factors such as seasonal demand changes, extreme weather conditions, market inventory levels, 

general economic conditions, changes in crude oil markets and other factors. The Company manages its risk exposure by balancing 

purchases and sales to lock-in margins; however, the Company may not be successful in balancing its purchases and sales. Also, in 

certain situations, a producer or supplier could fail to deliver contracted volumes or could deliver in excess of contracted volumes or 

a purchaser could purchase less than contracted volumes. Any of these actions could cause the Company’s purchases and sales to be 

unbalanced. While the Company attempts to balance its purchases and sales, if its purchases and sales are unbalanced, the Company 

will face increased exposure to commodity price risks and could have increased volatility in its operating income and cash flow. 

Notwithstanding the Company’s management of price and quality risk, marketing margins for commodities can vary and have varied 

significantly from period to period. This variability could have an adverse effect on the results of the Company.  

Since  crude  oil  margins  can  be  earned  by  capturing  spreads  between  different  qualities  of  crude  oil,  the  Company’s  crude  oil 

marketing business is subject to volatility in price differentials between crude oil streams and blending agents. Due to this volatility, 

the Company’s margins and profitability can vary significantly. The Company expects that commodity prices will continue to fluctuate 

significantly in the future. The Company utilizes financial derivative instruments as part of its overall risk management strategy to 

assist in managing the exposure to commodity prices, as well as interest rates and foreign exchange risks. For example, as NGL and 

refined product prices are somewhat related to the price of crude oil, crude oil financial contracts are one of the more common price 

risk management strategies that the Company uses. Also, with respect to crude oil, the Company manages its exposure using WTI 

based futures, options and swaps. These strategies are subject to basis risk between the prices of crude oil streams, WTI, NGL and 

refined product values and, therefore, may not fully offset future price movements. Furthermore, there is no guarantee that these 

strategies and other efforts to manage marketing and inventory risks will generate profits or mitigate all the market and inventory 

risk associated with these activities. If the Company utilizes price risk management strategies, the Company may forego the benefits 

that  may  otherwise  be  experienced  if  commodity  prices  were  to  increase.  In  addition,  any  non-compliance  with  the  Company’s 

trading  policies  could  result  in  significantly  adverse  financial  effects.  To  the  extent  that  the  Company  engages  in  these  kinds  of 

      Gibson Energy Inc.                                                            37                                              Management’s Discussion and Analysis  

activities, the Company is also subject to credit risks associated with counterparties  with whom the Company has contracts. The 
Company does not trade financial instruments for speculative purposes. 

Reputation 

The Company relies on its reputation to build and maintain positive relationships with its stakeholders, to recruit and retain staff, and 
to be a credible, trusted company. Reputational risk is the potential for negative impacts that could result from the deterioration of 
the  Company’s  reputation  with  key  stakeholders.  The  potential  for  harming  the  Company’s  corporate  reputation  exists  in  every 
business decision and public interaction, which in turn can negatively impact the Company’s business and its securities. Reputational 
risk  cannot  be  managed  in  isolation  from  other  forms  of  risk.  Credit,  market,  operational,  insurance,  liquidity,  regulatory, 
environmental  and  legal  risks  must  all  be  managed  effectively  to  safeguard  the  Company’s  reputation.  Negative  impacts  from  a 
compromised reputation could include revenue loss, reduction in customer base and diminution of share price. 

Decommissioning, Abandonment and Reclamation Costs 

The Company is responsible for compliance with all applicable laws and regulations regarding the decommissioning, abandonment 
and reclamation of the Company’s facilities and pipelines at the end of their economic life, the costs of which may be substantial. It 
is  not  possible  to  predict  these  costs  with  certainty  since  they  will  be  a  function  of  regulatory  requirements  at  the  time  of 
decommissioning, abandonment and reclamation. The Company may, in the future, be required by applicable laws or regulations to 
establish and fund one or more decommissioning, abandonment and reclamation reserve funds to provide for payment of future 
decommissioning, abandonment and reclamation costs, which could decrease funds available to the Company to execute its business 
plan  and  service  its  debt  obligations.  In  addition,  such  reserves,  if  established,  may  not  be  sufficient  to  satisfy  such  future 
decommissioning, abandonment and reclamation costs and the Company will be responsible for the payment of the balance of such 
costs. 

Legislative and Regulatory Changes 

The Company’s industry is highly regulated. There can be no guarantee that laws and other government programs relating to the oil 
and gas industry, the energy services industry and the transportation industry will not be changed in a manner which directly and 
adversely affects the Company’s business. There can also be no assurance that the laws, regulations or rules governing the Company’s 
customers will not be changed in a manner which adversely affects the Company’s customers and, therefore, the Company’s business. 
In addition, the Company’s pipelines and facilities are potentially subject to common carrier and common processor applications and 
to rate setting by regulatory authorities in the event agreement on fees or tariffs cannot be reached with producers. To the extent 
that producers believe processing fees or tariffs with respect to pipelines and facilities are too high, they may seek rate relief through 
regulatory  means.  If  regulations  were  passed  lowering  or  capping  the  Company’s  rates  and  tariffs,  the  Company’s  results  of 
operations and cash flows could be adversely affected. 

Petroleum products that the Company stores and transports are sold by the Company’s customers for consumption into the public 
market. Various federal, provincial, state and local agencies have the authority to prescribe specific product quality specifications for 
commodities  sold  into  the  public  market.  Changes  in  product  quality  specifications  or  blending  requirements  could  reduce  the 
Company’s throughput volume, require the Company to incur additional handling costs or require capital expenditures. For instance, 
different product specifications for different markets impact the fungibility of the products in the Company’s system and could require 
the construction of additional storage. If the Company is unable to recover these costs through increased revenues, the Company’s 
cash flows could be adversely affected. In addition, changes in the quality of the products the Company receives on its petroleum 
products pipeline system could reduce or eliminate the Company’s ability to blend products. 

The Company’s cross-border activities are subject to additional regulation, including import and export licenses, tariffs, Canadian and 
U.S.  customs  and  tax  issues  and  toxic  substance  certifications.  Such  regulations  include  the  Short  Supply  Controls  of  the  Export 
Administration Act, the United States-Mexico-Canada Agreement, the Toxic Substances Control Act and the Canadian Environmental 
Protection Act, 1999. Violations of these licensing, tariff and tax reporting requirements could result in the imposition of significant 
administrative, civil and criminal penalties. 

In addition, local, consumption and income tax laws relating to the Company may be changed in a manner which adversely affects 
the Company. 

Gibson Energy 

      Gibson Energy Inc.                                                            38                                              Management’s Discussion and Analysis  

Management’s Discussion and Analysis

39 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Capital Project Delivery and Success 

The Company has a number of organic growth projects that require the expenditure of significant amounts of capital. Many of these 
projects  involve  numerous  regulatory,  environmental,  commercial,  weather-related,  political  and  legal  uncertainties  that  will  be 
beyond the Company’s control. As these projects are undertaken, required regulatory and other approvals may not be obtained, may 
be delayed or may be obtained with conditions that materially alter the expected return associated with the underlying projects. 
Moreover,  the  Company  will  incur  financing  costs  during  the  planning  and  construction  phases  of  its  growth  projects,  but  the 
operating cash flow the Company expects these projects to generate will not materialize until after the projects are completed. These 
projects may be completed behind schedule or in excess of budgeted cost. For example, the Company must compete with other 
companies for the materials and construction services required to complete these projects, and competition for these materials or 
services could result in significant delays and/or cost overruns. Any such cost overruns, or unanticipated delays in the completion or 
commercial development of these projects, could reduce the Company’s liquidity. The Company may construct facilities or other 
assets in anticipation of market demand that dissipates during the intervening period between project conception and delivery to 
market  or  never  materializes.  As  a  result  of  these  uncertainties,  the  anticipated  benefits  associated  with  the  Company’s  capital 
projects may not be lower than expected. 

Regulatory Approvals  

The Company’s operations require it to obtain approvals from various regulatory authorities and there are no guarantees that it will 
be  able  to  obtain  all  necessary  licenses,  permits  and  other  approvals  that  may  be  required  to  conduct  its  business.  In  addition, 
obtaining certain approvals from regulatory authorities can involve, among other things, stakeholder and Aboriginal consultation, 
environmental impact assessments and public hearings. Regulatory approvals obtained may be subject to the satisfaction of certain 
conditions, including, but not limited to: security deposit obligations; ongoing regulatory oversight of projects; mitigating or avoiding 
project impacts; habitat assessments; and other commitments or obligations. Failure to obtain applicable regulatory approvals or 
satisfy any of the conditions thereto on a timely basis on satisfactory terms could result in delays, abandonment or restructuring of 
projects and increased costs. 

Environmental and Health and Safety Regulations 

Each of the Company’s segments is subject to the risk of incurring substantial costs and liabilities under environmental and health 
and safety laws and regulations. These costs and liabilities arise under increasingly stringent environmental and health and safety 
laws, including regulations and governmental enforcement policies and legislation, and as a result of third party claims for damages 
to property or persons arising from the Company’s operations. Environmental laws and regulations impose, among other things, 
restrictions, liabilities and obligations in connection with the generation, handling, storage, transportation, treatment and disposal 
of hazardous substances and waste and in connection with spills, releases and emissions of various substances into the environment. 
Environmental  laws  and  regulations  also  require  that  pipelines,  facilities  and  other  properties  associated  with  the  Company’s 
operations be constructed, operated, maintained, abandoned and reclaimed to the satisfaction of applicable regulatory authorities. 
Health and safety laws and regulations impose, among other things, requirements designed to ensure the protection of workers and 
to limit the exposure of persons to certain hazardous substances. In addition, certain types of projects may be required to submit 
and  obtain  approval  of  environmental  impact  assessments,  to  obtain  and  maintain  environmental  permits  and  approvals  and  to 
implement mitigative measures prior to the implementation of such projects. 

Failure to comply with environmental and health and safety laws and regulations, including related permits and approvals, may result 
in assessment of administrative, civil and criminal penalties, the issuance of regulatory or judicial orders, the imposition of remedial 
obligations  such  as  clean-up  and  site  restoration  requirements,  the  payment  of  deposits,  liens,  the  amendment,  suspension  or 
revocation of permits and approvals and the potential issuance of injunctions to limit  or cease operations. If the  Company were 
unable to recover these costs through increased revenues, the Company’s ability to meet its financial obligations could be adversely 
affected. 

Some of the Company’s facilities have been used for many years to transport, distribute or store petroleum products. Over time the 
Company’s operations, or operations by the Company’s predecessors or third parties not under the Company’s control, may have 
resulted in the disposal or release of hydrocarbons or wastes at or from these properties upon which the facilities are situated or 
along over pipeline rights-of-way. In addition, some of the Company’s facilities are located on or near current or former refining and 

Management’s Discussion and Analysis 

      Gibson Energy Inc.                                                            39                                              Management’s Discussion and Analysis  
Gibson Energy

40 

terminal sites, and there is a risk that contamination is present on those sites. The Company may be subject to strict joint and several 

liability under a number of these environmental laws and regulations for such disposal and releases of hydrocarbons or wastes or the 

existence of contamination, even in circumstances where such activities or conditions were caused by third parties not under the 

Company’s control or were otherwise lawful at the time they occurred. 

Further, the transportation of hazardous materials and/or other substances in the Company’s pipelines or by truck or rail may result 

in environmental damage, including accidental releases that may cause death or injuries to humans, damage to third parties and 

natural resources, and/or result in federal and/or provincial civil and/or criminal penalties that could be material to the Company’s 

results of operations and cash flow. 

The Company engages in operations which handle hazardous materials. As a result of these and other activities, the segment is subject 

to  a  variety  of  federal,  state,  local  and  foreign  laws  and  regulations  relating  to  the  generation,  transport,  use  handling,  storage, 

treatment and exposure to and disposal of these materials, including record keeping, reporting and registration requirements. The 

Company  has  incurred  and  expects  to  continue  to  incur  expenditures  to  maintain  compliance  with  environmental  laws  and 

regulations. Moreover, some or all of the environmental laws and regulations to which the Company is subject could become more 

stringent or be more stringently enforced in the future. Its failure to comply with applicable environmental laws and regulations and 

permit requirements could result in civil or criminal fines or penalties or enforcement actions, including regulatory or judicial orders 

enjoining or curtailing operations or requiring corrective measures or remedial actions. 

Certain environmental laws, including the Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”) and 

comparable state laws in the U.S., impose joint and several liability, without regard to fault or legality of the operations, on certain 

categories of persons, including current and prior owners or operators of a facility where there is a release or threatened release of 

hazardous substances, transporters of hazardous substances and entities that arranged for disposal of the hazardous substances at 

the site. Under CERCLA, these “responsible persons” may be held jointly and severally liable for the costs of cleaning up the hazardous 

substances, as well as for damages to natural resources and for the costs of certain health studies, relocation expenses and other 

response costs. 

CERCLA  generally  exempts  “petroleum”  from  the  definition  of  hazardous  substance;  however,  in  the  course  of  the  Company’s 

operations,  the  Company  has  accepted,  handled,  transported  and/or  generated  materials  that  are  considered  “hazardous 

substances.”  Further,  hazardous  substances  or  hazardous  wastes  may  have  been  released  at  properties  owned  or  leased  by  the 

Company now or in the past, or at other locations where these substances or wastes were taken for treatment or disposal. Given the 

nature of the Company’s environmental services business, it has incurred, and will in the future periodically incur, liabilities under 

CERCLA or other environmental cleanup laws, at its current or former facilities, adjacent or nearby third party facilities, or offsite 

disposal  locations.  There  can  be  no  assurance  that  the  costs  associated  with  future  cleanup  activities  that  the  Company  may  be 

required  to  conduct  or  finance  will  not  be  material.  Additionally,  the  Company  may  become  liable  to  third  parties  for  damages, 

including personal injury and property damage, resulting from the disposal or release of hazardous substances into the environment. 

Failure to comply with environmental regulations could have an adverse impact on the Company’s reputation. There is also risk that 

the Company could face litigation initiated by third parties relating to climate change or other environmental regulations. 

Demand for Crude Oil and Petroleum Products 

Any  sustained  decrease  in  demand  for  crude  oil  and  petroleum  products  in  the  markets  the  Company  serves  could  result  in  a 

significant reduction in the volume of products and services that the Company provides and thereby could significantly reduce cash 

flow and revenues. Factors that could lead to a decrease in market demand include: 

 

 

 

lower demand by consumers for refined products, including asphalt and wellsite fluids, as a result of recession or other 

adverse economic conditions or due to high prices caused by an increase in the market price of crude oil, which is subject to 

wide fluctuations in response to changes in global and regional supply over which the Company has no control; 

an  increase  in  fuel  economy,  whether  as  a  result  of  a  shift  by  consumers  to  more  fuel-efficient  vehicles,  technological 

advances by manufacturers, governmental or regulatory actions or otherwise; 

provincial, state and federal legislation either already in place or under development requiring the inclusion of ethanol and 

use of biodiesel which may negatively affect the overall demand for crude oil products; 

      Gibson Energy Inc.                                                            40                                              Management’s Discussion and Analysis  

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Capital Project Delivery and Success 

The Company has a number of organic growth projects that require the expenditure of significant amounts of capital. Many of these 

projects  involve  numerous  regulatory,  environmental,  commercial,  weather-related,  political  and  legal  uncertainties  that  will  be 

beyond the Company’s control. As these projects are undertaken, required regulatory and other approvals may not be obtained, may 

be delayed or may be obtained with conditions that materially alter the expected return associated with the underlying projects. 

Moreover,  the  Company  will  incur  financing  costs  during  the  planning  and  construction  phases  of  its  growth  projects,  but  the 

operating cash flow the Company expects these projects to generate will not materialize until after the projects are completed. These 

projects may be completed behind schedule or in excess of budgeted cost. For example, the Company must compete with other 

companies for the materials and construction services required to complete these projects, and competition for these materials or 

services could result in significant delays and/or cost overruns. Any such cost overruns, or unanticipated delays in the completion or 

commercial development of these projects, could reduce the Company’s liquidity. The Company may construct facilities or other 

assets in anticipation of market demand that dissipates during the intervening period between project conception and delivery to 

market  or  never  materializes.  As  a  result  of  these  uncertainties,  the  anticipated  benefits  associated  with  the  Company’s  capital 

projects may not be lower than expected. 

Regulatory Approvals  

terminal sites, and there is a risk that contamination is present on those sites. The Company may be subject to strict joint and several 
liability under a number of these environmental laws and regulations for such disposal and releases of hydrocarbons or wastes or the 
existence of contamination, even in circumstances where such activities or conditions were caused by third parties not under the 
Company’s control or were otherwise lawful at the time they occurred. 

Further, the transportation of hazardous materials and/or other substances in the Company’s pipelines or by truck or rail may result 
in environmental damage, including accidental releases that may cause death or injuries to humans, damage to third parties and 
natural resources, and/or result in federal and/or provincial civil and/or criminal penalties that could be material to the Company’s 
results of operations and cash flow. 

The Company engages in operations which handle hazardous materials. As a result of these and other activities, the segment is subject 
to  a  variety  of  federal,  state,  local  and  foreign  laws  and  regulations  relating  to  the  generation,  transport,  use  handling,  storage, 
treatment and exposure to and disposal of these materials, including record keeping, reporting and registration requirements. The 
Company  has  incurred  and  expects  to  continue  to  incur  expenditures  to  maintain  compliance  with  environmental  laws  and 
regulations. Moreover, some or all of the environmental laws and regulations to which the Company is subject could become more 
stringent or be more stringently enforced in the future. Its failure to comply with applicable environmental laws and regulations and 
permit requirements could result in civil or criminal fines or penalties or enforcement actions, including regulatory or judicial orders 
enjoining or curtailing operations or requiring corrective measures or remedial actions. 

The Company’s operations require it to obtain approvals from various regulatory authorities and there are no guarantees that it will 

be  able  to  obtain  all  necessary  licenses,  permits  and  other  approvals  that  may  be  required  to  conduct  its  business.  In  addition, 

obtaining certain approvals from regulatory authorities can involve, among other things, stakeholder and Aboriginal consultation, 

environmental impact assessments and public hearings. Regulatory approvals obtained may be subject to the satisfaction of certain 

conditions, including, but not limited to: security deposit obligations; ongoing regulatory oversight of projects; mitigating or avoiding 

project impacts; habitat assessments; and other commitments or obligations. Failure to obtain applicable regulatory approvals or 

satisfy any of the conditions thereto on a timely basis on satisfactory terms could result in delays, abandonment or restructuring of 

Certain environmental laws, including the Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”) and 
comparable state laws in the U.S., impose joint and several liability, without regard to fault or legality of the operations, on certain 
categories of persons, including current and prior owners or operators of a facility where there is a release or threatened release of 
hazardous substances, transporters of hazardous substances and entities that arranged for disposal of the hazardous substances at 
the site. Under CERCLA, these “responsible persons” may be held jointly and severally liable for the costs of cleaning up the hazardous 
substances, as well as for damages to natural resources and for the costs of certain health studies, relocation expenses and other 
response costs. 

CERCLA  generally  exempts  “petroleum”  from  the  definition  of  hazardous  substance;  however,  in  the  course  of  the  Company’s 
operations,  the  Company  has  accepted,  handled,  transported  and/or  generated  materials  that  are  considered  “hazardous 
substances.”  Further,  hazardous  substances  or  hazardous  wastes  may  have  been  released  at  properties  owned  or  leased  by  the 
Company now or in the past, or at other locations where these substances or wastes were taken for treatment or disposal. Given the 
nature of the Company’s environmental services business, it has incurred, and will in the future periodically incur, liabilities under 
CERCLA or other environmental cleanup laws, at its current or former facilities, adjacent or nearby third party facilities, or offsite 
disposal  locations.  There  can  be  no  assurance  that  the  costs  associated  with  future  cleanup  activities  that  the  Company  may  be 
required  to  conduct  or  finance  will  not  be  material.  Additionally,  the  Company  may  become  liable  to  third  parties  for  damages, 
including personal injury and property damage, resulting from the disposal or release of hazardous substances into the environment. 

Failure to comply with environmental regulations could have an adverse impact on the Company’s reputation. There is also risk that 
the Company could face litigation initiated by third parties relating to climate change or other environmental regulations. 

and  obtain  approval  of  environmental  impact  assessments,  to  obtain  and  maintain  environmental  permits  and  approvals  and  to 

Demand for Crude Oil and Petroleum Products 

implement mitigative measures prior to the implementation of such projects. 

Any  sustained  decrease  in  demand  for  crude  oil  and  petroleum  products  in  the  markets  the  Company  serves  could  result  in  a 
significant reduction in the volume of products and services that the Company provides and thereby could significantly reduce cash 
flow and revenues. Factors that could lead to a decrease in market demand include: 

 

 

 

lower demand by consumers for refined products, including asphalt and wellsite fluids, as a result of recession or other 
adverse economic conditions or due to high prices caused by an increase in the market price of crude oil, which is subject to 
wide fluctuations in response to changes in global and regional supply over which the Company has no control; 
an  increase  in  fuel  economy,  whether  as  a  result  of  a  shift  by  consumers  to  more  fuel-efficient  vehicles,  technological 
advances by manufacturers, governmental or regulatory actions or otherwise; 
provincial, state and federal legislation either already in place or under development requiring the inclusion of ethanol and 
use of biodiesel which may negatively affect the overall demand for crude oil products; 

projects and increased costs. 

Environmental and Health and Safety Regulations 

Each of the Company’s segments is subject to the risk of incurring substantial costs and liabilities under environmental and health 

and safety laws and regulations. These costs and liabilities arise under increasingly stringent environmental and health and safety 

laws, including regulations and governmental enforcement policies and legislation, and as a result of third party claims for damages 

to property or persons arising from the Company’s operations. Environmental laws and regulations impose, among other things, 

restrictions, liabilities and obligations in connection with the generation, handling, storage, transportation, treatment and disposal 

of hazardous substances and waste and in connection with spills, releases and emissions of various substances into the environment. 

Environmental  laws  and  regulations  also  require  that  pipelines,  facilities  and  other  properties  associated  with  the  Company’s 

operations be constructed, operated, maintained, abandoned and reclaimed to the satisfaction of applicable regulatory authorities. 

Health and safety laws and regulations impose, among other things, requirements designed to ensure the protection of workers and 

to limit the exposure of persons to certain hazardous substances. In addition, certain types of projects may be required to submit 

Failure to comply with environmental and health and safety laws and regulations, including related permits and approvals, may result 

in assessment of administrative, civil and criminal penalties, the issuance of regulatory or judicial orders, the imposition of remedial 

obligations  such  as  clean-up  and  site  restoration  requirements,  the  payment  of  deposits,  liens,  the  amendment,  suspension  or 

revocation of permits and approvals and the potential issuance of injunctions to limit  or cease operations. If the  Company were 

unable to recover these costs through increased revenues, the Company’s ability to meet its financial obligations could be adversely 

affected. 

Some of the Company’s facilities have been used for many years to transport, distribute or store petroleum products. Over time the 

Company’s operations, or operations by the Company’s predecessors or third parties not under the Company’s control, may have 

resulted in the disposal or release of hydrocarbons or wastes at or from these properties upon which the facilities are situated or 

along over pipeline rights-of-way. In addition, some of the Company’s facilities are located on or near current or former refining and 

      Gibson Energy Inc.                                                            39                                              Management’s Discussion and Analysis  

      Gibson Energy Inc.                                                            40                                              Management’s Discussion and Analysis  

41 

Management’s Discussion and Analysis

Gibson Energy 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 

 
 

lower demand by the oil and gas drilling industry for products such as drilling mud additives and for wellsite fluids as a result 
of legislation regulating hydraulic fracturing currently being considered by the U.S. Congress, a number of U.S. states and 
the Province of Quebec; 
technological advances in the production and longevity of fuel cells and solar, electric and battery-powered engines; and 
fluctuations in demand for crude oil, such as those caused by refinery downtime or shutdowns. 

The Company cannot predict and does not have control over the impact of future economic and political conditions on the energy 
and petrochemical industries, which, in turn, could affect the demand for crude oil and petroleum products. As a result of decreased 
demand, the Company may experience a decrease in the Company’s margins and profitability. 

FORWARD-LOOKING INFORMATION 

Certain statements contained in this MD&A constitute forward-looking information, as such term is defined under applicable Canadian 
securities laws (“forward-looking information”). These statements relate to future events or the Company’s future performance. All 
statements other than statements of historical fact are forward-looking information. The use of any of the words ‘‘anticipate’’, ‘‘plan’’, 
‘‘contemplate’’, ‘‘continue’’, “aim”, “target”, “must”, “commit”, ‘‘estimate’’, ‘‘expect’’, ‘‘intend’’, ‘‘propose’’, ‘‘might’’, ‘‘may’’, ‘‘will’’, 
‘‘shall’’, ‘‘project’’, ‘‘should’’, ‘‘could’’, ‘‘would’’, ‘‘believe’’, ‘‘predict’’, ‘‘forecast’’, ‘‘pursue’’, ‘‘potential’’ and ‘‘capable’’ and similar 
expressions are intended to identify forward-looking information. These statements involve known and unknown risks, uncertainties 
and  other  factors  that  may  cause  actual  results  or  events  to  differ  materially  from  those  anticipated  in  such  forward-looking 
information. No assurance can be given that these expectations will prove to be correct and such forward-looking information included 
in this MD&A should not be unduly relied upon. These statements speak only as of the date of this MD&A. In particular, this MD&A 
contains forward-looking information pertaining to the following:  

• 
• 
• 

• 

• 
• 

• 
• 
• 

• 
• 

• 
• 
• 

• 

• 
• 
• 

• 
• 
• 
• 
• 

the realization of perceived benefits and ability to close the sale of assets and businesses as per the Company’s plans; 
the timing, the amount of proceeds from sale of non-core businesses, the closing thereof, along with the execution of planned 
capital programs; 
achieving the targets including but not limited to segment profits, payout ratio and leverage ratio as discussed under the strategy 
section;  
the addition or disposition of assets and changes in the services to be offered by the Company; 
the Company’s projections relating to target segment profit, distributable cash flow, distributable cash flow per share, and total 
cash flow; 
the Company’s projections relating to target leverage and payout ratios; 
the Company's investment in new equipment, technology, facilities and personnel; 
the Company's growth strategy to expand in existing and new markets including the anticipated benefits from the Company’s 
basin strategy; 
the availability of sufficient liquidity for planned growth; 
new  technology  and  drilling  methodology  being  deployed  towards  conventional  and  unconventional  production  within  the 
Company's operating areas; 
uncertainty and volatility relating to crude prices and price differentials between crude oil streams and blending agents; 
increased crude oil production and exploration activity on shore in North America, including from the Canadian oil sands; 
the expansion of midstream infrastructure in North America to handle increased production and expansion of capacity in the U.S. 
refining complex to handle heavier crude oil from the WCSB; 
the effect of competition in regions of North America and its impact on downward pricing pressure and regional crude oil price 
differentials among crude oil grades and locations; 
the effect of market volatility on the Company's marketing revenues and activities; 
the Company's ability to pay down and retire indebtedness; 
the Company's plans for additional strategic acquisitions, capital expenditures or other similar transactions, including the costs 
thereof; 
in-service dates for new storage capacity and new projects being constructed by the Company; 
the Company's planned hedging activities;  
the Company's projections of commodity purchase and sales activities; 
the Company's projections of currency and interest rate fluctuations; 
The Company’s projections with respect to the adoption and implementation of new accounting standards and policies; 

Management’s Discussion and Analysis 

      Gibson Energy Inc.                                                            41                                              Management’s Discussion and Analysis  
Gibson Energy

42 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

the realization of anticipated benefits from the implementation of cost saving measures; 

the Company’s projections of dividends; and 

the Company's dividend policy. 

With respect to forward-looking information contained in this MD&A, assumptions have been made regarding, among other things:  

future growth in world-wide demand for crude oil and petroleum products; 

crude oil prices; 

manner; 

no material defaults by the counterparties to agreements with the Company;  

the Company's ability to obtain qualified personnel, owner-operators, lease operators and equipment in a timely and cost-efficient 

the regulatory framework governing taxes and environmental matters in the jurisdictions in which the Company conducts and 

will conduct its business; 

changes in credit ratings applicable to the Company; 

operating costs; 

future capital expenditures to be made by the Company; 

the Company's future debt levels;  

the impact of increasing competition on the Company;  

the Company's ability to obtain financing for its capital programs on acceptable terms; 

the impact of future changes in accounting policies on the Company’s consolidated financial statements; 

the Company’s ability to successfully implement the plans and programs disclosed in the Company’s new strategy; 

the Company’s ability to divest of its non-core businesses on acceptable terms, and the timing therefore; and 

the Company’s ability to transition to a focused oil infrastructure growth company. 

In addition, this MD&A may contain forward-looking information attributed to third party industry sources. The Company does not 

undertake any obligations to publicly update or revise any forward-looking information except as required by applicable Canadian 

securities laws. Actual results could differ materially from those anticipated in forward-looking information as a result of numerous 

risks and uncertainties including, but not limited to, the risks and uncertainties described in “Forward-Looking Information” and “Risk 

Factors” included in the Company’s Annual Information Form dated March 4, 2019 as filed on SEDAR at www.sedar.com and available 

on the Gibson website at www.gibsonenergy.com. 

NON-GAAP FINANCIAL MEASURES 

This  MD&A  refers  to  certain  financial  measures  that  are  not  determined  in  accordance  with  IFRS.  Combined  Revenue,  Combined 

Segment  Profit,  Adjusted  EBITDA  from  continuing  operations  and  discontinued  operations,  Adjusted  EBITDA  from  combined 

operations, Pro Forma Adjusted EBITDA from continuing operations, Pro Forma Adjusted EBITDA from discontinued operations and 

combined operations, distributable cash flow from continued and combined operations are not measures recognized under IFRS and 

do not have standardized meanings prescribed by IFRS and, therefore, may not be comparable to similar measures reported by other 

entities. Management considers these to be important supplemental measures of the Company’s performance and believes these 

measures are frequently used by securities analysts, investors and other interested parties in the evaluation of companies in industries 

with similar capital structures. See “Results of Continuing Operations” and “Results of Discontinued Operations”” for a reconciliation 

of Segment Profit to net income (loss), the IFRS measure most directly comparable to Segment Profit. See “Summary of Quarterly 

Results”  for  a  reconciliation  of  Adjusted  EBITDA  from  continuing,  discontinued,  and  combined  operations  to  Segment  Profit  from 

continuing, discontinued and combined operations. Distributable cash flow from continuing and combined operations is used to assess 

the level of cash flow generated from ongoing operations and to evaluate the adequacy of internally generated cash flow to fund 

dividends. See ‘‘Distributable Cash Flow” for a reconciliation of distributable cash flow to cash flow from operations, the IFRS measure 

most directly comparable to distributable cash flow. 

Readers  are  encouraged  to  evaluate  each  adjustment  and  the  reasons  the  Company  considers  it  appropriate  for  supplemental 

analysis.  Readers  are  cautioned,  however,  that  these  measures  should  not  be  construed  as  an  alternative  to  net  income  (loss) 

determined in accordance with IFRS as an indication of the Company’s performance. 

      Gibson Energy Inc.                                                            42                                              Management’s Discussion and Analysis  

 
 
 
 
 
 
• 
• 
• 

the realization of anticipated benefits from the implementation of cost saving measures; 
the Company’s projections of dividends; and 
the Company's dividend policy. 

With respect to forward-looking information contained in this MD&A, assumptions have been made regarding, among other things:  

• 
• 
• 
• 

• 

• 
• 
• 
• 
• 
• 
• 
• 
• 
• 

future growth in world-wide demand for crude oil and petroleum products; 
crude oil prices; 
no material defaults by the counterparties to agreements with the Company;  
the Company's ability to obtain qualified personnel, owner-operators, lease operators and equipment in a timely and cost-efficient 
manner; 
the regulatory framework governing taxes and environmental matters in the jurisdictions in which the Company conducts and 
will conduct its business; 
changes in credit ratings applicable to the Company; 
operating costs; 
future capital expenditures to be made by the Company; 
the Company's ability to obtain financing for its capital programs on acceptable terms; 
the Company's future debt levels;  
the impact of increasing competition on the Company;  
the impact of future changes in accounting policies on the Company’s consolidated financial statements; 
the Company’s ability to successfully implement the plans and programs disclosed in the Company’s new strategy; 
the Company’s ability to divest of its non-core businesses on acceptable terms, and the timing therefore; and 
the Company’s ability to transition to a focused oil infrastructure growth company. 

In addition, this MD&A may contain forward-looking information attributed to third party industry sources. The Company does not 
undertake any obligations to publicly update or revise any forward-looking information except as required by applicable Canadian 
securities laws. Actual results could differ materially from those anticipated in forward-looking information as a result of numerous 
risks and uncertainties including, but not limited to, the risks and uncertainties described in “Forward-Looking Information” and “Risk 
Factors” included in the Company’s Annual Information Form dated March 4, 2019 as filed on SEDAR at www.sedar.com and available 
on the Gibson website at www.gibsonenergy.com. 

the addition or disposition of assets and changes in the services to be offered by the Company; 

the Company’s projections relating to target segment profit, distributable cash flow, distributable cash flow per share, and total 

NON-GAAP FINANCIAL MEASURES 

This  MD&A  refers  to  certain  financial  measures  that  are  not  determined  in  accordance  with  IFRS.  Combined  Revenue,  Combined 
Segment  Profit,  Adjusted  EBITDA  from  continuing  operations  and  discontinued  operations,  Adjusted  EBITDA  from  combined 
operations, Pro Forma Adjusted EBITDA from continuing operations, Pro Forma Adjusted EBITDA from discontinued operations and 
combined operations, distributable cash flow from continued and combined operations are not measures recognized under IFRS and 
do not have standardized meanings prescribed by IFRS and, therefore, may not be comparable to similar measures reported by other 
entities. Management considers these to be important supplemental measures of the Company’s performance and believes these 
measures are frequently used by securities analysts, investors and other interested parties in the evaluation of companies in industries 
with similar capital structures. See “Results of Continuing Operations” and “Results of Discontinued Operations”” for a reconciliation 
of Segment Profit to net income (loss), the IFRS measure most directly comparable to Segment Profit. See “Summary of Quarterly 
Results”  for  a  reconciliation  of  Adjusted  EBITDA  from  continuing,  discontinued,  and  combined  operations  to  Segment  Profit  from 
continuing, discontinued and combined operations. Distributable cash flow from continuing and combined operations is used to assess 
the level of cash flow generated from ongoing operations and to evaluate the adequacy of internally generated cash flow to fund 
dividends. See ‘‘Distributable Cash Flow” for a reconciliation of distributable cash flow to cash flow from operations, the IFRS measure 
most directly comparable to distributable cash flow. 

Readers  are  encouraged  to  evaluate  each  adjustment  and  the  reasons  the  Company  considers  it  appropriate  for  supplemental 
analysis.  Readers  are  cautioned,  however,  that  these  measures  should  not  be  construed  as  an  alternative  to  net  income  (loss) 
determined in accordance with IFRS as an indication of the Company’s performance. 

 

 

 

lower demand by the oil and gas drilling industry for products such as drilling mud additives and for wellsite fluids as a result 

of legislation regulating hydraulic fracturing currently being considered by the U.S. Congress, a number of U.S. states and 

the Province of Quebec; 

technological advances in the production and longevity of fuel cells and solar, electric and battery-powered engines; and 

fluctuations in demand for crude oil, such as those caused by refinery downtime or shutdowns. 

The Company cannot predict and does not have control over the impact of future economic and political conditions on the energy 

and petrochemical industries, which, in turn, could affect the demand for crude oil and petroleum products. As a result of decreased 

demand, the Company may experience a decrease in the Company’s margins and profitability. 

FORWARD-LOOKING INFORMATION 

Certain statements contained in this MD&A constitute forward-looking information, as such term is defined under applicable Canadian 

securities laws (“forward-looking information”). These statements relate to future events or the Company’s future performance. All 

statements other than statements of historical fact are forward-looking information. The use of any of the words ‘‘anticipate’’, ‘‘plan’’, 

‘‘contemplate’’, ‘‘continue’’, “aim”, “target”, “must”, “commit”, ‘‘estimate’’, ‘‘expect’’, ‘‘intend’’, ‘‘propose’’, ‘‘might’’, ‘‘may’’, ‘‘will’’, 

‘‘shall’’, ‘‘project’’, ‘‘should’’, ‘‘could’’, ‘‘would’’, ‘‘believe’’, ‘‘predict’’, ‘‘forecast’’, ‘‘pursue’’, ‘‘potential’’ and ‘‘capable’’ and similar 

expressions are intended to identify forward-looking information. These statements involve known and unknown risks, uncertainties 

and  other  factors  that  may  cause  actual  results  or  events  to  differ  materially  from  those  anticipated  in  such  forward-looking 

information. No assurance can be given that these expectations will prove to be correct and such forward-looking information included 

in this MD&A should not be unduly relied upon. These statements speak only as of the date of this MD&A. In particular, this MD&A 

contains forward-looking information pertaining to the following:  

the realization of perceived benefits and ability to close the sale of assets and businesses as per the Company’s plans; 

the timing, the amount of proceeds from sale of non-core businesses, the closing thereof, along with the execution of planned 

achieving the targets including but not limited to segment profits, payout ratio and leverage ratio as discussed under the strategy 

capital programs; 

section;  

cash flow; 

the Company’s projections relating to target leverage and payout ratios; 

the Company's investment in new equipment, technology, facilities and personnel; 

the Company's growth strategy to expand in existing and new markets including the anticipated benefits from the Company’s 

basin strategy; 

the availability of sufficient liquidity for planned growth; 

Company's operating areas; 

new  technology  and  drilling  methodology  being  deployed  towards  conventional  and  unconventional  production  within  the 

uncertainty and volatility relating to crude prices and price differentials between crude oil streams and blending agents; 

increased crude oil production and exploration activity on shore in North America, including from the Canadian oil sands; 

the expansion of midstream infrastructure in North America to handle increased production and expansion of capacity in the U.S. 

refining complex to handle heavier crude oil from the WCSB; 

the effect of competition in regions of North America and its impact on downward pricing pressure and regional crude oil price 

differentials among crude oil grades and locations; 

the effect of market volatility on the Company's marketing revenues and activities; 

the Company's ability to pay down and retire indebtedness; 

the Company's plans for additional strategic acquisitions, capital expenditures or other similar transactions, including the costs 

thereof; 

in-service dates for new storage capacity and new projects being constructed by the Company; 

the Company's planned hedging activities;  

the Company's projections of commodity purchase and sales activities; 

the Company's projections of currency and interest rate fluctuations; 

The Company’s projections with respect to the adoption and implementation of new accounting standards and policies; 

      Gibson Energy Inc.                                                            41                                              Management’s Discussion and Analysis  

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

• 

      Gibson Energy Inc.                                                            42                                              Management’s Discussion and Analysis  

43 

Management’s Discussion and Analysis

Gibson Energy 

 
 
 
 
 
 
This page intentionally left blank

Consolidated 

Financial Statements

For the years ended December 31, 2018 and 2017

Consolidated 
Financial Statements
For the years ended December 31, 2018 and 2017

Independent auditor’s report

To the Shareholders of Gibson Energy Inc.

Our opinion

In our opinion, the accompanying consolidated financial statements present fairly, in all material respects, 
the financial position of Gibson Energy Inc. and its subsidiaries (together, the Company) as at December 31, 
2018 and 2017, and its financial performance and its cash flows for the years then ended in accordance with 
International Financial Reporting Standards (IFRS).

What we have audited
The Company's consolidated financial statements comprise:

 

 

 

 

 

 

the consolidated balance sheets as at December 31, 2018 and 2017;

the consolidated statements of operations for the years then ended;

the consolidated statements of comprehensive income (loss) for the years then ended;

whether due to fraud or error.

the consolidated statements of changes in equity for the years then ended;

the consolidated statements of cash flows for the years then ended; and

the notes to the consolidated financial statements, which include a summary of significant 
accounting policies.

Basis for opinion

We conducted our audit in accordance with Canadian generally accepted auditing standards. Our 
responsibilities under those standards are further described in the Auditor’s responsibilities for the audit 
of the consolidated financial statements section of our report.

We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our 
opinion.

Independence
We are independent of the Company in accordance with the ethical requirements that are relevant to our 
audit of the consolidated financial statements in Canada. We have fulfilled our other ethical 
responsibilities in accordance with these requirements.

Other information

Management is responsible for the other information. The other information comprises the Management's 
Discussion and Analysis and the information, other than the consolidated financial statements and our 
auditor's report thereon, included in the annual report.

PricewaterhouseCoopers LLP
111 5th Avenue SW, Suite 3100, East Tower, Calgary, Alberta, Canada T2P 5L3
T: +1 403 509 7500, F: +1 403 781 1825, www.pwc.com/ca

“PwC” refers to PricewaterhouseCoopers LLP, an Ontario limited liability partnership. 

Our opinion on the consolidated financial statements does not cover the other information and we do not 

express any form of assurance conclusion thereon.

In connection with our audit of the consolidated financial statements, our responsibility is to read the 

other information identified above and, in doing so, consider whether the other information is materially 

inconsistent with the consolidated financial statements or our knowledge obtained in the audit, or 

otherwise appears to be materially misstated.

If, based on the work we have performed, we conclude that there is a material misstatement of this other 

information, we are required to report that fact. We have nothing to report in this regard.

Responsibilities of management and those charged with governance for the 

consolidated financial statements

Management is responsible for the preparation and fair presentation of the consolidated financial 

statements in accordance with IFRS, and for such internal control as management determines is necessary 

to enable the preparation of consolidated financial statements that are free from material misstatement, 

In preparing the consolidated financial statements, management is responsible for assessing the 

Company's ability to continue as a going concern, disclosing, as applicable, matters related to going 

concern and using the going concern basis of accounting unless management either intends to liquidate 

the Company or to cease operations, or has no realistic alternative but to do so.

Those charged with governance are responsible for overseeing the Company’s financial reporting process. 

Auditor’s responsibilities for the audit of the consolidated financial statements

Our objectives are to obtain reasonable assurance about whether the consolidated financial statements as 

a whole are free from material misstatement, whether due to fraud or error, and to issue an auditor’s 

report that includes our opinion. Reasonable assurance is a high level of assurance, but is not a guarantee 

that an audit conducted in accordance with Canadian generally accepted auditing standards will always 

detect a material misstatement when it exists. Misstatements can arise from fraud or error and are 

considered material if, individually or in the aggregate, they could reasonably be expected to influence the 

economic decisions of users taken on the basis of these consolidated financial statements.

As part of an audit in accordance with Canadian generally accepted auditing standards, we exercise 

professional judgment and maintain professional skepticism throughout the audit. We also:

 

Identify and assess the risks of material misstatement of the consolidated financial statements, 

whether due to fraud or error, design and perform audit procedures responsive to those risks, and 

obtain audit evidence that is sufficient and appropriate to provide a basis for our opinion. The risk 

of not detecting a material misstatement resulting from fraud is higher than for one resulting from 

error, as fraud may involve collusion, forgery, intentional omissions, misrepresentations, or the 

override of internal control.

 
Independent auditor’s report

To the Shareholders of Gibson Energy Inc.

Our opinion

 

 

 

 

 

 

accounting policies.

Basis for opinion

opinion.

Independence

Other information

In our opinion, the accompanying consolidated financial statements present fairly, in all material respects, 

the financial position of Gibson Energy Inc. and its subsidiaries (together, the Company) as at December 31, 

2018 and 2017, and its financial performance and its cash flows for the years then ended in accordance with 

International Financial Reporting Standards (IFRS).

What we have audited

The Company's consolidated financial statements comprise:

the consolidated balance sheets as at December 31, 2018 and 2017;

the consolidated statements of operations for the years then ended;

the consolidated statements of comprehensive income (loss) for the years then ended;

the consolidated statements of changes in equity for the years then ended;

the consolidated statements of cash flows for the years then ended; and

the notes to the consolidated financial statements, which include a summary of significant 

We conducted our audit in accordance with Canadian generally accepted auditing standards. Our 

responsibilities under those standards are further described in the Auditor’s responsibilities for the audit 

of the consolidated financial statements section of our report.

We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our 

We are independent of the Company in accordance with the ethical requirements that are relevant to our 

audit of the consolidated financial statements in Canada. We have fulfilled our other ethical 

responsibilities in accordance with these requirements.

Management is responsible for the other information. The other information comprises the Management's 

Discussion and Analysis and the information, other than the consolidated financial statements and our 

auditor's report thereon, included in the annual report.

PricewaterhouseCoopers LLP

111 5th Avenue SW, Suite 3100, East Tower, Calgary, Alberta, Canada T2P 5L3

T: +1 403 509 7500, F: +1 403 781 1825, www.pwc.com/ca

“PwC” refers to PricewaterhouseCoopers LLP, an Ontario limited liability partnership. 

Our opinion on the consolidated financial statements does not cover the other information and we do not 
express any form of assurance conclusion thereon.

In connection with our audit of the consolidated financial statements, our responsibility is to read the 
other information identified above and, in doing so, consider whether the other information is materially 
inconsistent with the consolidated financial statements or our knowledge obtained in the audit, or 
otherwise appears to be materially misstated.

If, based on the work we have performed, we conclude that there is a material misstatement of this other 
information, we are required to report that fact. We have nothing to report in this regard.

Responsibilities of management and those charged with governance for the 
consolidated financial statements

Management is responsible for the preparation and fair presentation of the consolidated financial 
statements in accordance with IFRS, and for such internal control as management determines is necessary 
to enable the preparation of consolidated financial statements that are free from material misstatement, 
whether due to fraud or error.

In preparing the consolidated financial statements, management is responsible for assessing the 
Company's ability to continue as a going concern, disclosing, as applicable, matters related to going 
concern and using the going concern basis of accounting unless management either intends to liquidate 
the Company or to cease operations, or has no realistic alternative but to do so.

Those charged with governance are responsible for overseeing the Company’s financial reporting process. 

Auditor’s responsibilities for the audit of the consolidated financial statements

Our objectives are to obtain reasonable assurance about whether the consolidated financial statements as 
a whole are free from material misstatement, whether due to fraud or error, and to issue an auditor’s 
report that includes our opinion. Reasonable assurance is a high level of assurance, but is not a guarantee 
that an audit conducted in accordance with Canadian generally accepted auditing standards will always 
detect a material misstatement when it exists. Misstatements can arise from fraud or error and are 
considered material if, individually or in the aggregate, they could reasonably be expected to influence the 
economic decisions of users taken on the basis of these consolidated financial statements.

As part of an audit in accordance with Canadian generally accepted auditing standards, we exercise 
professional judgment and maintain professional skepticism throughout the audit. We also:

 

Identify and assess the risks of material misstatement of the consolidated financial statements, 
whether due to fraud or error, design and perform audit procedures responsive to those risks, and 
obtain audit evidence that is sufficient and appropriate to provide a basis for our opinion. The risk 
of not detecting a material misstatement resulting from fraud is higher than for one resulting from 
error, as fraud may involve collusion, forgery, intentional omissions, misrepresentations, or the 
override of internal control.

 
 

 

 

 

 

Obtain an understanding of internal control relevant to the audit in order to design audit 
procedures that are appropriate in the circumstances, but not for the purpose of expressing an 
opinion on the effectiveness of the Company’s internal control.

Evaluate the appropriateness of accounting policies used and the reasonableness of accounting 
estimates and related disclosures made by management.

Conclude on the appropriateness of management’s use of the going concern basis of accounting and, 
based on the audit evidence obtained, whether a material uncertainty exists related to events or 
conditions that may cast significant doubt on the Company’s ability to continue as a going concern. 
If we conclude that a material uncertainty exists, we are required to draw attention in our auditor’s 
report to the related disclosures in the consolidated financial statements or, if such disclosures are 
inadequate, to modify our opinion. Our conclusions are based on the audit evidence obtained up to 
the date of our auditor’s report. However, future events or conditions may cause the Company to 
cease to continue as a going concern. 

Evaluate the overall presentation, structure and content of the consolidated financial statements, 
including the disclosures, and whether the consolidated financial statements represent the 
underlying transactions and events in a manner that achieves fair presentation.

Obtain sufficient appropriate audit evidence regarding the financial information of the entities or 
business activities within the Company to express an opinion on the consolidated financial 
statements. We are responsible for the direction, supervision and performance of the group audit. 
We remain solely responsible for our audit opinion.

We communicate with those charged with governance regarding, among other matters, the planned scope 
and timing of the audit and significant audit findings, including any significant deficiencies in internal 
control that we identify during our audit. 

We also provide those charged with governance with a statement that we have complied with relevant 
ethical requirements regarding independence, and to communicate with them all relationships and other 
matters that may reasonably be thought to bear on our independence, and where applicable, related 
safeguards.

The engagement partner on the audit resulting in this independent auditor’s report is Khurram Asghar.

Chartered Professional Accountants

Calgary, Alberta
March 4, 2019

Gibson Energy Inc. 

Consolidated Balance Sheets 

(tabular amounts in thousands of Canadian dollars, except per share amounts) 

Assets 

Current assets 

Cash and cash equivalents  ..............................................................................................   

$        95,301    

$ 

Trade and other receivables (note 5) ...............................................................................  

95959595,30195

283,816   

As at December 31, 

2018   

2017 

Inventories (note 6) ..........................................................................................................  

Income taxes receivable ...................................................................................................  

Prepaid and other assets ..................................................................................................  

Net investment in finance leases (note 7) .......................................................................  

Assets held for sale (note 8) .............................................................................................  

Total current assets ..........................................................................................................  

Non-current assets 

Property, plant and equipment (note 10) ........................................................................  

Right-of-use assets (note 11) ...........................................................................................  

Long-term prepaid and other assets (note 12) ................................................................  

Net investment in finance leases (note 7) .......................................................................  

Deferred income tax assets (note 22) ..............................................................................  

Intangible assets (note 13) ...............................................................................................  

Goodwill (note 14) ...........................................................................................................  

Total non-current assets ..................................................................................................  

2,122,618   

Total assets .............................................................................................................................   

$   2,809,576   

2,236,107 

$  2,964,434 

Liabilities 

Current liabilities  

Trade payables and accrued charges (note 18) ...............................................................  

$      365,410   

$      500,662 

Income taxes payables .....................................................................................................  

Dividends payable (note 21) ............................................................................................  

Deferred revenue .............................................................................................................  

Contract liabilities (note 4) ...............................................................................................  

Lease liabilities – current portion (note 16) .....................................................................  

Liabilities related to assets held for sale (note 8) ............................................................  

Total current liabilities .....................................................................................................  

Non-current liabilities 

Lease liabilities – non-current portion (note 16)..............................................................  

Convertible debentures (note 17) ....................................................................................  

Provisions (note 19) .........................................................................................................  

Other long-term liabilities (note 20) ................................................................................  

Deferred income tax liabilities (note 22)..........................................................................  

Long-term debt (note 15) .................................................................................................  

1,039,578   

1,118,119 

Total non-current liabilities ..............................................................................................  

1,461,685   

1,498,900 

Total liabilities ..................................................................................................................  

$   2,051,346   

$     2,053,832 

Equity 

Share capital (note 21) .....................................................................................................  

1,955,146   

Contributed surplus .........................................................................................................  

Accumulated other comprehensive income ....................................................................  

Convertible debentures (note 17) ....................................................................................  

Deficit ...............................................................................................................................  

Total equity ......................................................................................................................  

44,461   

41,650   

7,023   

(1,290,050)  

758,230   

1,932,103 

48,706 

174,186 

7,023 

(1,251,416)

910,602 

Total liabilities and equity ......................................................................................................   

$   2,809,576   

$  2,964,434 

Commitments and contingencies (note 31) 

See accompanying notes to the consolidated financial statements 

Approved by the Board of Directors: 

(signed) “James M. Estey”  

James M. Estey (Director)    

                   (signed) “Marshall L. McRae” 

Marshall L. McRae (Director) 

1 

1,424,211   

1,619,688 

85,629   

-   

11,618   

1,156   

209,438   

686,958   

99,180   

4,803   

154,206   

35,874   

41,996   

362,348   

66,083   

47,704   

-   

15,451   

36,200   

58,813   

589,661   

72,871   

92,466   

162,811   

16,319   

77,640   

32,138 

494,901 

169,957 

11,102 

18,401 

1,828 

728,327 

7,364 

118,020 

75,221 

33,849 

381,965 

47,257 

7,013 

554,932 

89,919 

183,527 

6,512 

100,823 

- 

- 

- 

- 

- 

- 

- 

 
 
 
 
   
 
   
 
 
 
   
 
 
   
 
   
 
   
 
   
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 

 

 

 

 

Obtain an understanding of internal control relevant to the audit in order to design audit 

procedures that are appropriate in the circumstances, but not for the purpose of expressing an 

opinion on the effectiveness of the Company’s internal control.

Evaluate the appropriateness of accounting policies used and the reasonableness of accounting 

estimates and related disclosures made by management.

Conclude on the appropriateness of management’s use of the going concern basis of accounting and, 

based on the audit evidence obtained, whether a material uncertainty exists related to events or 

conditions that may cast significant doubt on the Company’s ability to continue as a going concern. 

If we conclude that a material uncertainty exists, we are required to draw attention in our auditor’s 

report to the related disclosures in the consolidated financial statements or, if such disclosures are 

inadequate, to modify our opinion. Our conclusions are based on the audit evidence obtained up to 

the date of our auditor’s report. However, future events or conditions may cause the Company to 

cease to continue as a going concern. 

Evaluate the overall presentation, structure and content of the consolidated financial statements, 

including the disclosures, and whether the consolidated financial statements represent the 

underlying transactions and events in a manner that achieves fair presentation.

Obtain sufficient appropriate audit evidence regarding the financial information of the entities or 

business activities within the Company to express an opinion on the consolidated financial 

statements. We are responsible for the direction, supervision and performance of the group audit. 

We remain solely responsible for our audit opinion.

We communicate with those charged with governance regarding, among other matters, the planned scope 

and timing of the audit and significant audit findings, including any significant deficiencies in internal 

control that we identify during our audit. 

We also provide those charged with governance with a statement that we have complied with relevant 

ethical requirements regarding independence, and to communicate with them all relationships and other 

matters that may reasonably be thought to bear on our independence, and where applicable, related 

safeguards.

The engagement partner on the audit resulting in this independent auditor’s report is Khurram Asghar.

Chartered Professional Accountants

Calgary, Alberta

March 4, 2019

Gibson Energy Inc. 
Consolidated Balance Sheets 

(tabular amounts in thousands of Canadian dollars, except per share amounts) 

As at December 31, 

2018   

2017 

Assets 
Current assets 

Cash and cash equivalents  ..............................................................................................   
Trade and other receivables (note 5) ...............................................................................  
Inventories (note 6) ..........................................................................................................  
Income taxes receivable ...................................................................................................  
Prepaid and other assets ..................................................................................................  
Net investment in finance leases (note 7) .......................................................................  
Assets held for sale (note 8) .............................................................................................  
Total current assets ..........................................................................................................  

$        95,301    
283,816   
95959595,30195
85,629   
-   
11,618   
1,156   
209,438   
686,958   

Non-current assets 

Property, plant and equipment (note 10) ........................................................................  
Right-of-use assets (note 11) ...........................................................................................  
Long-term prepaid and other assets (note 12) ................................................................  
Net investment in finance leases (note 7) .......................................................................  
Deferred income tax assets (note 22) ..............................................................................  
Intangible assets (note 13) ...............................................................................................  
Goodwill (note 14) ...........................................................................................................  
Total non-current assets ..................................................................................................  
Total assets .............................................................................................................................   
Liabilities 
Current liabilities  

Trade payables and accrued charges (note 18) ...............................................................  
Income taxes payables .....................................................................................................  
Dividends payable (note 21) ............................................................................................  
Deferred revenue .............................................................................................................  
Contract liabilities (note 4) ...............................................................................................  
Lease liabilities – current portion (note 16) .....................................................................  
Liabilities related to assets held for sale (note 8) ............................................................  
Total current liabilities .....................................................................................................  

Non-current liabilities 

Long-term debt (note 15) .................................................................................................  
Lease liabilities – non-current portion (note 16)..............................................................  
Convertible debentures (note 17) ....................................................................................  
Provisions (note 19) .........................................................................................................  
Other long-term liabilities (note 20) ................................................................................  
Deferred income tax liabilities (note 22)..........................................................................  
Total non-current liabilities ..............................................................................................  
Total liabilities ..................................................................................................................  

Equity 

Share capital (note 21) .....................................................................................................  
Contributed surplus .........................................................................................................  
Accumulated other comprehensive income ....................................................................  
Convertible debentures (note 17) ....................................................................................  
Deficit ...............................................................................................................................  
Total equity ......................................................................................................................  
Total liabilities and equity ......................................................................................................   
Commitments and contingencies (note 31) 
See accompanying notes to the consolidated financial statements 

1,424,211   
99,180   
4,803   
154,206   
35,874   
41,996   
362,348   
2,122,618   
$   2,809,576   

$      365,410   
66,083   
47,704   
-   
15,451   
36,200   
58,813   
589,661   

1,039,578   
72,871   
92,466   
162,811   
16,319   
77,640   
1,461,685   
$   2,051,346   

1,955,146   
44,461   
41,650   
7,023   
(1,290,050)  
758,230   
$   2,809,576   

$ 

32,138 
494,901 
169,957 
11,102 
18,401 
1,828 
- 
728,327 

1,619,688 
- 
7,364 
118,020 
75,221 
33,849 
381,965 
2,236,107 
$  2,964,434 

$      500,662 
- 
47,257 
7,013 
- 
- 
- 
554,932 

1,118,119 
- 
89,919 
183,527 
6,512 
100,823 
1,498,900 
$     2,053,832 

1,932,103 
48,706 
174,186 
7,023 
(1,251,416)
910,602 
$  2,964,434 

Approved by the Board of Directors: 

(signed) “James M. Estey”  
James M. Estey (Director)    

                   (signed) “Marshall L. McRae” 
Marshall L. McRae (Director) 

Gibson Energy 

1 
49 

Consolidated Financial Statements

 
 
 
 
   
 
   
 
 
 
   
 
 
   
 
   
 
   
 
   
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Consolidated Statements of Operations 

Gibson Energy Inc. 

Consolidated Statements of Comprehensive Income (Loss) 

(tabular amounts in thousands of Canadian dollars, except per share amounts) 

(tabular amounts in thousands of Canadian dollars, except per share amounts) 

Continuing operations 

Year ended 
December 31, 
2018 

2017 
(note 8)  

Revenue (note 23) ......................................................................................................................    
Cost of sales (notes 24 and 25) ..................................................................................................  
Gross profit ..........................................................................................................................  

$  6,846,589   
6,543,958   
302,631   

$  5,659,646 
5,512,256 
147,390 

General and administrative expenses (notes 24 and 25) ...........................................................  
Impairment of goodwill (note 14) ..............................................................................................  
Other operating income (note 26) .............................................................................................  
Operating income (loss) .......................................................................................................  

69,013   
20,479   
(2,091)  
215,230   

85,144 
69,414 
(1,423)
(5,745)

Finance costs, net (note 15) .......................................................................................................  
Income (loss) before income taxes .......................................................................................  
Income tax expense (recovery) (note 22) ..................................................................................  
Net income (loss) from continuing operations .....................................................................    
Net income from discontinued operations, after tax (note 8) ...................................................  
Net income ..........................................................................................................................  

78,492   
136,738   
55,613   
81,125   
69,923   
$     151,048    

$ 

118,785 
(124,530)
(58,204)
 (66,326)
110,461 
$       44,135 

$ 

Earnings/(loss) per share (note 27) 

Year ended 

December 31, 

2018 

2017 

(note 8) 

Net income.................................................................................................................................    

$  151,048      

$ 

44,135 

Other comprehensive loss .........................................................................................................  

Items that may be reclassified subsequently to statement of operations  

Exchange differences on translating foreign operations – continuing operations .............  

Other comprehensive income from discontinued operations ............................................  

Reclassification of foreign currency translation gain on disposal of foreign operations 

12,518 

5,373 

(19,684) 

- 

(note 8) ................................................................................................................................  

(143,601) 

(7,219) 

Items that will not be reclassified to statement of operations 

Remeasurements of post-employment benefit obligation, net of tax ($2.9 million) .........  

(6,826) 

Other comprehensive loss, net of tax .......................................................................................  

(132,536) 

(6) 

(26,909) 

Comprehensive income .............................................................................................................    

$       18,512      

$ 

17,226 

See accompanying notes to the consolidated financial statements

Basic earnings (loss) per share from continuing operations ...............................................    
Basic earnings per share from discontinued operations .....................................................                       0.48                  
Basic earnings per share......................................................................................................         $            1.05              
Diluted earnings (loss) per share from continuing operations............................................         $            0.56    
Diluted earnings per share from discontinued operations .................................................                       0.46   
Diluted earnings per share ..................................................................................................         $            1.02     

      $        (0.47) 
            0.78  
$          0.31 
$        (0.47) 
                  0.76 
$          0.29  

$            0.57   

See accompanying notes to the consolidated financial statements 

Consolidated Financial Statements 

2 

50 

Gibson Energy

3 

 
 
 
 
 
 
   
 
 
 
   
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
  
 
 
 
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Consolidated Statements of Operations 

Gibson Energy Inc. 
Consolidated Statements of Comprehensive Income (Loss) 

(tabular amounts in thousands of Canadian dollars, except per share amounts) 

(tabular amounts in thousands of Canadian dollars, except per share amounts) 

Year ended 

December 31, 

2018 

2017 

(note 8)  

Continuing operations 

Revenue (note 23) ......................................................................................................................    

$  6,846,589   

$  5,659,646 

Cost of sales (notes 24 and 25) ..................................................................................................  

Gross profit ..........................................................................................................................  

6,543,958   

302,631   

5,512,256 

147,390 

General and administrative expenses (notes 24 and 25) ...........................................................  

Impairment of goodwill (note 14) ..............................................................................................  

Other operating income (note 26) .............................................................................................  

Operating income (loss) .......................................................................................................  

Finance costs, net (note 15) .......................................................................................................  

Income (loss) before income taxes .......................................................................................  

Income tax expense (recovery) (note 22) ..................................................................................  

Net income (loss) from continuing operations .....................................................................    

$ 

Net income from discontinued operations, after tax (note 8) ...................................................  

69,013   

20,479   

(2,091)  

215,230   

78,492   

136,738   

55,613   

81,125   

69,923   

85,144 

69,414 

(1,423)

(5,745)

118,785 

(124,530)

(58,204)

$ 

 (66,326)

110,461 

Net income ..........................................................................................................................  

$     151,048    

$       44,135 

Earnings/(loss) per share (note 27) 

Basic earnings (loss) per share from continuing operations ...............................................    

$            0.57   

      $        (0.47) 

Basic earnings per share from discontinued operations .....................................................                       0.48                  

            0.78  

Basic earnings per share......................................................................................................         $            1.05              

$          0.31 

Diluted earnings (loss) per share from continuing operations............................................         $            0.56    

$        (0.47) 

Diluted earnings per share from discontinued operations .................................................                       0.46   

                  0.76 

Diluted earnings per share ..................................................................................................         $            1.02     

$          0.29  

See accompanying notes to the consolidated financial statements 

Year ended 
December 31, 
2018 

2017 
(note 8) 

Net income.................................................................................................................................    

$  151,048      

$ 

44,135 

Other comprehensive loss .........................................................................................................  
Items that may be reclassified subsequently to statement of operations  

Exchange differences on translating foreign operations – continuing operations .............  
Other comprehensive income from discontinued operations ............................................  
Reclassification of foreign currency translation gain on disposal of foreign operations 
(note 8) ................................................................................................................................  

Items that will not be reclassified to statement of operations 

12,518 
5,373 

(19,684) 
- 

(143,601) 

(7,219) 

Remeasurements of post-employment benefit obligation, net of tax ($2.9 million) .........  
Other comprehensive loss, net of tax .......................................................................................  
Comprehensive income .............................................................................................................    

(6,826) 
(132,536) 
$       18,512      

(6) 
(26,909) 
17,226 

$ 

See accompanying notes to the consolidated financial statements

2 

Gibson Energy 

3 
51 

Consolidated Financial Statements

 
 
 
 
 
 
   
 
 
 
   
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
  
 
 
 
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Consolidated Statements of Changes in Equity 

(tabular amounts in thousands of Canadian dollars, except per share amounts) 

Gibson Energy Inc. 

Consolidated Statements of Cash Flows 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Share 
capital 
(note 21) 

Contributed 
surplus 

Accumulated 
other 
comprehensive 
income (loss) 

Convertible 
debentures 

Deficit 

  Total Equity 

Balance – January 1, 2017 ....................$1,909,032 

$ 

46,899 

$    201,089  

 $  7,151

 $  (1,107,075) 

$1,057,096 

Net income ...........................................
Other comprehensive loss, net of tax ...
Comprehensive (loss) income ...............
Share based compensation ................
Convertibles debentures – tax ...........
Proceeds from exercise of stock 
options ...............................................
Reclassification of contributed 
surplus on issuance of awards 
under equity incentive plan ..........

Dividends on common shares ($0.33 

- 
- 
- 
- 
- 

2,822 

- 
- 
- 
22,056 
- 

- 

20,249 

(20,249) 

-  
(26,903)  
(26,903)  
-  
-  

-  

-  

per common share) ............................

- 
Balance – December 31, 2017 ..............$  1,932,103 

- 
  $  48,706 

-  
  $    174,186  

-  
-  
-  
- 
(128) 

- 

- 

-

 $      7,023  

44,135 
(6) 
44,129 
- 
- 

- 

- 

44,135 
(26,909) 
17,226 
22,056 
(128)

2,822 

- 

(188,470) 
$  (1,251,416) 

(188,470) 
  $      910,602 

Balance – January 1, 2018 ................... $ 1,932,103 

$    48,706 

         $    174,186  

$      7,023

$  (1,251,416) 

  $      910,602 

Impact of change in accounting policy 
(note 4) .................................................

                   - 

- 

  -  

            -

                 629 

            629 

Restated balance – January 1, 2018 ....    1,932,103 

48,706 

              174,186 

     7,023

  (1,250,787) 

      911,231 

-  

-  

151,048 

151,048 

Proceeds from (repayment of) credit facilities, net ............................................................  

(84,657)  

Net income ...........................................
Reclassification of foreign currency 
translation gain on disposal of foreign 
operations (note 8) ...............................
Other comprehensive income, net of 
tax .........................................................
Comprehensive (loss) income ...............
Share based compensation ................
Proceeds from exercise of stock 
options ...............................................
Reclassification of contributed 
surplus on issuance of awards 
under equity incentive plan ..........

Dividends on common shares ($0.33 

- 

- 

- 
- 
- 

1,056 

- 

- 

- 
- 
17,742 

- 

21,987 

(21,987) 

per common share) ............................

- 
Balance – December 31, 2018 ..............$ 1,955,146  

- 
  $  44,461 

-  
  $  41,650  

See accompanying notes to the consolidated financial statements 

(143,601)  

11,065  
(132,536)  
-  

-  

-  

-

-
-  
- 

- 

- 

-

 $ 

 7,023  

- 

(143,601) 

- 
151,048 
- 

- 

- 

11,065 
18,512 
17,742 

1,056 

- 

(190,311) 
$  (1,290,050)    

(190,311) 
$  758,230  

financing activities 

Year ended 

December 31, 

2018 

Cash flows from operating activities 

Net income (loss) from continuing operations  .......................................................................  

$       81,125     

$ 

(66,326) 

Adjustments for non-cash items (note 33)  ........................................................................  

             381,663     

Changes in items of working capital (note 33) ...................................................................  

               50,222     

Income taxes received, net (note 33) .................................................................................  

               14,076     

Cash provided by operating activities from continuing operations  ........................................  

Cash provided by operating activities from discontinued operations (note 8) .......................  

Net cash provided by operating activities  .............................................................................  

Cash flows from investing activities 

Purchase of property, plant and equipment  ......................................................................  

Acquisitions, net of cash acquired (note 9) ........................................................................  

Purchase of intangible assets  .............................................................................................  

Proceeds from net assets held for sale, net (note 8) ..........................................................  

Proceeds on sale of assets ..................................................................................................  

Cash used in investing activities from continuing operations ..................................................  

Cash provided by investing activities from discontinued operations (note 8)  ........................  

Net cash (used in) provided by investing activities  ...............................................................  

Cash flows from financing activities 

Payment of shareholder dividends .....................................................................................  

Interest paid, net ................................................................................................................  

Proceeds from exercise of stock options ............................................................................  

Finance lease payments (note 16) ......................................................................................  

Proceeds from issuance of long-term debt, net of cost .....................................................  

Repayment of long-term debt, net of cost  ........................................................................  

Settlement of financial instruments not affecting operating activities (note 15) ..............  

Cash used in financing activities from continuing operations  ................................................  

Cash used in financing activities from discontinued operations (note 8)  ...............................  

Net cash used in financing activities  ......................................................................................  

Net increase (decrease) in cash and cash equivalents  ..........................................................  

Effect of exchange rate on cash and cash equivalents ............................................................  

Cash and cash equivalents – beginning of year  ......................................................................  

527,086   

36,652   

563,738   

(224,440)  

(41,656)  

(4,051)  

   41,811   

13,834   

(214,502)  

107,777   

(106,725)  

(189,880)  

(68,924)  

1,056   

(49,792)  

-   

-   

-   

(392,197)  

(3,056)  

(395,253)  

61,760   

1,403   

32,138   

Cash and cash equivalents – end of year  ...............................................................................  

$ 

 95,301     

$ 

See accompanying notes to the consolidated financial statements 

See note 33 for supplemental disclosures and reconciliation of movements of financial liabilities to cash flows arising from 

2017 

(note 8) 

268,923 

(27,325) 

- 

175,272 

22,107 

197,379 

(157,555) 

(5,735) 

3,094 

(160,196) 

416,016 

255,820 

(187,985) 

(87,177) 

2,822 

- 

- 

- 

- 

590,452 

(1,024,007) 

230,180 

(2,218) 

(477,933) 

(477,933) 

(24,734) 

(3,287) 

60,159 

32,138 

Consolidated Financial Statements 

4 

52 

Gibson Energy

5 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
                                 
 
 
 
             
 
 
                          
 
 
                       
 
 
            
 
 
          
 
                
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
   
 
   
 
 
   
 
 
 
 
   
 
   
 
 
 
 
 
Gibson Energy Inc. 

Consolidated Statements of Changes in Equity 

(tabular amounts in thousands of Canadian dollars, except per share amounts) 

Gibson Energy Inc. 
Consolidated Statements of Cash Flows 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Year ended 
December 31, 
2018 

2017 
(note 8) 

Cash flows from operating activities 
Net income (loss) from continuing operations  .......................................................................  
Adjustments for non-cash items (note 33)  ........................................................................  
Changes in items of working capital (note 33) ...................................................................  
Income taxes received, net (note 33) .................................................................................  
Cash provided by operating activities from continuing operations  ........................................  
Cash provided by operating activities from discontinued operations (note 8) .......................  
Net cash provided by operating activities  .............................................................................  
Cash flows from investing activities 

Purchase of property, plant and equipment  ......................................................................  
Acquisitions, net of cash acquired (note 9) ........................................................................  
Purchase of intangible assets  .............................................................................................  
Proceeds from net assets held for sale, net (note 8) ..........................................................  
Proceeds on sale of assets ..................................................................................................  
Cash used in investing activities from continuing operations ..................................................  
Cash provided by investing activities from discontinued operations (note 8)  ........................  
Net cash (used in) provided by investing activities  ...............................................................  
Cash flows from financing activities 

Payment of shareholder dividends .....................................................................................  
Interest paid, net ................................................................................................................  
Proceeds from exercise of stock options ............................................................................  
Finance lease payments (note 16) ......................................................................................  
Proceeds from issuance of long-term debt, net of cost .....................................................  
Repayment of long-term debt, net of cost  ........................................................................  
Proceeds from (repayment of) credit facilities, net ............................................................  
Settlement of financial instruments not affecting operating activities (note 15) ..............  
Cash used in financing activities from continuing operations  ................................................  
Cash used in financing activities from discontinued operations (note 8)  ...............................  
Net cash used in financing activities  ......................................................................................  
Net increase (decrease) in cash and cash equivalents  ..........................................................  
Effect of exchange rate on cash and cash equivalents ............................................................  
Cash and cash equivalents – beginning of year  ......................................................................  
Cash and cash equivalents – end of year  ...............................................................................  

See accompanying notes to the consolidated financial statements 

$ 

$       81,125     
             381,663     
               50,222     
               14,076     

(66,326) 
268,923 
(27,325) 
- 
175,272 
22,107 
197,379 

(157,555) 
- 
(5,735) 
- 
3,094 
(160,196) 
416,016 
255,820 

(187,985) 
(87,177) 
2,822 
- 
590,452 
(1,024,007) 
230,180 
(2,218) 
(477,933) 
- 
(477,933) 
(24,734) 
(3,287) 
60,159 
32,138 

$ 

527,086   
36,652   
563,738   

(224,440)  
(41,656)  
(4,051)  
   41,811   
13,834   
(214,502)  
107,777   
(106,725)  

(189,880)  
(68,924)  
1,056   
(49,792)  
-   
-   
(84,657)  
-   
(392,197)  
(3,056)  
(395,253)  
61,760   
1,403   
32,138   
 95,301     

$ 

Balance – December 31, 2018 ..............$ 1,955,146  

  $  44,461 

  $  41,650  

 $ 

 7,023  

$  (1,290,050)    

$  758,230  

(190,311) 

(190,311) 

See note 33 for supplemental disclosures and reconciliation of movements of financial liabilities to cash flows arising from 
financing activities 

Gibson Energy 

5 
53 

Consolidated Financial Statements

Share 

capital 

(note 21) 

Contributed 

comprehensive 

surplus 

income (loss) 

Convertible 

debentures 

Deficit 

  Total Equity 

Accumulated 

other 

Balance – January 1, 2017 ....................$1,909,032 

$ 

46,899 

$    201,089  

 $  7,151

 $  (1,107,075) 

$1,057,096 

(26,903)  

(26,903)  

22,056 

44,135 

(6) 

44,129 

Net income ...........................................

Other comprehensive loss, net of tax ...

Comprehensive (loss) income ...............

Share based compensation ................

Convertibles debentures – tax ...........

Proceeds from exercise of stock 

options ...............................................

2,822 

Reclassification of contributed 

surplus on issuance of awards 

under equity incentive plan ..........

20,249 

(20,249) 

Dividends on common shares ($0.33 

per common share) ............................

Balance – December 31, 2017 ..............$  1,932,103 

  $  48,706 

  $    174,186  

 $      7,023  

$  (1,251,416) 

  $      910,602 

(188,470) 

(188,470) 

Balance – January 1, 2018 ................... $ 1,932,103 

$    48,706 

         $    174,186  

$      7,023

$  (1,251,416) 

  $      910,602 

Impact of change in accounting policy 

(note 4) .................................................

                   - 

  -  

            -

                 629 

            629 

Restated balance – January 1, 2018 ....    1,932,103 

48,706 

              174,186 

     7,023

  (1,250,787) 

      911,231 

-  

-  

151,048 

151,048 

-  

-  

-  

-  

-  

-  

-  

-  

-  

-  

(128) 

-  

-  

-  

- 

- 

- 

-

-

-

- 

- 

- 

-

44,135 

(26,909) 

17,226 

22,056 

(128)

2,822 

- 

(143,601) 

11,065 

18,512 

17,742 

1,056 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

Net income ...........................................

Reclassification of foreign currency 

translation gain on disposal of foreign 

operations (note 8) ...............................

Other comprehensive income, net of 

tax .........................................................

Comprehensive (loss) income ...............

Share based compensation ................

Proceeds from exercise of stock 

options ...............................................

1,056 

Reclassification of contributed 

surplus on issuance of awards 

under equity incentive plan ..........

21,987 

(21,987) 

Dividends on common shares ($0.33 

per common share) ............................

See accompanying notes to the consolidated financial statements 

(143,601)  

11,065  

(132,536)  

17,742 

-  

151,048 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

4 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
                                 
 
 
 
             
 
 
                          
 
 
                       
 
 
            
 
 
          
 
                
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
   
 
   
 
 
   
 
 
 
 
   
 
   
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

1  Description of the business and segmented disclosure 

Gibson Energy Inc. (“Gibson Energy” or the “Company”) was incorporated pursuant to the Business Corporations Act (Alberta) on 
April 11, 2011. The Company is incorporated in Alberta and domiciled in Canada. The address of the Company’s principal place of 
business is 1700, 440 Second Avenue S.W., Calgary, Alberta, Canada. The Company’s common shares are traded on the Toronto Stock 
Exchange under the symbol “GEI”. 

The Company had the following principal subsidiaries as at December 31, 2018: 

Name 
Gibson Energy Inc.  
Gibson Energy ULC  
Gibson (U.S.) Acquisitionco Corp. 

Nature of entity 
Ultimate Parent Company   Moose Jaw Refinery ULC 
Holding Company 
Holding Company 

Gibson Energy Trucking Ltd. 
Gibson Energy Partnership 

Name 

Nature of business 
Crude oil processing 
Transportation 
Wholesale, transportation and 
storage 

The Company’s reportable segments are: 

(1)  Infrastructure, which includes a network of oil infrastructure assets that include oil terminals, rail loading and unloading facilities, 
injection stations, gathering pipelines, a crude oil processing facility, and procession, recovery, and disposal (“PRD”) terminals. 
The primary facilities within this segment include the terminals located at Hardisty and Edmonton, which are the principal hubs 
for aggregating and exporting oil and refined products out of the Western Canadian Sedimantary Basin; gathering pipelines, 
which are connected to the Hardisty Terminal; an infrastructure position located in the United States (“U.S.); and a crude oil 
processing facility in Moose Jaw, Saskatchewan (the “Moose Jaw Facility”). The Moose Jaw Facility is impacted by maintenance 
turnarounds typically occurring within the spring period. The PRD business is dependent upon the drilling activity in various areas 
of operations and as a result, the PRD business is impacted by seasonality due to road bans as part of spring break-up.  

(2)  Logistics, which represents the U.S. Truck Transportation business due to Canadian Truck Transportation being classified as a 
discontinued operation during the third quarter of 2018.  This segment provides truck transportation services that allow the 
Company to service its customers’ needs between the wellhead and the end market and includes providing hauling services for 
crude for many of North America’s leading oil and gas producers. 

(3)  Wholesale, which involves the purchasing, selling, storing and optimization of hydrocarbon products, including crude oil, natural 
gas liquids, road asphalt, roofing flux, frac oils, light and heavy straight run distillates, combined vacuum gas oil, and an oil-based 
mud product as part of supplying the Moose Jaw Facility, marketing it refined products and helping to drive volumes through 
the Company’s key infrastructure assets. This segment earns margins by providing aggregation services to producers and/or by 
capturing  locational,  quality  or  time-based  opportunities.  The  Wholesale  segment  sources  the  majority  of  its  hydrocarbon 
products from Western Canada and markets those products throughout U.S. and Canada. Canadian road asphalt activity, related 
to refined products, is affected by the impact of weather conditions on road construction. Road asphalt demand peaks during 
the summer months when most of the road construction activity in Canada takes place. In the off-peak demand months for road 
asphalt, the demand for roofing flux continues. Demand for wellsite fluids is dependent on overall well drilling and completion 
activities, with activity normally the busiest in the  winter  months. Demand for propane and other natural gas liquids is also 
highest in the colder months of the year. 

This reporting structure provides a direct connection between the Company’s operations, the services it provides to customers and 
the ongoing strategic direction of the Company. 

These reportable segments of the Company have been derived because they are the segments: (a) that engage in business activities 
from which revenues are earned and expenses are incurred; (b) whose operating results are regularly reviewed by the Company’s 
chief operating decision maker to make decisions about resources to be allocated to each segment and assess its performance; and 
(c) for which discrete financial information is available. The Company has aggregated certain operating segments into the above 
noted reportable segments through examination of the Company's performance which is based on the similarity of the goods and 
services provided and economic characteristics exhibited by these operating segments. Accounting policies used for segment 
reporting are consistent with the accounting policies used for the preparation of the Company’s consolidated financial statements. 
Inter-segmental transactions are eliminated upon consolidation and the Company does not recognize margins on inter-segmental 
transactions. 

Consolidated Financial Statements 

6 

54 

Gibson Energy

7 

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Year ended December 31, 2018 1 

Statement of operations 

Revenue 

  External .........................................  

Inter-segmental  ............................  

  External and inter-segmental  .......  

Infrastructure 

Logistics 

Wholesale 

Total 

  $    259,865 

  $ 

  $        6,555,792 

  $    6,846,589

131,762

391,627

30,932

17,588

48,520

586,921  

7,142,713  

736,271

7,582,860

Segment profit (loss) .........................  

  $    283,489 

  $ 

(7,513) 

  $           211,111 

  $       487,087

Corporate & other reconciling items 

Depreciation and impairment of property, plant and equipment  .....................................................................................  

143,160 

Depreciation of right-of-use assets  ....................................................................................................................................  

Amortization and impairment of intangible assets  ............................................................................................................  

Impairment of goodwill (note 14)  ......................................................................................................................................  

General and administrative  ................................................................................................................................................  

Share based compensation  ................................................................................................................................................  

Corporate foreign exchange gain  .......................................................................................................................................  

Interest expense, net  .........................................................................................................................................................  

Foreign exchange loss on long-term debt  ..........................................................................................................................  

Loss on sale of net assets held for sale (note 8) ..................................................................................................................  

Net income from continuing operations before income tax  ..............................................................................................  

Income tax expense (note 22) .............................................................................................................................................  

Net income from continuing operations  ............................................................................................................................  

Net income from discontinued operations, after tax (note 8) ............................................................................................  

Net income from operations  ..............................................................................................................................................  

43,184 

10,870 

20,479 

32,155 

19,124 

(2,089) 

74,089 

4,403 

4,974 

136,738 

55,613 

           81,125 

           69,923 

    $     151,048  

Year ended December 31, 2017 1,2  

Statement of operations 

Revenue 

  External .........................................  

Inter-segmental .............................  

  External and inter-segmental ........  

Infrastructure 

Logistics 

Wholesale 

Total 

  $  205,561

  $ 

66,137

  $        5,387,948

  $  5,659,646 

131,340

336,901

8,568

74,705

429,304

5,817,252

569,212 

6,228,858 

Segment profit (loss) .........................  

  $  235,276

  $ 

(4,103)

  $             30,585

  $ 

261,758 

Corporate & other reconciling items 

Depreciation and impairment of property, plant and equipment  .....................................................................................  

Amortization and impairment of intangible assets  ............................................................................................................  

Impairment of goodwill (note 14)  ......................................................................................................................................  

General and administrative  ................................................................................................................................................  

Share based compensation  ................................................................................................................................................  

Corporate foreign exchange loss  ........................................................................................................................................  

Interest expense, net  .........................................................................................................................................................  

Debt extinguishment costs, net  .........................................................................................................................................  

Foreign exchange gain on long-term debt  .........................................................................................................................  

Net loss from continuing operations before income tax  ....................................................................................................  

Income tax recovery (note 22)  ...........................................................................................................................................  

Net loss from continuing operations  ..................................................................................................................................  

Net income from discontinued operations, after tax (note 8)  ...........................................................................................  

Net income from operations  ..............................................................................................................................................  

100,837 

23,340 

69,414 

50,016 

23,244 

652 

77,081 

60,492 

(18,788) 

(124,530) 

(58,204) 

(66,326) 

            110,461 

  $ 

44,135 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
  
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
  
 
 
 
 
   
 
 
 
 
 
 
 
 
   
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

1  Description of the business and segmented disclosure 

Gibson Energy Inc. (“Gibson Energy” or the “Company”) was incorporated pursuant to the Business Corporations Act (Alberta) on 

April 11, 2011. The Company is incorporated in Alberta and domiciled in Canada. The address of the Company’s principal place of 

business is 1700, 440 Second Avenue S.W., Calgary, Alberta, Canada. The Company’s common shares are traded on the Toronto Stock 

Exchange under the symbol “GEI”. 

The Company had the following principal subsidiaries as at December 31, 2018: 

Name 

Gibson Energy Inc.  

Gibson Energy ULC  

Nature of entity 

Name 

Ultimate Parent Company   Moose Jaw Refinery ULC 

Nature of business 

Crude oil processing 

Holding Company 

Gibson Energy Trucking Ltd. 

Transportation 

storage 

The Company’s reportable segments are: 

(1)  Infrastructure, which includes a network of oil infrastructure assets that include oil terminals, rail loading and unloading facilities, 

injection stations, gathering pipelines, a crude oil processing facility, and procession, recovery, and disposal (“PRD”) terminals. 

The primary facilities within this segment include the terminals located at Hardisty and Edmonton, which are the principal hubs 

for aggregating and exporting oil and refined products out of the Western Canadian Sedimantary Basin; gathering pipelines, 

which are connected to the Hardisty Terminal; an infrastructure position located in the United States (“U.S.); and a crude oil 

processing facility in Moose Jaw, Saskatchewan (the “Moose Jaw Facility”). The Moose Jaw Facility is impacted by maintenance 

turnarounds typically occurring within the spring period. The PRD business is dependent upon the drilling activity in various areas 

of operations and as a result, the PRD business is impacted by seasonality due to road bans as part of spring break-up.  

(2)  Logistics, which represents the U.S. Truck Transportation business due to Canadian Truck Transportation being classified as a 

discontinued operation during the third quarter of 2018.  This segment provides truck transportation services that allow the 

Company to service its customers’ needs between the wellhead and the end market and includes providing hauling services for 

crude for many of North America’s leading oil and gas producers. 

(3)  Wholesale, which involves the purchasing, selling, storing and optimization of hydrocarbon products, including crude oil, natural 

gas liquids, road asphalt, roofing flux, frac oils, light and heavy straight run distillates, combined vacuum gas oil, and an oil-based 

mud product as part of supplying the Moose Jaw Facility, marketing it refined products and helping to drive volumes through 

the Company’s key infrastructure assets. This segment earns margins by providing aggregation services to producers and/or by 

capturing  locational,  quality  or  time-based  opportunities.  The  Wholesale  segment  sources  the  majority  of  its  hydrocarbon 

products from Western Canada and markets those products throughout U.S. and Canada. Canadian road asphalt activity, related 

to refined products, is affected by the impact of weather conditions on road construction. Road asphalt demand peaks during 

the summer months when most of the road construction activity in Canada takes place. In the off-peak demand months for road 

asphalt, the demand for roofing flux continues. Demand for wellsite fluids is dependent on overall well drilling and completion 

activities, with activity normally the busiest in the  winter  months. Demand for propane and other natural gas liquids is also 

highest in the colder months of the year. 

the ongoing strategic direction of the Company. 

This reporting structure provides a direct connection between the Company’s operations, the services it provides to customers and 

These reportable segments of the Company have been derived because they are the segments: (a) that engage in business activities 

from which revenues are earned and expenses are incurred; (b) whose operating results are regularly reviewed by the Company’s 

chief operating decision maker to make decisions about resources to be allocated to each segment and assess its performance; and 

(c) for which discrete financial information is available. The Company has aggregated certain operating segments into the above 

noted reportable segments through examination of the Company's performance which is based on the similarity of the goods and 

services provided and economic characteristics exhibited by these operating segments. Accounting policies used for segment 

reporting are consistent with the accounting policies used for the preparation of the Company’s consolidated financial statements. 

Inter-segmental transactions are eliminated upon consolidation and the Company does not recognize margins on inter-segmental 

transactions. 

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Year ended December 31, 2018 1 

Statement of operations 
Revenue 
  External .........................................  
Inter-segmental  ............................  
  External and inter-segmental  .......  

Infrastructure 

Logistics 

Wholesale 

Total 

  $    259,865 
131,762
391,627

  $ 

30,932
17,588
48,520

  $        6,555,792 

586,921  
7,142,713  

  $    6,846,589
736,271
7,582,860

Segment profit (loss) .........................  

  $    283,489 

  $ 

(7,513) 

  $           211,111 

  $       487,087

Gibson (U.S.) Acquisitionco Corp. 

Holding Company 

Gibson Energy Partnership 

Wholesale, transportation and 

Corporate & other reconciling items 

Depreciation and impairment of property, plant and equipment  .....................................................................................  
Depreciation of right-of-use assets  ....................................................................................................................................  
Amortization and impairment of intangible assets  ............................................................................................................  
Impairment of goodwill (note 14)  ......................................................................................................................................  
General and administrative  ................................................................................................................................................  
Share based compensation  ................................................................................................................................................  
Corporate foreign exchange gain  .......................................................................................................................................  
Interest expense, net  .........................................................................................................................................................  
Foreign exchange loss on long-term debt  ..........................................................................................................................  
Loss on sale of net assets held for sale (note 8) ..................................................................................................................  
Net income from continuing operations before income tax  ..............................................................................................  
Income tax expense (note 22) .............................................................................................................................................  
Net income from continuing operations  ............................................................................................................................  
Net income from discontinued operations, after tax (note 8) ............................................................................................  
Net income from operations  ..............................................................................................................................................  

143,160 
43,184 
10,870 
20,479 
32,155 
19,124 
(2,089) 
74,089 
4,403 
4,974 
136,738 
55,613 
           81,125 
           69,923 
    $     151,048  

Year ended December 31, 2017 1,2  

Statement of operations 
Revenue 
  External .........................................  
Inter-segmental .............................  
  External and inter-segmental ........  

Infrastructure 

Logistics 

Wholesale 

Total 

  $  205,561
131,340
336,901

  $ 

66,137
8,568
74,705

  $        5,387,948
429,304
5,817,252

  $  5,659,646 
569,212 
6,228,858 

Segment profit (loss) .........................  

  $  235,276

  $ 

(4,103)

  $             30,585

  $ 

261,758 

Corporate & other reconciling items 

Depreciation and impairment of property, plant and equipment  .....................................................................................  
Amortization and impairment of intangible assets  ............................................................................................................  
Impairment of goodwill (note 14)  ......................................................................................................................................  
General and administrative  ................................................................................................................................................  
Share based compensation  ................................................................................................................................................  
Corporate foreign exchange loss  ........................................................................................................................................  
Interest expense, net  .........................................................................................................................................................  
Debt extinguishment costs, net  .........................................................................................................................................  
Foreign exchange gain on long-term debt  .........................................................................................................................  
Net loss from continuing operations before income tax  ....................................................................................................  
Income tax recovery (note 22)  ...........................................................................................................................................  
Net loss from continuing operations  ..................................................................................................................................  
Net income from discontinued operations, after tax (note 8)  ...........................................................................................  
Net income from operations  ..............................................................................................................................................  

100,837 
23,340 
69,414 
50,016 
23,244 
652 
77,081 
60,492 
(18,788) 
(124,530) 
(58,204) 
(66,326) 
            110,461 
44,135 
  $ 

6 

Gibson Energy 

7 
55 

Consolidated Financial Statements

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
  
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
  
 
 
 
 
   
 
 
 
 
 
 
 
 
   
 
These consolidated financial statements include the results of the Company and its subsidiaries together with its interest in joint 

Subsidiaries are all entities over which the Company has control. The Company controls an entity when the Company is exposed to, 

or has rights to, variable returns from its involvement with the entity and has the ability to affect those returns through its power 

over the entity. Subsidiaries are fully consolidated from the date on which control is transferred to the Company and continue to be 

consolidated  until  the  date  control  ceases.  All  intercompany  transactions,  balances,  income  and  expenses  are  eliminated  on 

Joint arrangements are classified as either joint operations or joint ventures depending on the contractual rights and obligations of 

each investor.  The Company has assessed the nature of its joint arrangements and determined them to be joint operations and 

accordingly, the Company has recognized its proportionate share of revenues, expenses, assets and liabilities relating to these joint 

operations. 

consolidation.  

operations.  

Foreign currency translation 

The financial statements for each of the Company’s subsidiaries and joint operations are prepared using their functional currency. 

The functional currency is the currency of the primary economic environment in which an entity operates. The presentation and 

functional currency of the parent company is Canadian dollars. Assets and liabilities of foreign operations are translated into Canadian 

dollars at the market rates prevailing at the balance sheet date. Operating results are translated at the average rates for the period. 

Exchange differences arising on the consolidation of the net assets of foreign operations are recorded in other comprehensive income 

Foreign currency transactions are translated into the functional currency using exchange rates prevailing at the transaction date. 

Foreign exchange gains and losses resulting from the settlement of foreign currency transactions and from the translation at period 

end  exchange  rates  of  monetary  assets  and  liabilities  denominated  in  currencies  other  than  an  entity’s  functional  currency  are 

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

The breakdown of additions to property, plant and equipment and intangible assets by reportable segments are as follows: 

Basis of consolidation 

Infrastructure ............................................................................ 
Logistics ..................................................................................... 
Wholesale ................................................................................. 
Corporate .................................................................................. 
Total .........................................................................................  

Twelve months ended December 31 

2018 

2017 2 

Property, 
plant and 
equipment 

 $    265,751  
4,497  
650  
1,423  
$      272,321  

Intangible 
Assets 

$  20,241  
- 
- 
2,493 
$  22,734  

Property, 
plant and 
equipment 

$  161,326  
493  
1,093  
2,932  
$  165,844  

Intangible 
Assets 

$ 

$ 

2,849 
114 
35 
3,213 
6,211 

1.  Due to the adoption of new accounting standards effective January 1, 2018 as discussed in note 4, the comparative information has not been 

restated and, therefore, the results may not be comparable. 

2.  Comparative period segment information was restated to reflect the results of continuing operations separately from discontinued 

operations. See note 8 for further details. 

Geographic Data 

Based on the location of the end user, approximately 21% and 20% of revenue was from customers in the U.S. for the year ended 
December 31, 2018 and 2017, respectively.  

The Company’s non-current assets, excluding investment in finance leases and deferred tax assets, are primarily concentrated in 
Canada with 5% and 12% in the U.S. at December 31, 2018 and 2017, respectively. 

(loss).  

2  Basis of preparation and statement of compliance 

These consolidated financial statements have been prepared in compliance with International Financial Reporting Standards (“IFRS”) 
as  set  out  in  the  Handbook  of  the  Canadian  Institute  of  Chartered  Professional  Accountants  and  as  issued  by  the  International 
Accounting Standards Board (“IASB”).  

recognized in the consolidated statements of operations. 

Business combinations and goodwill 

Certain reclassifications of prior year amounts have been made to conform to the current year presentation and current information 
presented are not comparable due to the adoption of new IFRS as discussed in note 4 and the presentation of continuing operations 
separately from discontinued operations as discussed in note 8.  

These consolidated financial statements are presented in Canadian dollars, the Company’s functional currency, and all values are 
rounded  to  the  nearest  thousands  of  dollars,  except  where  indicated  otherwise.  All  references  to  $  are  to  Canadian  dollars  and 
references to US$ are to U.S. dollars. 

These consolidated financial statements were approved for issuance by the Company’s board of directors (“Board”) on March 4, 
2019.  

3 

Significant accounting policies 

The  significant  accounting  policies  applied  in  the  preparation  of  these  consolidated  financial  statements  are  set  out  below.  The 
policies discussed in note 3 and 4 have been consistently applied to the applicable years presented. 

Basis of measurement 

Business combinations are accounted for using the acquisition method of accounting. The cost of an acquisition is measured as the 

cash  paid  and  the  fair  value  of  other  assets  given,  equity  instruments  issued  and  liabilities  incurred  or  assumed  at  the  date  of 

exchange.  For  acquisitions  achieved  in  stages,  previously  held  equity  interests  in  the  acquired  company  are  remeasured  at  the 

acquisition date fair  value and the resulting gain or loss is recognized in the consolidated statements of operations. Direct costs 

incurred by the Company in connection with an acquisition, such as finder’s fees, advisors, legal, accounting, valuation and other 

professional or consulting fees, are expensed as general and administrative expenses when incurred. The acquired identifiable assets, 

liabilities and contingent liabilities are measured at their fair values at the date of acquisition. Any excess of the cost of acquisition 

plus the amount of any non-controlling interest in the acquiree, and the acquisition date fair value of the acquirer’s previously held 

equity interest, if any, over the net fair value of the identifiable assets, liabilities and contingent liabilities acquired is recognized as 

goodwill. Any deficiency of the cost of acquisition below  the fair values of the identifiable net assets acquired is credited to the 

consolidated statements of operations in the period of acquisition.  

Any  contingent  consideration  to  be  transferred  by  the  Company  is  recognised  at  fair  value  at  the  acquisition  date.  Subsequent 

changes to the fair value of the contingent consideration that are deemed to be an asset or liability are recognised in the consolidated 

statements of operations. Contingent consideration that is classified as equity is not re-measured, and its subsequent settlement is 

accounted for within equity. 

These consolidated financial statements have been prepared under the historical cost convention except for certain items that are 
recorded at fair value on a recurring basis as required by the respective accounting standards. 

At  the  acquisition  date,  any  goodwill  acquired  is  allocated  to  each  of  the  operating  segments  expected  to  benefit  from  the 

combination’s synergies. Following initial recognition, goodwill is measured at cost less any accumulated impairment losses. 

Consolidated Financial Statements 

8 

56 

Gibson Energy

9 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
   
 
 
 
 
 
 
   
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

The breakdown of additions to property, plant and equipment and intangible assets by reportable segments are as follows: 

Basis of consolidation 

Twelve months ended December 31 

2018 

Property, 

plant and 

equipment 

Intangible 

Assets 

2017 2 

Property, 

plant and 

equipment 

Intangible 

Assets 

Infrastructure ............................................................................ 

Logistics ..................................................................................... 

Wholesale ................................................................................. 

Corporate .................................................................................. 

Total .........................................................................................  

 $    265,751  

$  20,241  

$  161,326  

$ 

2,849 

4,497  

650  

1,423  

- 

- 

2,493 

493  

1,093  

2,932  

$      272,321  

$  22,734  

$  165,844  

$ 

114 

35 

3,213 

6,211 

1.  Due to the adoption of new accounting standards effective January 1, 2018 as discussed in note 4, the comparative information has not been 

restated and, therefore, the results may not be comparable. 

2.  Comparative period segment information was restated to reflect the results of continuing operations separately from discontinued 

operations. See note 8 for further details. 

Geographic Data 

December 31, 2018 and 2017, respectively.  

Based on the location of the end user, approximately 21% and 20% of revenue was from customers in the U.S. for the year ended 

The Company’s non-current assets, excluding investment in finance leases and deferred tax assets, are primarily concentrated in 

Canada with 5% and 12% in the U.S. at December 31, 2018 and 2017, respectively. 

2  Basis of preparation and statement of compliance 

These consolidated financial statements have been prepared in compliance with International Financial Reporting Standards (“IFRS”) 

as  set  out  in  the  Handbook  of  the  Canadian  Institute  of  Chartered  Professional  Accountants  and  as  issued  by  the  International 

Accounting Standards Board (“IASB”).  

Certain reclassifications of prior year amounts have been made to conform to the current year presentation and current information 

presented are not comparable due to the adoption of new IFRS as discussed in note 4 and the presentation of continuing operations 

separately from discontinued operations as discussed in note 8.  

These consolidated financial statements are presented in Canadian dollars, the Company’s functional currency, and all values are 

rounded  to  the  nearest  thousands  of  dollars,  except  where  indicated  otherwise.  All  references  to  $  are  to  Canadian  dollars  and 

references to US$ are to U.S. dollars. 

These consolidated financial statements were approved for issuance by the Company’s board of directors (“Board”) on March 4, 

2019.  

3 

Significant accounting policies 

Basis of measurement 

The  significant  accounting  policies  applied  in  the  preparation  of  these  consolidated  financial  statements  are  set  out  below.  The 

policies discussed in note 3 and 4 have been consistently applied to the applicable years presented. 

These consolidated financial statements include the results of the Company and its subsidiaries together with its interest in joint 
operations. 

Subsidiaries are all entities over which the Company has control. The Company controls an entity when the Company is exposed to, 
or has rights to, variable returns from its involvement with the entity and has the ability to affect those returns through its power 
over the entity. Subsidiaries are fully consolidated from the date on which control is transferred to the Company and continue to be 
consolidated  until  the  date  control  ceases.  All  intercompany  transactions,  balances,  income  and  expenses  are  eliminated  on 
consolidation.  

Joint arrangements are classified as either joint operations or joint ventures depending on the contractual rights and obligations of 
each investor.  The Company has assessed the nature of its joint arrangements and determined them to be joint operations and 
accordingly, the Company has recognized its proportionate share of revenues, expenses, assets and liabilities relating to these joint 
operations.  

Foreign currency translation 

The financial statements for each of the Company’s subsidiaries and joint operations are prepared using their functional currency. 
The functional currency is the currency of the primary economic environment in which an entity operates. The presentation and 
functional currency of the parent company is Canadian dollars. Assets and liabilities of foreign operations are translated into Canadian 
dollars at the market rates prevailing at the balance sheet date. Operating results are translated at the average rates for the period. 
Exchange differences arising on the consolidation of the net assets of foreign operations are recorded in other comprehensive income 
(loss).  

Foreign currency transactions are translated into the functional currency using exchange rates prevailing at the transaction date. 
Foreign exchange gains and losses resulting from the settlement of foreign currency transactions and from the translation at period 
end  exchange  rates  of  monetary  assets  and  liabilities  denominated  in  currencies  other  than  an  entity’s  functional  currency  are 
recognized in the consolidated statements of operations. 

Business combinations and goodwill 

Business combinations are accounted for using the acquisition method of accounting. The cost of an acquisition is measured as the 
cash  paid  and  the  fair  value  of  other  assets  given,  equity  instruments  issued  and  liabilities  incurred  or  assumed  at  the  date  of 
exchange.  For  acquisitions  achieved  in  stages,  previously  held  equity  interests  in  the  acquired  company  are  remeasured  at  the 
acquisition date fair  value and the resulting gain or loss is recognized in the consolidated statements of operations. Direct costs 
incurred by the Company in connection with an acquisition, such as finder’s fees, advisors, legal, accounting, valuation and other 
professional or consulting fees, are expensed as general and administrative expenses when incurred. The acquired identifiable assets, 
liabilities and contingent liabilities are measured at their fair values at the date of acquisition. Any excess of the cost of acquisition 
plus the amount of any non-controlling interest in the acquiree, and the acquisition date fair value of the acquirer’s previously held 
equity interest, if any, over the net fair value of the identifiable assets, liabilities and contingent liabilities acquired is recognized as 
goodwill. Any deficiency of the cost of acquisition below  the fair values of the identifiable net assets acquired is credited to the 
consolidated statements of operations in the period of acquisition.  

Any  contingent  consideration  to  be  transferred  by  the  Company  is  recognised  at  fair  value  at  the  acquisition  date.  Subsequent 
changes to the fair value of the contingent consideration that are deemed to be an asset or liability are recognised in the consolidated 
statements of operations. Contingent consideration that is classified as equity is not re-measured, and its subsequent settlement is 
accounted for within equity. 

These consolidated financial statements have been prepared under the historical cost convention except for certain items that are 

recorded at fair value on a recurring basis as required by the respective accounting standards. 

At  the  acquisition  date,  any  goodwill  acquired  is  allocated  to  each  of  the  operating  segments  expected  to  benefit  from  the 
combination’s synergies. Following initial recognition, goodwill is measured at cost less any accumulated impairment losses. 

8 

Gibson Energy 

9 
57 

Consolidated Financial Statements

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
   
 
 
 
 
 
 
   
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Intangible assets 

Impairments 

Intangible assets are stated at cost, less accumulated amortization and accumulated impairment losses.  

An intangible asset acquired as part of a business combination is measured at fair value at the date of acquisition and is recognized 
separately from goodwill if the asset is separable or arises from contractual or other legal rights and its fair value can be measured 
reliably. Intangible assets acquired separately from a business are carried initially at cost. The initial cost is the aggregate amount 
paid and the fair value of any other consideration given to acquire the asset. 

Intangible assets with a finite life are amortized on a straight-line basis over their expected useful lives as follows: 

Customer relationships  .............................................................................................................................................. 1 – 12 years 
Long-term customer contracts ................................................................................................................................... 6 – 10 years 
Technology, software and license ................................................................................................................................ 3 – 7 years 

The expected useful lives and method of amortization of intangible assets are reviewed on an annual basis and, if necessary, changes 
in expected useful life are accounted for prospectively. 

appropriate valuation model is used. 

The carrying value of intangible assets is reviewed for impairment whenever events or changes in circumstances indicate carrying 
value may not be recoverable. 

Property, plant and equipment 

An impairment loss in respect of goodwill is not reversible in the future. In respect of other assets, an impairment loss is reversed if 

there has been a triggering event which indicates a change in the recoverable amount. If there is a trigger that impairment loss 

recognized in the prior periods for an asset other than goodwill may no longer exist or may have decreased, the impairment loss is 

reversed only to the extent that the asset’s carrying amount does not exceed the carrying amount that would have been determined, 

net of depreciation or amortization, if no impairment loss had been previously recognized. 

Property, plant and equipment is stated at cost, less accumulated depreciation and accumulated impairment losses.  

Assets held for sale and discontinued operations 

The initial cost of an asset comprises its purchase price or construction cost, any costs directly attributable to bringing the asset into 
operation, the initial estimate of any decommissioning obligation, if any, and, for qualifying assets, borrowing costs. The purchase 
price or construction cost is the aggregate amount paid and the fair value of any other consideration given to acquire the asset.  

Expenditure on major maintenance refits or repairs comprises the cost of replacement assets or parts of assets, inspection costs and 
overhaul costs. Where an asset or part of an asset that was separately depreciated is replaced and it is probable that future economic 
benefits associated with the item will flow to the Company, the expenditure is capitalized and the carrying amount of the replaced 
asset is derecognized. Inspection costs associated with major maintenance programs are capitalized and amortized over the period 
to the next inspection. All other maintenance costs are expensed as incurred. 

Depreciation is charged so as to write off the cost of assets, other than assets that are work in progress, using the straight-line method 
over their expected useful lives. 

The useful lives of the Company’s property, plant and equipment are as follows: 

Buildings .................................................................................................................................................................... 10 – 20 years 
Equipment .................................................................................................................................................................. 3 – 20 years 
Rolling stock  ............................................................................................................................................................... 5 – 23 years 
Pipelines and connections .......................................................................................................................................... 8 – 20 years 
Tanks  ........................................................................................................................................................................ 20 – 33 years 
Plant  ........................................................................................................................................................................... 7 – 25 years 
Disposal wells ............................................................................................................................................................ 15 – 25 years 

The expected useful lives, method of depreciation and residual values of property, plant and equipment are reviewed on an annual 
basis and, if necessary, changes are accounted for prospectively. 

An item of property, plant and equipment is derecognized upon disposal or when no future economic benefits are expected to arise 
from the continued use of the asset. Any gain or loss arising on derecognition of the asset (calculated as the difference between the 
net disposal proceeds and the carrying amount of the item) is included in the consolidated statements of operations in the period 
the item is derecognized. 

Consolidated Financial Statements 

10 

58 

Gibson Energy

11 

The Company carries out impairment reviews in respect of goodwill at least annually or if indicators of possible impairment exist. 

The Company also assesses during each reporting period whether there have been any events or changes in circumstances that 

indicate that property, plant and equipment and intangible assets may be impaired and an impairment review is carried out whenever 

such  an  assessment  indicates  that  the  carrying  amount  may  not  be  recoverable.  Such  indicators  include,  but  are  not  limited  to 

changes in the Company’s business plans, economic performance of the assets, changes in commodity prices leading to lower activity 

levels, an increase in the discount rate and evidence of physical damage. For the purposes of impairment testing, assets are grouped 

at the lowest levels for which there are separately identifiable cash inflows. Where impairment exists, the asset is written down to 

its recoverable amount, which is the higher of the fair value less costs of disposal (FVLCD) and its value in use (VIU). Impairments are 

recognized immediately in the consolidated statements of operations.  

The assessment for impairment entails comparing the carrying value of the asset or cash-generating unit with its recoverable amount, 

that  is,  the  higher  of  FVLCD  and  VIU.  VIU  is  usually  determined  on  the  basis  of  discounted  estimated  future  net  cash  flows.  In 

determining  FVLCD,  recent  market  transactions  are  taken  into  account,  if  available.  In  the  absence  of  such  transactions,  an 

Non-current assets are classified as held for sale if their carrying amounts will be recovered through a sale transaction rather than 

through continuing use. This condition is met when the sale is highly probable and the asset is available for immediate sale in its 

present condition. 

Non-current assets and disposal groups are classified and presented as discontinued operations if the assets or disposal groups are 

disposed of or classified as held for sale and: 

the assets or disposal groups are a major line of business or geographical area of operations; 

the assets or disposal groups are part of a single coordinated plan to dispose of a separate major line of business or geographical 

area of operations; or 

the assets or disposal groups are a subsidiary acquired solely for the purpose of resale. 

- 

- 

- 

The assets or disposal groups that meet these criteria are measured at the lower of the carrying amount and FVLCD with impairments 

recognized in the consolidated statements of operations, except for deferred tax assets that are recognized for tax loss carry-forwards 

to the extent that the realization of the related tax benefit through future taxable profits is probable. An impairment loss is recognized 

for any initial or subsequent write-down of the asset (or disposal group) to fair value less costs to dispose. Non-current assets held 

for sale are presented separately in current assets and liabilities within the consolidated balance sheet. Assets held for sale are not 

depreciated, depleted or amortized. The comparative period consolidated balance sheet is not restated.  

The  results  of  discontinued  operations  are  shown  separately  in  the  consolidated  statements  of  operations  and  cash  flows  and 

comparative figures are restated. 

 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Intangible assets 

Impairments 

The Company carries out impairment reviews in respect of goodwill at least annually or if indicators of possible impairment exist. 
The Company also assesses during each reporting period whether there have been any events or changes in circumstances that 
indicate that property, plant and equipment and intangible assets may be impaired and an impairment review is carried out whenever 
such  an  assessment  indicates  that  the  carrying  amount  may  not  be  recoverable.  Such  indicators  include,  but  are  not  limited  to 
changes in the Company’s business plans, economic performance of the assets, changes in commodity prices leading to lower activity 
levels, an increase in the discount rate and evidence of physical damage. For the purposes of impairment testing, assets are grouped 
at the lowest levels for which there are separately identifiable cash inflows. Where impairment exists, the asset is written down to 
its recoverable amount, which is the higher of the fair value less costs of disposal (FVLCD) and its value in use (VIU). Impairments are 
recognized immediately in the consolidated statements of operations.  

The assessment for impairment entails comparing the carrying value of the asset or cash-generating unit with its recoverable amount, 
that  is,  the  higher  of  FVLCD  and  VIU.  VIU  is  usually  determined  on  the  basis  of  discounted  estimated  future  net  cash  flows.  In 
determining  FVLCD,  recent  market  transactions  are  taken  into  account,  if  available.  In  the  absence  of  such  transactions,  an 
appropriate valuation model is used. 

An impairment loss in respect of goodwill is not reversible in the future. In respect of other assets, an impairment loss is reversed if 
there has been a triggering event which indicates a change in the recoverable amount. If there is a trigger that impairment loss 
recognized in the prior periods for an asset other than goodwill may no longer exist or may have decreased, the impairment loss is 
reversed only to the extent that the asset’s carrying amount does not exceed the carrying amount that would have been determined, 
net of depreciation or amortization, if no impairment loss had been previously recognized. 

Property, plant and equipment is stated at cost, less accumulated depreciation and accumulated impairment losses.  

Assets held for sale and discontinued operations 

Non-current assets are classified as held for sale if their carrying amounts will be recovered through a sale transaction rather than 
through continuing use. This condition is met when the sale is highly probable and the asset is available for immediate sale in its 
present condition. 

Depreciation is charged so as to write off the cost of assets, other than assets that are work in progress, using the straight-line method 

- 

Non-current assets and disposal groups are classified and presented as discontinued operations if the assets or disposal groups are 
disposed of or classified as held for sale and: 
- 
- 

the assets or disposal groups are a major line of business or geographical area of operations; 
the assets or disposal groups are part of a single coordinated plan to dispose of a separate major line of business or geographical 
area of operations; or 
the assets or disposal groups are a subsidiary acquired solely for the purpose of resale. 

The assets or disposal groups that meet these criteria are measured at the lower of the carrying amount and FVLCD with impairments 
recognized in the consolidated statements of operations, except for deferred tax assets that are recognized for tax loss carry-forwards 
to the extent that the realization of the related tax benefit through future taxable profits is probable. An impairment loss is recognized 
for any initial or subsequent write-down of the asset (or disposal group) to fair value less costs to dispose. Non-current assets held 
for sale are presented separately in current assets and liabilities within the consolidated balance sheet. Assets held for sale are not 
depreciated, depleted or amortized. The comparative period consolidated balance sheet is not restated.  

The  results  of  discontinued  operations  are  shown  separately  in  the  consolidated  statements  of  operations  and  cash  flows  and 
comparative figures are restated. 

10 

Gibson Energy 

11 
59 

Consolidated Financial Statements

Intangible assets are stated at cost, less accumulated amortization and accumulated impairment losses.  

An intangible asset acquired as part of a business combination is measured at fair value at the date of acquisition and is recognized 

separately from goodwill if the asset is separable or arises from contractual or other legal rights and its fair value can be measured 

reliably. Intangible assets acquired separately from a business are carried initially at cost. The initial cost is the aggregate amount 

paid and the fair value of any other consideration given to acquire the asset. 

Intangible assets with a finite life are amortized on a straight-line basis over their expected useful lives as follows: 

Customer relationships  .............................................................................................................................................. 1 – 12 years 

Long-term customer contracts ................................................................................................................................... 6 – 10 years 

Technology, software and license ................................................................................................................................ 3 – 7 years 

The expected useful lives and method of amortization of intangible assets are reviewed on an annual basis and, if necessary, changes 

in expected useful life are accounted for prospectively. 

The carrying value of intangible assets is reviewed for impairment whenever events or changes in circumstances indicate carrying 

value may not be recoverable. 

Property, plant and equipment 

The initial cost of an asset comprises its purchase price or construction cost, any costs directly attributable to bringing the asset into 

operation, the initial estimate of any decommissioning obligation, if any, and, for qualifying assets, borrowing costs. The purchase 

price or construction cost is the aggregate amount paid and the fair value of any other consideration given to acquire the asset.  

Expenditure on major maintenance refits or repairs comprises the cost of replacement assets or parts of assets, inspection costs and 

overhaul costs. Where an asset or part of an asset that was separately depreciated is replaced and it is probable that future economic 

benefits associated with the item will flow to the Company, the expenditure is capitalized and the carrying amount of the replaced 

asset is derecognized. Inspection costs associated with major maintenance programs are capitalized and amortized over the period 

to the next inspection. All other maintenance costs are expensed as incurred. 

over their expected useful lives. 

The useful lives of the Company’s property, plant and equipment are as follows: 

Buildings .................................................................................................................................................................... 10 – 20 years 

Equipment .................................................................................................................................................................. 3 – 20 years 

Rolling stock  ............................................................................................................................................................... 5 – 23 years 

Pipelines and connections .......................................................................................................................................... 8 – 20 years 

Tanks  ........................................................................................................................................................................ 20 – 33 years 

Plant  ........................................................................................................................................................................... 7 – 25 years 

Disposal wells ............................................................................................................................................................ 15 – 25 years 

The expected useful lives, method of depreciation and residual values of property, plant and equipment are reviewed on an annual 

basis and, if necessary, changes are accounted for prospectively. 

An item of property, plant and equipment is derecognized upon disposal or when no future economic benefits are expected to arise 

from the continued use of the asset. Any gain or loss arising on derecognition of the asset (calculated as the difference between the 

net disposal proceeds and the carrying amount of the item) is included in the consolidated statements of operations in the period 

the item is derecognized. 

 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Inventories 

Past-service costs or credits are recognised immediately in the consolidated statements of operations. 

Inventories are carried at the lower of cost and net realizable value, with cost determined using a weighted average cost method. 
Net realizable value is the estimated selling price less applicable selling expenses. If carrying value exceeds net realizable amount, a 
write down is recognized. The write down may be reversed in a subsequent period if the circumstances which caused it no longer 
exist. 

Provisions and contingencies 

Provisions are recognized when the Company has a present obligation, legal or constructive, as a result of a past event, it is probable 
that an outflow of resources embodying economic benefits will be required to settle the obligation and a reliable estimate can be 
made of the amount of the obligation. Where appropriate, the future cash flow estimates are adjusted to reflect risks specific to the 
liability. 

If the effect of the time value of money is material, provisions are determined by discounting the expected future cash flows at a pre-
tax rate that reflects current market assessments of the time value of money. Where discounting is used, the increase in the provision 
due to the passage of time is recognized within finance costs. 

A contingent liability is disclosed where the existence of an obligation will only be confirmed by future events or where the amount 
of the obligation cannot be measured reliably and outflow of cash is less than remote. Contingent assets are not recognized, but are 
disclosed when an inflow of economic benefits is probable. 

Decommissioning 

Liabilities for site restoration on the retirement of assets are recognized when the Company has an obligation to restore the site, and 
when a reliable estimate of that liability can be made. An obligation may also crystallize during the period of operation of a facility 
through a change in legislation or through a decision to terminate operations. The amount recognized is the present value of the 
estimated future expenditure determined in accordance with local conditions and requirements. The present value is determined by 
discounting the expenditures expected to be required to settle the obligation using a risk-free discount rate. Actual expenditures 
incurred are charged against the accumulated liability. 

A  corresponding  item  of  property,  plant  and  equipment  of  an  amount  equivalent  to  the  provision  is  also  created.  The  amount 
capitalized in property, plant and equipment is depreciated over the useful life of the related asset. Increases in the decommissioning 
liabilities resulting from the passage of time are recognized as a finance cost in the consolidated statements of operations. Other 
than the unwinding of the discount on the provision, any change in the present value of the estimated expenditure is reflected as an 
adjustment to the provision and the corresponding item of property, plant and equipment. 

Environmental liabilities 

Environmental liabilities are recognized when a remediation is probable and the associated costs can be reliably estimated. Generally, 
the timing of recognition of these provisions coincides with the completion of a feasibility study or a commitment to a formal plan 
of action. The amount recognized is the best estimate of the expenditure required. Where the liability will not be settled for a number 
of years, the amount recognized is the present value of the estimated future expenditure using a risk-free discount rate. 

Employee benefits 

Defined benefit pension plan  

The liability recognised in respect of defined benefit plans is the present value of the defined benefit obligation at the end of the 
reporting period less the fair value of plan assets. The defined benefit obligation is calculated annually by independent actuaries 
using  the  projected  unit  credit  method.  The  present  value  of  the  defined  benefit  obligation  is  determined  by  discounting  the 
estimated future cash outflows using interest rates of high-quality corporate bonds that are denominated in the currency in which 
the benefits will be paid, and that have terms to maturity approximating to the terms of the related pension obligation. 

Actuarial gains and losses arising from experience adjustments and changes in actuarial assumptions are charged or credited to equity 
in other comprehensive income (loss) in the period in which they arise. 

Consolidated Financial Statements 

12 

60 

Gibson Energy

13 

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Defined contribution pension plans 

are earned by employees and funded by the Company. 

Share-based payments 

The Company’s defined contribution plans are funded as specified in the plans and the pension expense is recorded as the benefits 

The Company’s equity incentive plan allows for the granting of stock options, restricted share units with time based vesting (RSUs) 

and performance share units (PSUs) with performance based vesting conditions and deferred share units (DSUs) that vest on the 

date such employee redeems the DSUs after their cessation of employment with the Company. 

The fair value of grants made under the employee share award plan is measured at the date of grant of the award. The resulting cost, 

as adjusted for the expected and actual level of vesting of the awards, is expensed over the period in which the awards vest.  

At each balance sheet date before vesting, the cumulative expense is calculated, representing the extent to which the vesting period 

has expired and management’s best estimate of the number of equity instruments that will ultimately vest. 

The movement in the cumulative expense since the previous balance sheet date is recognized in the consolidated statements of 

operations with a corresponding impact to contributed surplus. 

The fair value of RSUs, PSUs and DSUs is equal to the Company’s five day weighted average share price at the date of grant.  

The fair value of options is measured by using the Black-Scholes model. The Black-Scholes option valuation model was developed for 

use in estimating the fair value of traded options that have no vesting restrictions and are fully transferable and it requires the input 

of  highly  subjective  assumptions.  Expected  volatility  of  the  stock  is  based  on  a  combination  of  the  historical  stock  price  of  the 

Company and also of comparable companies in the industry. The expected term of options represents the period of time that options 

granted are expected to be outstanding. The risk-free rate is based on the Government of Canada’s Canadian Bond Yields with a 

remaining term equal to the expected life of the options used in the Black-Scholes valuation model.  

The  Company  recognizes  termination  benefits  as  an  expense  when  it  is  demonstrably  committed  to  either  terminating  the 

employment of current employees according to a detailed formal plan without possibility of withdrawal, or providing benefits as a 

result of an offer made to encourage voluntary termination. 

Termination benefit 

Income taxes 

Income tax expense represents the sum of the income tax currently payable and deferred income tax. Interest and penalties relating 

to income tax are included in interest expense. 

The income tax currently payable is based on the taxable income for the period. Taxable income differs from net income as reported 

in the consolidated statements of operations because it excludes items of income or expense that are taxable or deductible in other 

periods and it further excludes items that are never taxable or deductible. The Company’s liability for current income tax is calculated 

using tax rates that have been enacted or substantively enacted by the balance sheet date. 

Deferred income tax is provided for using the liability method of accounting. Deferred income tax assets and liabilities are determined 

based  on  differences  between  the  financial  reporting  and  income  tax  basis  of  assets  and  liabilities.  These  differences  are  then 

measured using enacted or substantially enacted income tax rates and laws that will be in effect when these differences are expected 

to reverse. The effect of a change in income tax rates on deferred tax assets and liabilities is recognized in income in the period that 

the change occurs. Deferred income tax assets are recognized for tax loss carry-forwards to the extent that the realization of the 

related tax benefit through future taxable profits is probable.  

 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Inventories 

Past-service costs or credits are recognised immediately in the consolidated statements of operations. 

Inventories are carried at the lower of cost and net realizable value, with cost determined using a weighted average cost method. 

Defined contribution pension plans 

Net realizable value is the estimated selling price less applicable selling expenses. If carrying value exceeds net realizable amount, a 

write down is recognized. The write down may be reversed in a subsequent period if the circumstances which caused it no longer 

The Company’s defined contribution plans are funded as specified in the plans and the pension expense is recorded as the benefits 
are earned by employees and funded by the Company. 

Share-based payments 

Provisions are recognized when the Company has a present obligation, legal or constructive, as a result of a past event, it is probable 

that an outflow of resources embodying economic benefits will be required to settle the obligation and a reliable estimate can be 

made of the amount of the obligation. Where appropriate, the future cash flow estimates are adjusted to reflect risks specific to the 

The Company’s equity incentive plan allows for the granting of stock options, restricted share units with time based vesting (RSUs) 
and performance share units (PSUs) with performance based vesting conditions and deferred share units (DSUs) that vest on the 
date such employee redeems the DSUs after their cessation of employment with the Company. 

The fair value of grants made under the employee share award plan is measured at the date of grant of the award. The resulting cost, 
as adjusted for the expected and actual level of vesting of the awards, is expensed over the period in which the awards vest.  

At each balance sheet date before vesting, the cumulative expense is calculated, representing the extent to which the vesting period 
has expired and management’s best estimate of the number of equity instruments that will ultimately vest. 

The movement in the cumulative expense since the previous balance sheet date is recognized in the consolidated statements of 
operations with a corresponding impact to contributed surplus. 

The fair value of RSUs, PSUs and DSUs is equal to the Company’s five day weighted average share price at the date of grant.  

The fair value of options is measured by using the Black-Scholes model. The Black-Scholes option valuation model was developed for 
use in estimating the fair value of traded options that have no vesting restrictions and are fully transferable and it requires the input 
of  highly  subjective  assumptions.  Expected  volatility  of  the  stock  is  based  on  a  combination  of  the  historical  stock  price  of  the 
Company and also of comparable companies in the industry. The expected term of options represents the period of time that options 
granted are expected to be outstanding. The risk-free rate is based on the Government of Canada’s Canadian Bond Yields with a 
remaining term equal to the expected life of the options used in the Black-Scholes valuation model.  

Termination benefit 

The  Company  recognizes  termination  benefits  as  an  expense  when  it  is  demonstrably  committed  to  either  terminating  the 
employment of current employees according to a detailed formal plan without possibility of withdrawal, or providing benefits as a 
result of an offer made to encourage voluntary termination. 

Income taxes 

Income tax expense represents the sum of the income tax currently payable and deferred income tax. Interest and penalties relating 
to income tax are included in interest expense. 

The income tax currently payable is based on the taxable income for the period. Taxable income differs from net income as reported 
in the consolidated statements of operations because it excludes items of income or expense that are taxable or deductible in other 
periods and it further excludes items that are never taxable or deductible. The Company’s liability for current income tax is calculated 
using tax rates that have been enacted or substantively enacted by the balance sheet date. 

Deferred income tax is provided for using the liability method of accounting. Deferred income tax assets and liabilities are determined 
based  on  differences  between  the  financial  reporting  and  income  tax  basis  of  assets  and  liabilities.  These  differences  are  then 
measured using enacted or substantially enacted income tax rates and laws that will be in effect when these differences are expected 
to reverse. The effect of a change in income tax rates on deferred tax assets and liabilities is recognized in income in the period that 
the change occurs. Deferred income tax assets are recognized for tax loss carry-forwards to the extent that the realization of the 
related tax benefit through future taxable profits is probable.  

12 

Gibson Energy 

13 
61 

Consolidated Financial Statements

exist. 

Provisions and contingencies 

liability. 

If the effect of the time value of money is material, provisions are determined by discounting the expected future cash flows at a pre-

tax rate that reflects current market assessments of the time value of money. Where discounting is used, the increase in the provision 

due to the passage of time is recognized within finance costs. 

A contingent liability is disclosed where the existence of an obligation will only be confirmed by future events or where the amount 

of the obligation cannot be measured reliably and outflow of cash is less than remote. Contingent assets are not recognized, but are 

disclosed when an inflow of economic benefits is probable. 

Decommissioning 

Liabilities for site restoration on the retirement of assets are recognized when the Company has an obligation to restore the site, and 

when a reliable estimate of that liability can be made. An obligation may also crystallize during the period of operation of a facility 

through a change in legislation or through a decision to terminate operations. The amount recognized is the present value of the 

estimated future expenditure determined in accordance with local conditions and requirements. The present value is determined by 

discounting the expenditures expected to be required to settle the obligation using a risk-free discount rate. Actual expenditures 

incurred are charged against the accumulated liability. 

A  corresponding  item  of  property,  plant  and  equipment  of  an  amount  equivalent  to  the  provision  is  also  created.  The  amount 

capitalized in property, plant and equipment is depreciated over the useful life of the related asset. Increases in the decommissioning 

liabilities resulting from the passage of time are recognized as a finance cost in the consolidated statements of operations. Other 

than the unwinding of the discount on the provision, any change in the present value of the estimated expenditure is reflected as an 

adjustment to the provision and the corresponding item of property, plant and equipment. 

Environmental liabilities are recognized when a remediation is probable and the associated costs can be reliably estimated. Generally, 

the timing of recognition of these provisions coincides with the completion of a feasibility study or a commitment to a formal plan 

of action. The amount recognized is the best estimate of the expenditure required. Where the liability will not be settled for a number 

of years, the amount recognized is the present value of the estimated future expenditure using a risk-free discount rate. 

Environmental liabilities 

Employee benefits 

Defined benefit pension plan  

The liability recognised in respect of defined benefit plans is the present value of the defined benefit obligation at the end of the 

reporting period less the fair value of plan assets. The defined benefit obligation is calculated annually by independent actuaries 

using  the  projected  unit  credit  method.  The  present  value  of  the  defined  benefit  obligation  is  determined  by  discounting  the 

estimated future cash outflows using interest rates of high-quality corporate bonds that are denominated in the currency in which 

the benefits will be paid, and that have terms to maturity approximating to the terms of the related pension obligation. 

Actuarial gains and losses arising from experience adjustments and changes in actuarial assumptions are charged or credited to equity 

in other comprehensive income (loss) in the period in which they arise. 

 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Cost of sales 

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Provisions 

Cost of sales includes the cost of finished goods inventory (including depreciation, amortization and impairment charges), processing 
costs, costs related to transportation, inventory write downs and reversals, and gains and losses on derivative financial instruments 
relating to commodities. 

Borrowing costs 

General and specific borrowing costs directly attributable to the acquisition, construction or production of qualifying assets, which 
are assets that take a substantial period of time to get ready for their intended use or sale, are added to the cost of those assets, 
until such time as the assets are substantially ready for their intended use or sale. All other borrowing costs are recognized in the 
consolidated statements of operations in the period in which they are incurred. 

Per share amounts 

Basic per share amounts are calculated using the weighted average number of shares outstanding during the year. Diluted per share 
amounts  are  calculated  giving  effect  to  the  potential  dilution  that  would  occur  if  stock  options  and  other  equity  awards  were 
exercised or converted into common shares. 

Segmental reporting 

The Company determines its reportable segments based on the nature of its operations, which is consistent with how the business 
is managed and results are reported to the chief operating decision maker. Each operating segment also uses a measure of profit 
and loss that represents segment profit. The chief operating decision maker, who is responsible for resource allocation and assessing 
performance of the operating segments, has been identified as the President and Chief Executive Officer.  

Critical accounting estimates and judgements 

The  preparation  of  financial  statements  in  conformity  with  IFRS  requires  the  use  of  certain  critical  accounting  estimates.  It  also 
requires  management  to  exercise  its  judgement  in  the  process  of  applying  the  Company’s  accounting  policies.  Estimates  and 
judgements  are  continually  evaluated  and  are based  on  historical  experience  and  other  factors,  including  expectations  of  future 
events that are believed to be reasonable under the circumstances. 

Critical accounting estimates and assumptions 

The preparation of financial statements requires management to make estimates and assumptions that affect the reported amounts 
of assets and liabilities as well as the disclosure of contingent assets and liabilities at the balance sheet date and the reported amounts 
of  revenues  and  expenses  during  the  reporting  period.  Actual  outcomes  could  differ  from  those  estimates.  The  estimates  and 
assumptions that have a significant risk of causing a material adjustment to the carrying amounts of assets and liabilities within the 
next financial year are addressed below. 

Impairment assessment of non-financial assets  

The  Company  tests  annually  whether  goodwill  of  an  operating  segment  has  suffered  any  impairment,  in  accordance  with  the 
Company’s accounting policy. The recoverable amounts of the operating segments are determined based on the higher of VIU and 
FVLCD calculations that require the use of estimates. The Company also assesses whether there have been any events or changes in 
circumstances that indicate that property, plant and equipment and other intangible assets may be impaired and an impairment 
review is carried out whenever such an assessment indicates that the carrying amount may not be recoverable.  

In  the  impairment  analysis  of  the  Company’s  assets,  some  of  the  key  assumptions  used  in  estimating  future  cash  flows  include 
revenue  growth,  future  commodity  prices,  expected  margin,  expected  sales  volumes,  cost  structures  and  the  outlook  of  market 
supply and demand conditions appropriate to the local circumstances and macro-economic environment. These assumptions and 
estimates are uncertain and are subject to change as new information becomes available. Changes in economic conditions can also 
affect the rate used to discount future cash flow estimates.  

Accruals for decommissioning and environmental remediation are recorded when it is considered probable and the costs can be 

reasonably estimated. A number of factors affect the cost of environmental remediation, including the determination of the extent 

of contamination, the length of time remediation may require, the complexity of environmental regulations and the advancement 

of technology. Considering these factors, the Company has estimated the costs of remediation, which are likely to be incurred in 

future years. The Company believes the provisions made for environmental matters are adequate, however it is reasonably possible 

that  actual  costs  may  differ  from  the  estimated  accrual,  if  the  selected  methods  of  remediation  do  not  adequately  reduce  the 

contaminates and if further remedial action is required. The Company uses third-party environmental evaluators, where determined 

necessary, to obtain the estimates of the decommissioning and environmental provision.  

Critical judgements in applying the Company’s accounting policies 

Assets held for sale and discontinued operations 

As at December 31, 2018, the Company considered certain businesses and assets as held-for-sale and discontinued operations (refer 

to note 8, Assets and liabilities held for sale). In making these determinations, the Company used significant judgment in evaluating 

whether a sale was considered highly probable and considered the progress of negotiations specific to significant terms of the sales, 

including  the  structure  of  the  transaction  and  if  the  buyer  has  substantially  completed  their  due  diligence  review.  For  these 

businesses and assets these conditions were all met during the year ended December 31, 2018. The Company also used significant 

judgment  in  evaluating  whether  a  disposal  group  represented  a  major  line  of  business  or  geographical  area  of  operations  to  be 

reported within discontinued operations, considering if the disposal group is a component of an entity and its materiality in relation 

to the reportable segment. These criterias were met for certain disposal groups.  

Identification of cash-generating unit (“CGU”) 

For the purposes of impairment testing, assets are grouped at the lowest levels of integrated assets that generate identifiable cash 

inflows that are largely independent of the cash inflows of other assets or groups of assets, termed as a CGU. The allocation of assets 

into a CGU requires significant judgment and interpretations with respect to the integration between assets, the existence of active 

markets, similar exposure to market risks, shared infrastructures and the way in which management monitors the operations. 

Investment in finance leases 

In determining whether certain of the Company’s long-term tank storage arrangements are, or contain, a lease, the Company must 

use judgement in assessing whether if the arrangement conveys the right to control the use of an identified asset for a period of time 

in  exchange  for  consideration.  Where  such  rights  do  not  exist,  the  arrangement  is  considered  a  service  contract.  For  those 

arrangements considered to be a lease, further judgement is required to determine whether if substantially all of the significant risks 

and  rewards  of  ownership  are  transferred  to  the  customer  or  remain  with  the  Company,  to  appropriately  account  for  the 

arrangement as a finance or operating lease. These judgements can be significant as to how the Company classifies amounts related 

to the arrangements as property, plant and equipment or net investment in finance lease on the balance sheet. The Company has 

determined, based on the terms and conditions of these arrangements, that the substantial risks and rewards to the ownership of 

certain  storage  tanks  have  been  transferred  to  the  customer,  and  accordingly,  these  storage  tanks  have  been  recognized  as  an 

investment in finance lease. 

Current and deferred taxation 

The computation of the Company’s income tax expense involves the interpretation of applicable tax laws and regulations in many 

jurisdictions. The resolution of tax positions taken by the Company can take significant time to complete and in some cases it is 

difficult to predict the ultimate outcome. In addition, the Company has carry-forward tax losses in certain taxing jurisdictions that 

are available to offset against future taxable profit. This involves an assessment of when those deferred tax assets are likely to be 

realized, and a judgment as to whether or not there will be sufficient taxable profits available to offset the tax assets when they do 

reverse. This requires assumptions regarding future profitability and is therefore inherently uncertain. To the extent assumptions 

regarding future profitability change, there can be an increase or decrease in the amounts recognized in respect of deferred tax 

assets  as  well  as  in  the  amounts  recognized  in  consolidated  statements  of  operations  in  the  period  in  which the  change  occurs. 

However, deferred income tax assets are recognized only to the extent that it is probable that taxable profit will be available against 

Consolidated Financial Statements 

14 

62 

Gibson Energy

15 

 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Provisions 

Accruals for decommissioning and environmental remediation are recorded when it is considered probable and the costs can be 
reasonably estimated. A number of factors affect the cost of environmental remediation, including the determination of the extent 
of contamination, the length of time remediation may require, the complexity of environmental regulations and the advancement 
of technology. Considering these factors, the Company has estimated the costs of remediation, which are likely to be incurred in 
future years. The Company believes the provisions made for environmental matters are adequate, however it is reasonably possible 
that  actual  costs  may  differ  from  the  estimated  accrual,  if  the  selected  methods  of  remediation  do  not  adequately  reduce  the 
contaminates and if further remedial action is required. The Company uses third-party environmental evaluators, where determined 
necessary, to obtain the estimates of the decommissioning and environmental provision.  

Critical judgements in applying the Company’s accounting policies 

Assets held for sale and discontinued operations 

As at December 31, 2018, the Company considered certain businesses and assets as held-for-sale and discontinued operations (refer 
to note 8, Assets and liabilities held for sale). In making these determinations, the Company used significant judgment in evaluating 
whether a sale was considered highly probable and considered the progress of negotiations specific to significant terms of the sales, 
including  the  structure  of  the  transaction  and  if  the  buyer  has  substantially  completed  their  due  diligence  review.  For  these 
businesses and assets these conditions were all met during the year ended December 31, 2018. The Company also used significant 
judgment  in  evaluating  whether  a  disposal  group  represented  a  major  line  of  business  or  geographical  area  of  operations  to  be 
reported within discontinued operations, considering if the disposal group is a component of an entity and its materiality in relation 
to the reportable segment. These criterias were met for certain disposal groups.  

Identification of cash-generating unit (“CGU”) 

For the purposes of impairment testing, assets are grouped at the lowest levels of integrated assets that generate identifiable cash 
inflows that are largely independent of the cash inflows of other assets or groups of assets, termed as a CGU. The allocation of assets 
into a CGU requires significant judgment and interpretations with respect to the integration between assets, the existence of active 
markets, similar exposure to market risks, shared infrastructures and the way in which management monitors the operations. 

Investment in finance leases 

In determining whether certain of the Company’s long-term tank storage arrangements are, or contain, a lease, the Company must 
use judgement in assessing whether if the arrangement conveys the right to control the use of an identified asset for a period of time 
in  exchange  for  consideration.  Where  such  rights  do  not  exist,  the  arrangement  is  considered  a  service  contract.  For  those 
arrangements considered to be a lease, further judgement is required to determine whether if substantially all of the significant risks 
and  rewards  of  ownership  are  transferred  to  the  customer  or  remain  with  the  Company,  to  appropriately  account  for  the 
arrangement as a finance or operating lease. These judgements can be significant as to how the Company classifies amounts related 
to the arrangements as property, plant and equipment or net investment in finance lease on the balance sheet. The Company has 
determined, based on the terms and conditions of these arrangements, that the substantial risks and rewards to the ownership of 
certain  storage  tanks  have  been  transferred  to  the  customer,  and  accordingly,  these  storage  tanks  have  been  recognized  as  an 
investment in finance lease. 

Current and deferred taxation 

The computation of the Company’s income tax expense involves the interpretation of applicable tax laws and regulations in many 
jurisdictions. The resolution of tax positions taken by the Company can take significant time to complete and in some cases it is 
difficult to predict the ultimate outcome. In addition, the Company has carry-forward tax losses in certain taxing jurisdictions that 
are available to offset against future taxable profit. This involves an assessment of when those deferred tax assets are likely to be 
realized, and a judgment as to whether or not there will be sufficient taxable profits available to offset the tax assets when they do 
reverse. This requires assumptions regarding future profitability and is therefore inherently uncertain. To the extent assumptions 
regarding future profitability change, there can be an increase or decrease in the amounts recognized in respect of deferred tax 
assets  as  well  as  in  the  amounts  recognized  in  consolidated  statements  of  operations  in  the  period  in  which the  change  occurs. 
However, deferred income tax assets are recognized only to the extent that it is probable that taxable profit will be available against 

14 

Gibson Energy 

15 
63 

Consolidated Financial Statements

Cost of sales 

relating to commodities. 

Borrowing costs 

Per share amounts 

Cost of sales includes the cost of finished goods inventory (including depreciation, amortization and impairment charges), processing 

costs, costs related to transportation, inventory write downs and reversals, and gains and losses on derivative financial instruments 

General and specific borrowing costs directly attributable to the acquisition, construction or production of qualifying assets, which 

are assets that take a substantial period of time to get ready for their intended use or sale, are added to the cost of those assets, 

until such time as the assets are substantially ready for their intended use or sale. All other borrowing costs are recognized in the 

consolidated statements of operations in the period in which they are incurred. 

Basic per share amounts are calculated using the weighted average number of shares outstanding during the year. Diluted per share 

amounts  are  calculated  giving  effect  to  the  potential  dilution  that  would  occur  if  stock  options  and  other  equity  awards  were 

exercised or converted into common shares. 

Segmental reporting 

The Company determines its reportable segments based on the nature of its operations, which is consistent with how the business 

is managed and results are reported to the chief operating decision maker. Each operating segment also uses a measure of profit 

and loss that represents segment profit. The chief operating decision maker, who is responsible for resource allocation and assessing 

performance of the operating segments, has been identified as the President and Chief Executive Officer.  

Critical accounting estimates and judgements 

The  preparation  of  financial  statements  in  conformity  with  IFRS  requires  the  use  of  certain  critical  accounting  estimates.  It  also 

requires  management  to  exercise  its  judgement  in  the  process  of  applying  the  Company’s  accounting  policies.  Estimates  and 

judgements  are  continually  evaluated  and  are based  on  historical  experience  and  other  factors,  including  expectations  of  future 

events that are believed to be reasonable under the circumstances. 

Critical accounting estimates and assumptions 

The preparation of financial statements requires management to make estimates and assumptions that affect the reported amounts 

of assets and liabilities as well as the disclosure of contingent assets and liabilities at the balance sheet date and the reported amounts 

of  revenues  and  expenses  during  the  reporting  period.  Actual  outcomes  could  differ  from  those  estimates.  The  estimates  and 

assumptions that have a significant risk of causing a material adjustment to the carrying amounts of assets and liabilities within the 

next financial year are addressed below. 

Impairment assessment of non-financial assets  

The  Company  tests  annually  whether  goodwill  of  an  operating  segment  has  suffered  any  impairment,  in  accordance  with  the 

Company’s accounting policy. The recoverable amounts of the operating segments are determined based on the higher of VIU and 

FVLCD calculations that require the use of estimates. The Company also assesses whether there have been any events or changes in 

circumstances that indicate that property, plant and equipment and other intangible assets may be impaired and an impairment 

review is carried out whenever such an assessment indicates that the carrying amount may not be recoverable.  

In  the  impairment  analysis  of  the  Company’s  assets,  some  of  the  key  assumptions  used  in  estimating  future  cash  flows  include 

revenue  growth,  future  commodity  prices,  expected  margin,  expected  sales  volumes,  cost  structures  and  the  outlook  of  market 

supply and demand conditions appropriate to the local circumstances and macro-economic environment. These assumptions and 

estimates are uncertain and are subject to change as new information becomes available. Changes in economic conditions can also 

affect the rate used to discount future cash flow estimates.  

 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

which the unused tax losses can be utilized. To the extent that actual outcomes differ from management’s estimates, income tax 
charges or credits may arise in future periods. 

4  Changes in accounting policies and disclosures 

A.  Adoption of new accounting standards 

IFRS 16 – Leases (“IFRS 16”) is effective for years beginning on or after January 1, 2019, however the Company has elected to adopt 
IFRS 16 effective  January 1, 2018, concurrent with the adoption date of IFRS 9 – Financial Instruments  (“IFRS  9”), and IFRS 15  – 
Revenue from Contracts with Customers (“IFRS 15”). These standards have been applied using the modified retrospective approach. 
The  modified  retrospective  approach  does  not  require  restatement  of  prior  period  financial  information  as  it  recognizes  the 
cumulative effect as an adjustment to opening retained earnings and applies the standard prospectively. Accordingly, comparative 
information  in  the  Company’s  consolidated  balance  sheets,  consolidated  statements  of  operations,  consolidated  statements  of 
comprehensive income, consolidated statements of changes in equity and consolidated cash flow statements are not restated.  

        Changes in significant accounting policies from adoption of new accounting standards  

Policies  applicable  for  the  year  ending  December  31, 
2017 

Policies effective January 1, 2018 

Revenue Recognition 

Product revenues associated with the sales of products such 
as crude oil, diluent, natural gas liquids, road asphalt, roofing 
flux, wellsite fluids and distillate owned by the Company are 
recognized  when  the  risk  of  ownership  passes  to  the 
customer and physical delivery occurs, the price is fixed and 
collection  is  reasonably  assured.  Sales  terms  are  generally 
freight  on  board  (“FOB”)  shipping  point,  in  which  case  the 
sales  are  recorded  at  the  time  of  shipment,  because  this  is 
when  title  and  risk  of  loss  are  transferred.  All  payments 
received  before  delivery  are  recorded  as  deferred  revenue 
and  are  recognized  as  revenue  when  delivery  occurs, 
assuming  all  other  criteria  are  met.  Freight  costs  billed  to 
customers  are  recorded  as  a  component  of  revenue. 
Revenues from buy/sell transactions whereby the Company 
effectively is acting as an agent are recorded on a net basis. 

Revenue  associated  with  the  provision  of  services  such  as 
transportation, terminalling and environmental services are 
recognized when the services are provided, the price is fixed 
and collection is reasonably assured. Revenue from pipeline 
tariffs  and  fees  are  based  on  volumes  and  rates  as  the 
pipeline  is  being  used.  Long-term  take-or-pay  contracts, 
under  which  shippers  are  obligated  to  pay  fixed  amounts 
ratably  over  the  contract  period  regardless  of  volumes 
shipped,  may  contain  make-up  rights.  Make-up  rights  are 
earned by shippers when minimum volume commitments are 
not  utilized  during 
the  period  but  under  certain 
circumstances  can  be  used  to  offset  overages  in  future 
periods, subject to expiry periods. The Company recognizes 
revenues  associated  with  make-up  rights  at  the  earlier  of 
when  the  make-up  volume  is  shipped,  the  make-up  right 
expires or when it is determined that the likelihood that the 

Revenue  is  measured  based  on  the  consideration  specified  in  a 
contract with a customer and excludes amounts collected on behalf 
of third parties. The Company recognizes revenue when it transfers 
control of a product or service to a customer, at a point in time or 
over time. The Company does not have contracts where the period 
between  the  transfer  of  the  promised  goods  or  services  to  the 
customer and payments by the customer exceeds one year. As such, 
no  adjustments  are  made  to  the  transaction  prices  for  the  time 
value of money.  

Revenue  generated  through  the  provision  of  services  charged 
through 
long-term  fixed-fee  contracts  related  to  midstream 
infrastructure assets and includes a fixed and/or take or pay portion 
for the use of the midstream infrastructure and a variable portion 
related  to  the  servicing  of  volume  throughput.  The  Company 
accounts  for  individual  services  separately  if  they  are  distinct, 
indicated by the fact that they are separately identifiable from other 
services provided and the customer can benefit from these distinct 
services. The stand-alone prices on services are determined by the 
rates  listed  within  the  individual  contracts  related  to  the  service. 
The Company recognizes revenue over time as services are provided 
on a monthly basis, consistent with when the services are billed and 
paid.  Long-term  take-or-pay  contracts,  under  which  shippers  are 
obligated  to  pay  fixed  amounts  ratably  over  the  contract  period 
regardless  of  volumes  shipped,  may  contain  breakage  rights. 
Breakage amounts are earned by shippers when minimum volume 
commitments are not utilized during the period but under certain 
circumstances  can  be  used  to  offset  overages  in  future  periods, 
subject  to  expiry  periods.  The  Company  recognizes  revenues 
associated  with  breakage  at  the  earlier  of  when  the  breakage 
volume is shipped, the rights expires or when it is determined that 
the likelihood that the shipper will utilize the right is remote. 

Policies  applicable  for  the  year  ending  December  31, 

Policies effective January 1, 2018 

2017 

shipper will utilize the make-up right is remote. Revenue from 

Revenues generated from provision of transportation and related 

pipeline tariffs and fees are based on volumes and rates as 

services such as hauling services for crude, waste water and drilling 

the pipeline is being used. Revenue from equipment rentals 

fluids for many of North America’s leading oil and gas producers are 

and  non-refundable  propane  tank  fees  are  recorded  in 

typically  short-term  in  accordance  with  a  customer’s  current 

deferred revenue and are recognized in revenue on a straight 

hauling requirements. The Company accounts for individual hauling 

line basis over the rental period, typically one year. 

services  separately  if  they  are  distinct,  indicated  by  the  fact  that 

Excise  taxes  are  reported  gross  within  sales  and  other 

operating revenues and taxes other than income taxes, while 

other  sales  and  value-added  taxes  are  recorded  net  in 

operating expenses. 

they  are  separately 

identifiable  from  other  hauling  services 

provided and the customer can benefit from these distinct services. 

The  stand-alone  prices  on  services  are  determined  by  the  rates 

listed by the Company and are predetermined based on the volume 

of products serviced. The Company recognizes revenue over time as 

hauling and transportation services are provided and control of the 

service transfers to the customer, consistent with when the services 

are billed and paid. 

Revenues  generated  through  the  purchasing,  selling,  storing  and 

blending of hydrocarbon products, including crude oil, NGLs, road 

asphalt, roofing flux, frac oils, light and heavy straight run distillates, 

combined vacuum gas oil, and an oil based mud product, as well as 

by  providing  aggregation  services  to  producers  and/by  capturing 

quality, 

locational  or  time-based  arbitrage  opportunities  are 

typically short to long term in accordance with a customer’s current 

product demands which are generally grouped as spot sales where 

no commitment exists prior to the day of the transaction, term sales 

where  a  commitment  exists  over  a  period  of  time  for  negotiated 

sales,  and  evergreen  sales  where  contracts  are  automatically 

renewed  on  a  month  to  month  basis.  The  Company  accounts  for 

individual product sales separately if they are distinct, indicated by 

the fact that they are separately identifiable from other enforceable 

rights  and  obligations  and  the  customer  can  benefit  from  these 

distinct  services.  The  stand-alone  prices  on  product  sales  are 

determined  by  the  rates 

listed  within  market 

indexes  and 

benchmarks  and  usually 

include  quality  or 

transportation 

adjustments. The Company recognizes revenue at a point in time as 

products are delivered and control of the product has transferred 

to the customer, consistent with when the products are billed and 

paid.  All  payments  received  before  delivery  are  recorded  as  a 

contract  liability  and  are  recognized  as  revenue  when  delivery 

occurs, assuming all other criteria are met. Revenues from buy/sell 

transactions  which  are  monetary 

transactions 

containing 

commercial  substance  is  recognized  on  a  gross-basis  as  separate 

performance  obligation.  Revenues  from  buy/sell  transactions  of 

non-monetary  exchanges  of  similar  products,  which 

lack 

commercial substance, are recognized on a net basis. 

Excise  taxes  are  reported  gross  within  sales  and  other  operating 

revenues and taxes other than income taxes, while other sales and 

value-added taxes are recorded net in operating expenses. 

Consolidated Financial Statements 

16 

64 

Gibson Energy

17 

 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

charges or credits may arise in future periods. 

4  Changes in accounting policies and disclosures 

A.  Adoption of new accounting standards 

which the unused tax losses can be utilized. To the extent that actual outcomes differ from management’s estimates, income tax 

IFRS 16 – Leases (“IFRS 16”) is effective for years beginning on or after January 1, 2019, however the Company has elected to adopt 

IFRS 16 effective  January 1, 2018, concurrent with the adoption date of IFRS 9 – Financial Instruments  (“IFRS  9”), and IFRS 15  – 

Revenue from Contracts with Customers (“IFRS 15”). These standards have been applied using the modified retrospective approach. 

The  modified  retrospective  approach  does  not  require  restatement  of  prior  period  financial  information  as  it  recognizes  the 

cumulative effect as an adjustment to opening retained earnings and applies the standard prospectively. Accordingly, comparative 

information  in  the  Company’s  consolidated  balance  sheets,  consolidated  statements  of  operations,  consolidated  statements  of 

comprehensive income, consolidated statements of changes in equity and consolidated cash flow statements are not restated.  

        Changes in significant accounting policies from adoption of new accounting standards  

Policies  applicable  for  the  year  ending  December  31, 

Policies effective January 1, 2018 

2017 

Revenue Recognition 

Product revenues associated with the sales of products such 

Revenue  is  measured  based  on  the  consideration  specified  in  a 

as crude oil, diluent, natural gas liquids, road asphalt, roofing 

contract with a customer and excludes amounts collected on behalf 

flux, wellsite fluids and distillate owned by the Company are 

of third parties. The Company recognizes revenue when it transfers 

recognized  when  the  risk  of  ownership  passes  to  the 

control of a product or service to a customer, at a point in time or 

customer and physical delivery occurs, the price is fixed and 

over time. The Company does not have contracts where the period 

collection  is  reasonably  assured.  Sales  terms  are  generally 

between  the  transfer  of  the  promised  goods  or  services  to  the 

freight  on  board  (“FOB”)  shipping  point,  in  which  case  the 

customer and payments by the customer exceeds one year. As such, 

sales  are  recorded  at  the  time  of  shipment,  because  this  is 

no  adjustments  are  made  to  the  transaction  prices  for  the  time 

when  title  and  risk  of  loss  are  transferred.  All  payments 

value of money.  

received  before  delivery  are  recorded  as  deferred  revenue 

and  are  recognized  as  revenue  when  delivery  occurs, 

assuming  all  other  criteria  are  met.  Freight  costs  billed  to 

customers  are  recorded  as  a  component  of  revenue. 

Revenues from buy/sell transactions whereby the Company 

effectively is acting as an agent are recorded on a net basis. 

Revenue  generated  through  the  provision  of  services  charged 

through 

long-term  fixed-fee  contracts  related  to  midstream 

infrastructure assets and includes a fixed and/or take or pay portion 

for the use of the midstream infrastructure and a variable portion 

related  to  the  servicing  of  volume  throughput.  The  Company 

accounts  for  individual  services  separately  if  they  are  distinct, 

Revenue  associated  with  the  provision  of  services  such  as 

indicated by the fact that they are separately identifiable from other 

transportation, terminalling and environmental services are 

services provided and the customer can benefit from these distinct 

recognized when the services are provided, the price is fixed 

services. The stand-alone prices on services are determined by the 

and collection is reasonably assured. Revenue from pipeline 

rates  listed  within  the  individual  contracts  related  to  the  service. 

tariffs  and  fees  are  based  on  volumes  and  rates  as  the 

The Company recognizes revenue over time as services are provided 

pipeline  is  being  used.  Long-term  take-or-pay  contracts, 

on a monthly basis, consistent with when the services are billed and 

under  which  shippers  are  obligated  to  pay  fixed  amounts 

paid.  Long-term  take-or-pay  contracts,  under  which  shippers  are 

ratably  over  the  contract  period  regardless  of  volumes 

obligated  to  pay  fixed  amounts  ratably  over  the  contract  period 

shipped,  may  contain  make-up  rights.  Make-up  rights  are 

regardless  of  volumes  shipped,  may  contain  breakage  rights. 

earned by shippers when minimum volume commitments are 

Breakage amounts are earned by shippers when minimum volume 

not  utilized  during 

the  period  but  under  certain 

commitments are not utilized during the period but under certain 

circumstances  can  be  used  to  offset  overages  in  future 

circumstances  can  be  used  to  offset  overages  in  future  periods, 

periods, subject to expiry periods. The Company recognizes 

subject  to  expiry  periods.  The  Company  recognizes  revenues 

revenues  associated  with  make-up  rights  at  the  earlier  of 

associated  with  breakage  at  the  earlier  of  when  the  breakage 

when  the  make-up  volume  is  shipped,  the  make-up  right 

volume is shipped, the rights expires or when it is determined that 

expires or when it is determined that the likelihood that the 

the likelihood that the shipper will utilize the right is remote. 

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Policies  applicable  for  the  year  ending  December  31, 
2017 

shipper will utilize the make-up right is remote. Revenue from 
pipeline tariffs and fees are based on volumes and rates as 
the pipeline is being used. Revenue from equipment rentals 
and  non-refundable  propane  tank  fees  are  recorded  in 
deferred revenue and are recognized in revenue on a straight 
line basis over the rental period, typically one year. 

Excise  taxes  are  reported  gross  within  sales  and  other 
operating revenues and taxes other than income taxes, while 
other  sales  and  value-added  taxes  are  recorded  net  in 
operating expenses. 

Policies effective January 1, 2018 

Revenues generated from provision of transportation and related 
services such as hauling services for crude, waste water and drilling 
fluids for many of North America’s leading oil and gas producers are 
typically  short-term  in  accordance  with  a  customer’s  current 
hauling requirements. The Company accounts for individual hauling 
services  separately  if  they  are  distinct,  indicated  by  the  fact  that 
they  are  separately 
identifiable  from  other  hauling  services 
provided and the customer can benefit from these distinct services. 
The  stand-alone  prices  on  services  are  determined  by  the  rates 
listed by the Company and are predetermined based on the volume 
of products serviced. The Company recognizes revenue over time as 
hauling and transportation services are provided and control of the 
service transfers to the customer, consistent with when the services 
are billed and paid. 

Revenues  generated  through  the  purchasing,  selling,  storing  and 
blending of hydrocarbon products, including crude oil, NGLs, road 
asphalt, roofing flux, frac oils, light and heavy straight run distillates, 
combined vacuum gas oil, and an oil based mud product, as well as 
by  providing  aggregation  services  to  producers  and/by  capturing 
quality, 
locational  or  time-based  arbitrage  opportunities  are 
typically short to long term in accordance with a customer’s current 
product demands which are generally grouped as spot sales where 
no commitment exists prior to the day of the transaction, term sales 
where  a  commitment  exists  over  a  period  of  time  for  negotiated 
sales,  and  evergreen  sales  where  contracts  are  automatically 
renewed  on  a  month  to  month  basis.  The  Company  accounts  for 
individual product sales separately if they are distinct, indicated by 
the fact that they are separately identifiable from other enforceable 
rights  and  obligations  and  the  customer  can  benefit  from  these 
distinct  services.  The  stand-alone  prices  on  product  sales  are 
determined  by  the  rates 
indexes  and 
benchmarks  and  usually 
transportation 
adjustments. The Company recognizes revenue at a point in time as 
products are delivered and control of the product has transferred 
to the customer, consistent with when the products are billed and 
paid.  All  payments  received  before  delivery  are  recorded  as  a 
contract  liability  and  are  recognized  as  revenue  when  delivery 
occurs, assuming all other criteria are met. Revenues from buy/sell 
transactions  which  are  monetary 
containing 
commercial  substance  is  recognized  on  a  gross-basis  as  separate 
performance  obligation.  Revenues  from  buy/sell  transactions  of 
non-monetary  exchanges  of  similar  products,  which 
lack 
commercial substance, are recognized on a net basis. 

listed  within  market 
include  quality  or 

transactions 

16 

Gibson Energy 

17 
65 

Consolidated Financial Statements

Excise  taxes  are  reported  gross  within  sales  and  other  operating 
revenues and taxes other than income taxes, while other sales and 
value-added taxes are recorded net in operating expenses. 

 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Policies  applicable  for  the  year  ending  December  31, 
2017 

Leases 

Lessee 

A finance lease is a lease that transfers substantially all the 
risks  and  rewards  of  ownership  of  an  asset  to  the  lessee. 
Assets  acquired  under  finance  leases  are  recorded  in  the 
balance sheet as property, plant and equipment at the lower 
of their fair value and the present value of the minimum lease 
payments  and  depreciated  over  the  shorter  of  their 
estimated useful life or their lease terms. 

The  corresponding  rental  obligations  are  included  in  other 
long-term 
liabilities.  Interest 
incurred  on  finance  leases  is  charged  to  the  consolidated 
statements of operations on an accrual basis. 

liabilities  as  finance 

lease 

All other leases are operating leases, and the rental of these 
is  charged  to  the  consolidated  statements  of  operations  as 
incurred over the lease term. 

Policies effective January 1, 2018 

Policies applicable for the year ending as at December 

Policies effective January 1, 2018 

Lessee  

All  leases  are  accounted  for  as  finance  leases.  Finance  leases  are 
recognized as a right-of-use asset and corresponding liability at the 
date of which the leased asset is available for use by the Company. 
Each lease payment is allocated between the liability and finance 
cost. The finance cost is charged to the consolidated statements of 
operations over the lease term so as to produce a constant periodic 
rate  of  interest  on  the  remaining  balance  of  the  liability  for  each 
period. The right-of-use asset is depreciated over the shorter of the 
asset’s useful life and the lease term on a straight-line basis.  

The  Company  uses  a  single  discount  rate  for  a portfolio  of  leases 
with  reasonably  similar  characteristics.  Lease  payments  on  short 
term leases with lease terms of less than twelve months or leases 
on which the underlying asset is of low value are accounted for as 
expenses in the consolidated statements of operations. 

Assets and liabilities arising from a lease are initially measured on a 
present value basis. Lease liabilities include the net present value of 
fixed  payments  (including  in-substance  fixed  payments),  less  any 
lease incentives receivable, variable lease payments that are based 
on an index or a rate, amounts expected to be payable by the lessee 
under residual value guarantees, the exercise price of a purchase 
option if the lessee is reasonably certain to exercise that option, and 
payments of penalties for terminating the lease, if the lease term 
reflects the lessee exercising that option. These lease payments are 
discounted using the Company’s incremental borrowing rate where 
the rate implicit in the lease is not readily determinable.  

Right-of-use assets are measured at cost comprising of the amount 
of  the  initial  measurement  of  lease  liability,  any  lease  payments 
made at or before the commencement date, any initial direct costs, 
and restoration costs.  

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

31, 2017 

Financial assets 

Non-derivative financial instruments – recognition and measurement 

Financial assets include cash and cash equivalents and trade and other receivables. The Company determines the classification 

of its financial assets at initial recognition. Financial assets are recognized initially at fair value, normally being the transaction 

price plus directly attributable transaction costs. 

Loans and receivables are non-derivative financial assets with fixed or determinable payments that are not quoted in an active 

market. Such assets are carried at amortized cost using the effective interest method if the time value of money is significant. 

Gains and losses are recognized in the consolidated statements of operations when the loans and receivables are derecognized 

or impaired, as well as through the use of the effective interest method. This category of financial assets includes cash and cash 

equivalents and trade and other receivables. 

Cash and cash equivalents comprise cash on hand and short-term deposit, highly liquid investments that are readily convertible 

to known amounts of cash which are subject to insignificant risk of changes in value and maturity of three months or less from 

the date of acquisition. 

A  provision 

for 

impairment  of  trade  receivables 

is 

For trade receivables, the simplified approach is applied to the 

established  when  there  is  objective  evidence  that  the 

Company’s respective business units, which requires the use of 

Company  may  not  be  able  to  collect  all  amounts  due 

the lifetime expected loss provisions for expected credit losses. 

according to the original terms of the receivables. Significant 

To  measure  the  expected  credit  losses,  trade  receivables  are 

financial difficulties of the debtor, probability that the debtor 

grouped based on shared credit risk characteristics and the days 

will enter bankruptcy or financial reorganization, and default 

past due. The carrying amount of the asset is reduced through 

or delinquency in payments (more than 30 days past the due 

the use of an allowance account, and the amount of the loss is 

date)  are  considered  indicators  that  the  trade  receivable 

recognized in the consolidated statements of operations. When 

may  be  impaired.  The  amount  of  the  provision  is  the 

a  trade  receivable  is  uncollectible,  it  is  written  off  against  the 

difference  between  the  asset’s  carrying  amount  and  the 

allowance account for trade receivables. For lease receivables, 

present value of estimated future cash flows, discounted at 

the general approach is applied which requires the recognition 

the original effective interest rate. The carrying amount of 

of  twelve-month  expected  loss  provisions  for  expected  credit 

the  asset  is  reduced  through  the  use  of  an  allowance 

losses on lease receivables that have low credit risk at January 1, 

account,  and  the  amount  of  the  loss  is  recognized  in  the 

2018.  Where  such  lease  receivables  have  had  a  significant 

consolidated  statements  of  operations.  When  a  trade 

increase in credit risk since initial recognition but no objective 

receivable  is  uncollectible,  it  is  written  off  against  the 

evidence of impairment, lifetime expected loss provision is used 

allowance account for trade receivables. 

with  interest  calculated  on  the  gross  carrying  amount  of  the 

asset. Where objective evidence of impairment exists, interest is 

calculated on the carrying amount net of the impairment.   

Financial liabilities classified as other liabilities include amounts borrowed under credit facilities, trade payables and accrued 

charges, dividends payable, long-term debt and the convertible debentures. The Company determines the classification of its 

financial liabilities at initial recognition. All financial liabilities are initially recognized at fair value. For interest-bearing loans and 

borrowings  this  is  the  fair  value  of  the  proceeds  received  net  of  issue  costs  associated  with  the  borrowing.  After  initial 

recognition, financial liabilities are subsequently measured at amortized cost using the effective interest method. Amortized 

cost is calculated by taking into account any issue costs, and any discount or premium on settlement. Gains and losses arising 

on the repurchase, settlement or cancellation of liabilities are recognized in the consolidated statements of operations.  

Financial assets and liabilities are offset and the net amount reported in the balance sheet when there is a legally enforceable 

right to offset the recognised amounts and there is an intention to settle on a net basis or realise the asset and settle the liability 

simultaneously. 

Lessor 

Leases in contractual arrangements which transfer substantially all the risks and benefits of ownership of property to the lessee are 
accounted for as finance leases, while all other leases are accounted for as operating leases. 

Financial liabilities 

Finance leases are recorded  as a net investment in a finance lease.  The present  value  of minimum lease receivable under such 
arrangements are recorded as an investment in finance lease and the finance income is recognized in a manner that produces a 
consistent rate of return on the investment in the finance lease and is included in revenue. 

Operating lease income is recognized in the consolidated statements of operations as it is earned over the lease term. 

Consolidated Financial Statements 

18 

66 

Gibson Energy

19 

 
 
 
 
 
2017 

Leases 

Lessee 

Lessor 

A finance lease is a lease that transfers substantially all the 

All  leases  are  accounted  for  as  finance  leases.  Finance  leases  are 

risks  and  rewards  of  ownership  of  an  asset  to  the  lessee. 

recognized as a right-of-use asset and corresponding liability at the 

Assets  acquired  under  finance  leases  are  recorded  in  the 

date of which the leased asset is available for use by the Company. 

balance sheet as property, plant and equipment at the lower 

Each lease payment is allocated between the liability and finance 

of their fair value and the present value of the minimum lease 

cost. The finance cost is charged to the consolidated statements of 

payments  and  depreciated  over  the  shorter  of  their 

operations over the lease term so as to produce a constant periodic 

estimated useful life or their lease terms. 

The  corresponding  rental  obligations  are  included  in  other 

long-term 

liabilities  as  finance 

lease 

liabilities.  Interest 

rate  of  interest  on  the  remaining  balance  of  the  liability  for  each 

period. The right-of-use asset is depreciated over the shorter of the 

asset’s useful life and the lease term on a straight-line basis.  

incurred  on  finance  leases  is  charged  to  the  consolidated 

The  Company  uses  a  single  discount  rate  for  a portfolio  of  leases 

statements of operations on an accrual basis. 

All other leases are operating leases, and the rental of these 

is  charged  to  the  consolidated  statements  of  operations  as 

incurred over the lease term. 

with  reasonably  similar  characteristics.  Lease  payments  on  short 

term leases with lease terms of less than twelve months or leases 

on which the underlying asset is of low value are accounted for as 

expenses in the consolidated statements of operations. 

Assets and liabilities arising from a lease are initially measured on a 

present value basis. Lease liabilities include the net present value of 

fixed  payments  (including  in-substance  fixed  payments),  less  any 

lease incentives receivable, variable lease payments that are based 

on an index or a rate, amounts expected to be payable by the lessee 

under residual value guarantees, the exercise price of a purchase 

option if the lessee is reasonably certain to exercise that option, and 

payments of penalties for terminating the lease, if the lease term 

reflects the lessee exercising that option. These lease payments are 

discounted using the Company’s incremental borrowing rate where 

the rate implicit in the lease is not readily determinable.  

Right-of-use assets are measured at cost comprising of the amount 

of  the  initial  measurement  of  lease  liability,  any  lease  payments 

made at or before the commencement date, any initial direct costs, 

and restoration costs.  

accounted for as finance leases, while all other leases are accounted for as operating leases. 

Finance leases are recorded  as a net investment in a finance lease.  The present  value  of minimum lease receivable under such 

arrangements are recorded as an investment in finance lease and the finance income is recognized in a manner that produces a 

consistent rate of return on the investment in the finance lease and is included in revenue. 

Operating lease income is recognized in the consolidated statements of operations as it is earned over the lease term. 

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Policies  applicable  for  the  year  ending  December  31, 

Policies effective January 1, 2018 

Policies applicable for the year ending as at December 
31, 2017 

Policies effective January 1, 2018 

Non-derivative financial instruments – recognition and measurement 

Lessee  

Financial assets 

Financial assets include cash and cash equivalents and trade and other receivables. The Company determines the classification 
of its financial assets at initial recognition. Financial assets are recognized initially at fair value, normally being the transaction 
price plus directly attributable transaction costs. 

Loans and receivables are non-derivative financial assets with fixed or determinable payments that are not quoted in an active 
market. Such assets are carried at amortized cost using the effective interest method if the time value of money is significant. 
Gains and losses are recognized in the consolidated statements of operations when the loans and receivables are derecognized 
or impaired, as well as through the use of the effective interest method. This category of financial assets includes cash and cash 
equivalents and trade and other receivables. 

Cash and cash equivalents comprise cash on hand and short-term deposit, highly liquid investments that are readily convertible 
to known amounts of cash which are subject to insignificant risk of changes in value and maturity of three months or less from 
the date of acquisition. 

for 

impairment  of  trade  receivables 

is 
A  provision 
established  when  there  is  objective  evidence  that  the 
Company  may  not  be  able  to  collect  all  amounts  due 
according to the original terms of the receivables. Significant 
financial difficulties of the debtor, probability that the debtor 
will enter bankruptcy or financial reorganization, and default 
or delinquency in payments (more than 30 days past the due 
date)  are  considered  indicators  that  the  trade  receivable 
may  be  impaired.  The  amount  of  the  provision  is  the 
difference  between  the  asset’s  carrying  amount  and  the 
present value of estimated future cash flows, discounted at 
the original effective interest rate. The carrying amount of 
the  asset  is  reduced  through  the  use  of  an  allowance 
account,  and  the  amount  of  the  loss  is  recognized  in  the 
consolidated  statements  of  operations.  When  a  trade 
receivable  is  uncollectible,  it  is  written  off  against  the 
allowance account for trade receivables. 

For trade receivables, the simplified approach is applied to the 
Company’s respective business units, which requires the use of 
the lifetime expected loss provisions for expected credit losses. 
To  measure  the  expected  credit  losses,  trade  receivables  are 
grouped based on shared credit risk characteristics and the days 
past due. The carrying amount of the asset is reduced through 
the use of an allowance account, and the amount of the loss is 
recognized in the consolidated statements of operations. When 
a  trade  receivable  is  uncollectible,  it  is  written  off  against  the 
allowance account for trade receivables. For lease receivables, 
the general approach is applied which requires the recognition 
of  twelve-month  expected  loss  provisions  for  expected  credit 
losses on lease receivables that have low credit risk at January 1, 
2018.  Where  such  lease  receivables  have  had  a  significant 
increase in credit risk since initial recognition but no objective 
evidence of impairment, lifetime expected loss provision is used 
with  interest  calculated  on  the  gross  carrying  amount  of  the 
asset. Where objective evidence of impairment exists, interest is 
calculated on the carrying amount net of the impairment.   

Leases in contractual arrangements which transfer substantially all the risks and benefits of ownership of property to the lessee are 

Financial liabilities 

Financial liabilities classified as other liabilities include amounts borrowed under credit facilities, trade payables and accrued 
charges, dividends payable, long-term debt and the convertible debentures. The Company determines the classification of its 
financial liabilities at initial recognition. All financial liabilities are initially recognized at fair value. For interest-bearing loans and 
borrowings  this  is  the  fair  value  of  the  proceeds  received  net  of  issue  costs  associated  with  the  borrowing.  After  initial 
recognition, financial liabilities are subsequently measured at amortized cost using the effective interest method. Amortized 
cost is calculated by taking into account any issue costs, and any discount or premium on settlement. Gains and losses arising 
on the repurchase, settlement or cancellation of liabilities are recognized in the consolidated statements of operations.  

Financial assets and liabilities are offset and the net amount reported in the balance sheet when there is a legally enforceable 
right to offset the recognised amounts and there is an intention to settle on a net basis or realise the asset and settle the liability 
simultaneously. 

18 

Gibson Energy 

19 
67 

Consolidated Financial Statements

 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Policies applicable for the year ending as at December 
31, 2017 

Policies effective January 1, 2018 

Compound financial instruments 

Compound  financial  instruments  are  separated  into  liability  and  equity  components.  The  liability  component  is  recognized 
initially  at  the  fair  value  of  a  similar  liability  that  does  not  have  an  equity  conversion  option  and  the  equity  component  is 
recognized as the difference between the fair value of the compound financial instrument as a whole and the fair value of the 
liability component net of any deferred taxes. Any transaction costs are allocated to the liability and equity components in 
proportion to their initial carrying amounts. Subsequent to initial recognition, the liability component of the compound financial 
instrument is measured at amortized cost and is accreted to the original principal balance using the effective interest method. 
The equity component is not remeasured subsequent to initial recognition. The equity component and the accreted liability 
component  are  reclassified  to  share  capital  upon  conversion  and  any  balance  in  the  equity  component  of  the  compound 
financial instrument that remains after the settlement of the liability is transferred to contributed surplus. 

Derivative financial instruments – recognition and measurement 

Derivative financial instruments, used periodically by the Company to manage exposure to market risks relating to commodity 
prices, interest rates, share based compensation and foreign currency exchange rates, are not designated as hedges. They are 
recorded at fair value and recorded on the Company’s balance sheet as either an asset, when the fair value is positive, or a 
liability,  when  the  fair  value  is  negative.  Changes  in  fair  value  are  recorded  immediately  in  the  consolidated  statements  of 
operations. 

The impacts of the adoption of IFRS 9, 15 and 16, as at January 1, 2018 are as follows: 

Consolidated balance sheet adjustments 

As reported as 
at December 
31, 2017 

  $   494,901
    169,957
    (500,662)
-
-
(7,013)
-
-
   1,251,416
$ 1,408,599

  Adjustments 

Footnote 

 $     

  484
4,765
3,329
170,548
(12,676)
7,013
(43,490)
(129,344)
(629)
$                -

(i) 
(ii) 
(ii & iii) 
(iii) 
(ii) 
(ii) 
(iii) 
(iii) 
(i & ii) 

Restated 
balance as at 
January 1, 2018 

  $       495,385
    174,722
    (497,333)
170,548
(12,676)
-
(43,490)
(129,344)
   1,250,787
$    1,408,599

Trade and other receivables ...................................................... 
Inventories ................................................................................. 
Trade payables and accrued charges ......................................... 
Right-of-use assets ..................................................................... 
Contract liabilities ...................................................................... 
Deferred revenue ....................................................................... 
Lease liabilities – current portion ............................................... 
Lease liabilities – non-current portion ....................................... 
Retained deficit (earnings) ......................................................... 
Total  .......................................................................................... 

Footnotes 

(i)  Financial instruments 

The Company carries the following categories of financial assets subject to expected credit losses model under IFRS 9: 

Trade receivables 

 
  Net investments in finance leases 

The Company has revised its impairment methodology under IFRS 9 for the above noted classes of assets and applied the simplified 
approach on all trade receivables which requires the use of the lifetime expected loss provisions for expected credit losses. For lease 

receivables, the Company used the general approach which requires the recognition of twelve-month expected loss provisions for 

expected  credit  losses  on  lease  receivables  subject  to  credit  risk  as  at  January  1,  2018.  Where  such  lease  receivables  have  had  a 

significant increase in credit risk since initial recognition but no objective evidence of impairment, lifetime expected loss provisions 

are used with interest calculated on the gross carrying amount of the receivable balance. Where objective evidence of impairment 

exists, interest is calculated on the carrying amount, net of the impairment. At December 31, 2018, there were no material changes 

to the credit risk on lease receivables. 

There was no impact to the classification of the Company’s financial assets from the adoption of IFRS 9. 

In previous reporting periods, wholesale product revenues associated with the sales of roofing flux products owned by the Company 

were recognized at the time of shipment when the risk of ownership and loss are passed to the customer. Under IFRS 15, where the 

revenue contract provides a right to invoice prior to the physical delivery of the product, the Company will recognize a contract liability, 

until such time when the product has been physically delivered and the transfer of control has occurred.  

(ii) Revenue recognition 

(iii)  Leases 

On adoption of IFRS 16, the Company has recognised lease liabilities in relation to all lease arrangements measured at the present 

value of the remaining lease payments from commitments disclosed as at December 31, 2017, adjusted by commitments in relation 

to arrangements not containing leases (service agreements), short-term and low-value leases, and discounted using the Company’s 

incremental borrowing rate of 5% as of January 1, 2018:  

Operating lease commitments, disclosed as at December 31, 2017 ..............................  

Contracts re-assessed as service agreements .................................................................  

Net lease liabilities commitments ...................................................................................  

Discounted ......................................................................................................................  

Lease liabilities as at January 1, 2018 ..............................................................................  

  $ 

  $ 

223,723

(21,537)

202,186

(29,352)

172,834

The  associated  right-of-use  assets  were  measured  at  the  amount  equal  to  the  lease  liability  on  January  1,  2018,  adjusted  by  the 

amount of any prepaid or accrued lease payments relating to that lease recognised in the statement of financial position immediately 

before the date of transition, with no impact on retained earnings. 

There was no impact to lessor accounting from the adoption of IFRS 16. 

B.  Critical accounting estimates and judgements from adoption of new accounting standards  

Critical judgements in determining lease terms 

The Company uses hindsight in determining the lease term where a contract contains options to extend or terminate the lease. In 

determining  the  lease  term,  management  considers  all  facts  and  circumstances  that  create  an  economic  incentive  to  exercise  an 

extension option, or not exercise a termination option. The assessment is reviewed upon a trigger by a significant event or a significant 

change in circumstances.  

Impairment provision for financial assets 

The impairment provisions for financial assets are based on assumptions related to the risk of default and expected loss. The Company 

uses judgement in making these assumptions and selecting the inputs to the impairment calculation, based on the Company’s history, 

existing market conditions as well as forward looking estimates at the end of each reporting period.  

Consolidated Financial Statements 

20 

68 

Gibson Energy

21 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
   
 
 
   
 
 
 
   
 
   
 
   
   
 
   
 
   
 
 
   
   
 
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

receivables, the Company used the general approach which requires the recognition of twelve-month expected loss provisions for 
expected  credit  losses  on  lease  receivables  subject  to  credit  risk  as  at  January  1,  2018.  Where  such  lease  receivables  have  had  a 
significant increase in credit risk since initial recognition but no objective evidence of impairment, lifetime expected loss provisions 
are used with interest calculated on the gross carrying amount of the receivable balance. Where objective evidence of impairment 
exists, interest is calculated on the carrying amount, net of the impairment. At December 31, 2018, there were no material changes 
to the credit risk on lease receivables. 

There was no impact to the classification of the Company’s financial assets from the adoption of IFRS 9. 

(ii) Revenue recognition 

In previous reporting periods, wholesale product revenues associated with the sales of roofing flux products owned by the Company 
were recognized at the time of shipment when the risk of ownership and loss are passed to the customer. Under IFRS 15, where the 
revenue contract provides a right to invoice prior to the physical delivery of the product, the Company will recognize a contract liability, 
until such time when the product has been physically delivered and the transfer of control has occurred.  

Derivative financial instruments – recognition and measurement 

(iii)  Leases 

On adoption of IFRS 16, the Company has recognised lease liabilities in relation to all lease arrangements measured at the present 
value of the remaining lease payments from commitments disclosed as at December 31, 2017, adjusted by commitments in relation 
to arrangements not containing leases (service agreements), short-term and low-value leases, and discounted using the Company’s 
incremental borrowing rate of 5% as of January 1, 2018:  

Operating lease commitments, disclosed as at December 31, 2017 ..............................  
Contracts re-assessed as service agreements .................................................................  
Net lease liabilities commitments ...................................................................................  
Discounted ......................................................................................................................  
Lease liabilities as at January 1, 2018 ..............................................................................  

  $ 

  $ 

223,723
(21,537)
202,186
(29,352)
172,834

The  associated  right-of-use  assets  were  measured  at  the  amount  equal  to  the  lease  liability  on  January  1,  2018,  adjusted  by  the 
amount of any prepaid or accrued lease payments relating to that lease recognised in the statement of financial position immediately 
before the date of transition, with no impact on retained earnings. 

There was no impact to lessor accounting from the adoption of IFRS 16. 

B.  Critical accounting estimates and judgements from adoption of new accounting standards  

Critical judgements in determining lease terms 

The Company uses hindsight in determining the lease term where a contract contains options to extend or terminate the lease. In 
determining  the  lease  term,  management  considers  all  facts  and  circumstances  that  create  an  economic  incentive  to  exercise  an 
extension option, or not exercise a termination option. The assessment is reviewed upon a trigger by a significant event or a significant 
change in circumstances.  

Impairment provision for financial assets 

The impairment provisions for financial assets are based on assumptions related to the risk of default and expected loss. The Company 
uses judgement in making these assumptions and selecting the inputs to the impairment calculation, based on the Company’s history, 
existing market conditions as well as forward looking estimates at the end of each reporting period.  

20 

Gibson Energy 

21 
69 

Consolidated Financial Statements

Policies applicable for the year ending as at December 

Policies effective January 1, 2018 

31, 2017 

Compound financial instruments 

Compound  financial  instruments  are  separated  into  liability  and  equity  components.  The  liability  component  is  recognized 

initially  at  the  fair  value  of  a  similar  liability  that  does  not  have  an  equity  conversion  option  and  the  equity  component  is 

recognized as the difference between the fair value of the compound financial instrument as a whole and the fair value of the 

liability component net of any deferred taxes. Any transaction costs are allocated to the liability and equity components in 

proportion to their initial carrying amounts. Subsequent to initial recognition, the liability component of the compound financial 

instrument is measured at amortized cost and is accreted to the original principal balance using the effective interest method. 

The equity component is not remeasured subsequent to initial recognition. The equity component and the accreted liability 

component  are  reclassified  to  share  capital  upon  conversion  and  any  balance  in  the  equity  component  of  the  compound 

financial instrument that remains after the settlement of the liability is transferred to contributed surplus. 

Derivative financial instruments, used periodically by the Company to manage exposure to market risks relating to commodity 

prices, interest rates, share based compensation and foreign currency exchange rates, are not designated as hedges. They are 

recorded at fair value and recorded on the Company’s balance sheet as either an asset, when the fair value is positive, or a 

liability,  when  the  fair  value  is  negative.  Changes  in  fair  value  are  recorded  immediately  in  the  consolidated  statements  of 

operations. 

The impacts of the adoption of IFRS 9, 15 and 16, as at January 1, 2018 are as follows: 

Consolidated balance sheet adjustments 

31, 2017 

  Adjustments 

Footnote 

Trade and other receivables ...................................................... 

Inventories ................................................................................. 

Trade payables and accrued charges ......................................... 

Right-of-use assets ..................................................................... 

Contract liabilities ...................................................................... 

Deferred revenue ....................................................................... 

(7,013)

Lease liabilities – current portion ............................................... 

Lease liabilities – non-current portion ....................................... 

Retained deficit (earnings) ......................................................... 

Total  .......................................................................................... 

   1,251,416

$ 1,408,599

 $     

  484

4,765

3,329

170,548

(12,676)

7,013

(43,490)

(129,344)

(629)

$                -

(ii & iii) 

(i) 

(ii) 

(iii) 

(ii) 

(ii) 

(iii) 

(iii) 

(i & ii) 

As reported as 

at December 

  $   494,901

    169,957

    (500,662)

-

-

-

-

Restated 

balance as at 

January 1, 2018 

  $       495,385

    174,722

    (497,333)

170,548

(12,676)

-

(43,490)

(129,344)

   1,250,787

$    1,408,599

Footnotes 

(i)  Financial instruments 

 

Trade receivables 

  Net investments in finance leases 

The Company carries the following categories of financial assets subject to expected credit losses model under IFRS 9: 

The Company has revised its impairment methodology under IFRS 9 for the above noted classes of assets and applied the simplified 

approach on all trade receivables which requires the use of the lifetime expected loss provisions for expected credit losses. For lease 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
   
 
 
   
 
 
 
   
 
   
 
   
   
 
   
 
   
 
 
   
   
 
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Estimation uncertainty arising from variable lease payments  

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

5 

Trade and other receivables 

Certain leases contain variable payment terms that are linked to the Company’s owner operator costs within our Logistics segment. 
Judgment  is  applied  in  determination  of  whether  the  owner  operator  arrangement  contain  variable  payment  terms.  All  owner 
operator costs that are dependent upon the activity levels are classified as variable payments and all such costs are accounted for as 
a single lease component and charged to the consolidated statements of operations as incurred.    

C.  New interpretations and amended standards adopted by the Company  

The Company adopted the following new interpretations and revised standards, along with any consequential amendments. These 
changes were made in accordance with applicable transitional provisions. 

 

 

 

 

IFRS 2 – Share-based payments (“IFRS 2”), has been amended to address (i) certain issues related to the accounting for cash 
settled awards, and (ii) the accounting for equity settled awards that include a “net settlement” feature in respect of employee 
withholding taxes. IFRS 2 is effective for annual periods beginning on or after January 1, 2018. The adoption of this interpretation 
did not have a material impact on its consolidated financial statements. 

IFRIC 22 – Foreign currency transactions and advance consideration (“IFRIC 22”), provides guidance on how to determine the 
date  of  the  transaction  when  an  entity  either  pays  or  receives  consideration  in  advance  for  foreign  currency-denominated 
contracts. IFRIC 22 is effective for annual periods beginning on or after January 1, 2018. The adoption of this interpretation did 
not have a material impact on its consolidated financial statements. 

IAS  28  –  Investments  in  associates  and  joint  ventures  (“IAS  28”),  has  been  amended  to  clarify  that  an  entity  applies  IFRS  9, 
including its impairment requirements, to long-term interests in associate or joint venture to which the equity method is not 
applied. The amendment to IAS 28 is effective for years beginning on or after January 1, 2018. The Company has determined 
that the adoption of this interpretation did not have a material impact on its consolidated financial statements. 

The annual improvements process addresses issues in the 2014-2016 reporting cycles include changes to IFRS 1 – First time 
adoption  of  IFRS,  IFRS  7  –  Financial  instruments:  Disclosures,  IAS  19  –  Employee  benefits,  IFRS  10  –  Consolidated  financial 
statements and IAS 28 – Investment in associates and joint ventures. This improvement is effective for periods beginning on or 
after  January  1,  2018.  The  adoption  of  these  improvements  did  not  have  a  material  impact  on  the  consolidated  financial 
statements. 

D.  New standards and interpretations issued but not yet adopted  

The following accounting interpretations and standards were issued during the year: 

 

 

 

IAS 19 – Employee benefits (“IAS 19”), has been amended to (i) require current service cost and net interest for the period after 
the re-measurement to be determined using the assumptions used for the re-measurement, and (ii) clarify the effect of a plan 
amendment, curtailment or settlement on the requirements regarding the asset ceiling. The amendment to IAS 19 is effective 
for the years beginning on or after January 1, 2019. The Company is currently assessing the impact of this amendment.  

IFRS 3 – Business Combinations (“IFRS 3”), has been amended to revise the definition of a business to include an input and a 
substantive process that together significantly contribute to the ability to create outputs. The amendment to IFRS 3 is effective 
for the years beginning on or after January 1, 2020. The Company is currently assessing the impact of this amendment.  

IAS 1 – Presentation of financial statements (“IAS 1”) and IAS 8 – Accounting policies, changes in accounting estimates and errors 
(“IAS 8”), have been amended to (i) use a consistent definition of materiality throughout IFRSs and the Conceptual Framework 
for Financial Reporting; (ii) clarify the explanation of the definition of material; and iii) incorporate guidance in IAS 1 regarding 
immaterial information. The amendments to IAS 1 and IAS 8 are effective for the years beginning on or after January 1, 2020. 
The Company is currently assessing the impact of this amendment. 

Trade receivables ..............................................................................................................  

  $       271,799 

  $ 

480,084 

Allowance for doubtful accounts ......................................................................................  

Trade receivables, net .......................................................................................................  

Risk management assets (note 30) ...................................................................................  

Broker accounts receivable ...............................................................................................  

Indirect taxes receivable ...................................................................................................  

Other .................................................................................................................................  

Allowance for doubtful accounts 

 Opening balance ............................................................................................................... 

$ 

(931)   

$ 

(1,124) 

 Impact of change in accounting policy (note 4)................................................................ 

                     484 

                            - 

 Additional allowances ....................................................................................................... 

 Receivables written off as uncollectible ........................................................................... 

 Effect of changes in foreign exchange rates ..................................................................... 

 Closing balance ................................................................................................................. 

$ 

$ 

6 

Inventories 

Crude oil and diluent ......................................................................................................  

$  23,412   

$ 

Asphalt ............................................................................................................................  

Natural gas liquids ..........................................................................................................  

Wellsite fluids and distillate ............................................................................................  

Spare parts and other .....................................................................................................  

The cost of the inventory sold included in cost of sales was $5,656 million and $4,777 million for the year ended December 31, 2018 

and 2017, respectively.  

December 31, 

2018 

2017 

(133) 

271,666 

5,683 

4,194 

989 

1,284 

(931) 

479,153 

6,032 

4,441 

2,712 

2,563 

  $ 

 283,816 

  $ 

494,901 

Year ended 

December 31, 

2018 

2017 

(7,360) 

7,624 

50 

(133) 

17,450   

30,599   

14,168   

-   

December 31, 

2018 

(2,238) 

2,394 

37 

(931) 

2017 

79,223 

19,817 

44,087 

13,150 

13,680 

$ 

 85,629   

$  169,957 

Consolidated Financial Statements 

22 

70 

Gibson Energy

23 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Estimation uncertainty arising from variable lease payments  

Certain leases contain variable payment terms that are linked to the Company’s owner operator costs within our Logistics segment. 

Judgment  is  applied  in  determination  of  whether  the  owner  operator  arrangement  contain  variable  payment  terms.  All  owner 

operator costs that are dependent upon the activity levels are classified as variable payments and all such costs are accounted for as 

a single lease component and charged to the consolidated statements of operations as incurred.    

C.  New interpretations and amended standards adopted by the Company  

The Company adopted the following new interpretations and revised standards, along with any consequential amendments. These 

changes were made in accordance with applicable transitional provisions. 

IFRS 2 – Share-based payments (“IFRS 2”), has been amended to address (i) certain issues related to the accounting for cash 

settled awards, and (ii) the accounting for equity settled awards that include a “net settlement” feature in respect of employee 

withholding taxes. IFRS 2 is effective for annual periods beginning on or after January 1, 2018. The adoption of this interpretation 

did not have a material impact on its consolidated financial statements. 

IFRIC 22 – Foreign currency transactions and advance consideration (“IFRIC 22”), provides guidance on how to determine the 

date  of  the  transaction  when  an  entity  either  pays  or  receives  consideration  in  advance  for  foreign  currency-denominated 

contracts. IFRIC 22 is effective for annual periods beginning on or after January 1, 2018. The adoption of this interpretation did 

not have a material impact on its consolidated financial statements. 

IAS  28  –  Investments  in  associates  and  joint  ventures  (“IAS  28”),  has  been  amended  to  clarify  that  an  entity  applies  IFRS  9, 

including its impairment requirements, to long-term interests in associate or joint venture to which the equity method is not 

applied. The amendment to IAS 28 is effective for years beginning on or after January 1, 2018. The Company has determined 

that the adoption of this interpretation did not have a material impact on its consolidated financial statements. 

The annual improvements process addresses issues in the 2014-2016 reporting cycles include changes to IFRS 1 – First time 

adoption  of  IFRS,  IFRS  7  –  Financial  instruments:  Disclosures,  IAS  19  –  Employee  benefits,  IFRS  10  –  Consolidated  financial 

statements and IAS 28 – Investment in associates and joint ventures. This improvement is effective for periods beginning on or 

after  January  1,  2018.  The  adoption  of  these  improvements  did  not  have  a  material  impact  on  the  consolidated  financial 

statements. 

D.  New standards and interpretations issued but not yet adopted  

The following accounting interpretations and standards were issued during the year: 

IAS 19 – Employee benefits (“IAS 19”), has been amended to (i) require current service cost and net interest for the period after 

the re-measurement to be determined using the assumptions used for the re-measurement, and (ii) clarify the effect of a plan 

amendment, curtailment or settlement on the requirements regarding the asset ceiling. The amendment to IAS 19 is effective 

for the years beginning on or after January 1, 2019. The Company is currently assessing the impact of this amendment.  

IFRS 3 – Business Combinations (“IFRS 3”), has been amended to revise the definition of a business to include an input and a 

substantive process that together significantly contribute to the ability to create outputs. The amendment to IFRS 3 is effective 

for the years beginning on or after January 1, 2020. The Company is currently assessing the impact of this amendment.  

IAS 1 – Presentation of financial statements (“IAS 1”) and IAS 8 – Accounting policies, changes in accounting estimates and errors 

(“IAS 8”), have been amended to (i) use a consistent definition of materiality throughout IFRSs and the Conceptual Framework 

for Financial Reporting; (ii) clarify the explanation of the definition of material; and iii) incorporate guidance in IAS 1 regarding 

immaterial information. The amendments to IAS 1 and IAS 8 are effective for the years beginning on or after January 1, 2020. 

The Company is currently assessing the impact of this amendment. 

 

 

 

 

 

 

 

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

5 

Trade and other receivables 

Trade receivables ..............................................................................................................  
Allowance for doubtful accounts ......................................................................................  
Trade receivables, net .......................................................................................................  
Risk management assets (note 30) ...................................................................................  
Broker accounts receivable ...............................................................................................  
Indirect taxes receivable ...................................................................................................  
Other .................................................................................................................................  

Allowance for doubtful accounts 

December 31, 
2018 

  $       271,799 
(133) 
271,666 
5,683 
4,194 
989 
1,284 
 283,816 

  $ 

  $ 

  $ 

2017 

480,084 
(931) 
479,153 
6,032 
4,441 
2,712 
2,563 
494,901 

Year ended 
December 31, 
2018 

2017 

 Opening balance ............................................................................................................... 
 Impact of change in accounting policy (note 4)................................................................ 
 Additional allowances ....................................................................................................... 
 Receivables written off as uncollectible ........................................................................... 
 Effect of changes in foreign exchange rates ..................................................................... 
 Closing balance ................................................................................................................. 

$ 

(931)   

                     484 
(7,360) 
7,624 
50 
(133) 

$ 

6 

Inventories 

$ 

(1,124) 
                            - 
(2,238) 
2,394 
37 
(931) 

$ 

Crude oil and diluent ......................................................................................................  
Asphalt ............................................................................................................................  
Natural gas liquids ..........................................................................................................  
Wellsite fluids and distillate ............................................................................................  
Spare parts and other .....................................................................................................  

December 31, 
2018 

2017 

$  23,412   
17,450   
30,599   
14,168   
-   
 85,629   

$ 

$ 

79,223 
19,817 
44,087 
13,150 
13,680 
$  169,957 

The cost of the inventory sold included in cost of sales was $5,656 million and $4,777 million for the year ended December 31, 2018 
and 2017, respectively.  

22 

Gibson Energy 

23 
71 

Consolidated Financial Statements

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

7  Net investment in finance leases 

8  Assets and liabilities held for sale, discontinued operations and disposals 

The  following  summarizes  the  Company’s  net  investment  in  arrangements  whereby  the  Company  has  entered  into  fixed  term 
contractual arrangements to allow customers to have dedicated use of certain tanks owned by the Company. These arrangements 
are accounted for as finance leases: 

During the year ended December 31, 2018, the Company completed the assessment of various disposal groups that met the criteria 

under  IFRS  5  –  Non-Current  Assets  Held  for  Sale  and  Discontinued  Operations  (“IFRS  5”)  as  held  for  sale  and/or  discontinued 

operations. Noted below is a brief description of each disposal group. 

Total minimum lease payments receivable ....................................................................  
Residual value .................................................................................................................  
Unearned income ...........................................................................................................  

Less: current portion .......................................................................................................  
Net investment in finance lease: non-current portion ...................................................  

December 31, 
2018 

2017 

$   595,672    
57,073   
(497,383)  
155,362   
1,156   
$  154,206   

$  360,107 
44,944 
(285,203) 
119,848 
1,828 
$  118,020 

The minimum lease receivables are expected to be as follows: 

2019 ................................................................................................................................................................................  
2020 ................................................................................................................................................................................  
2021 ................................................................................................................................................................................  
2022 ................................................................................................................................................................................  
2023 ................................................................................................................................................................................  
2024 and later .................................................................................................................................................................  

  $  36,334 
36,563 
36,799 
35,161 
32,777 
$  418,038  

The following tables set forth the description of disposal groups classified as held for sale as at December 31, 2018: 

Disposal Group 

Canadian Truck 

U.S. Logistics and 

Non-Core Environmental Services 

Transportation (“TT Canada”) 

Infrastructure disposal group 

North (“ESN”) business 

business 

disposal groups.  

Met the high probability criteria of the sale of the business, including the active marketing of the 

Valuation of net 

Lower of carrying amount and FVLCD  

Fair value less cost of 

Market based model which is considered level 2 valuation 

Held for sale 

classification 

assets 

disposal (FVLCD) 

determination 

Discontinued 

operations 

determination 

Refer to “TT Canada” section 

This disposal group provides 

This business provides processing, 

below. 

truck transportation services in 

recovery and disposal services 

the U.S. and also includes a 

from a network of midstream 

Represent a separate major 

network of midstream 

infrastructure assets located 

line of business and classified 

infrastructure assets which are 

throughout Western Canada, 

as discontinued operations. 

included within the Company’s 

which are included within the 

Logistics and Infrastructure’s 

Company’s Infrastructure 

reportable segments.  

reportable segments.   

Does not represent a separate 

Does not represent a separate 

major line of business or 

geographical area of 

operations. 

major line of business or 

geographical area of operations. 

Assets and liabilities held for sale for all disposal groups as discussed above comprises of the following: 

       Trade and other receivables .........................................................................................  

               $        37,403 

       Inventories ....................................................................................................................  

       Property, plant and equipment (note 10) .....................................................................  

       Right-of-use assets (note 11) ........................................................................................  

       Other assets and prepaids ............................................................................................  

       Total assets held for sale ...............................................................................................  

$       209,438 

As at December 

31, 2018 

2,053 

159,540 

9,401 

1,041 

Assets 

Liabilities 

       Trade payables and accrued charges ............................................................................  

       Lease liability (note 16) .................................................................................................  

       Provisions (note 19) ......................................................................................................  

     Deferred income tax liability .........................................................................................  

$         20,778     

8,965 

21,641 

7,429 

       Total liabilities held for sale ..........................................................................................  

     $          58,813    

Consolidated Financial Statements 

24 

72 

Gibson Energy

25 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

7  Net investment in finance leases 

8  Assets and liabilities held for sale, discontinued operations and disposals 

The  following  summarizes  the  Company’s  net  investment  in  arrangements  whereby  the  Company  has  entered  into  fixed  term 

contractual arrangements to allow customers to have dedicated use of certain tanks owned by the Company. These arrangements 

are accounted for as finance leases: 

During the year ended December 31, 2018, the Company completed the assessment of various disposal groups that met the criteria 
under  IFRS  5  –  Non-Current  Assets  Held  for  Sale  and  Discontinued  Operations  (“IFRS  5”)  as  held  for  sale  and/or  discontinued 
operations. Noted below is a brief description of each disposal group. 

The following tables set forth the description of disposal groups classified as held for sale as at December 31, 2018: 

Total minimum lease payments receivable ....................................................................  

$   595,672    

$  360,107 

Disposal Group 

Residual value .................................................................................................................  

Unearned income ...........................................................................................................  

Less: current portion .......................................................................................................  

Net investment in finance lease: non-current portion ...................................................  

$  154,206   

$  118,020 

The minimum lease receivables are expected to be as follows: 

2019 ................................................................................................................................................................................  

  $  36,334 

2020 ................................................................................................................................................................................  

2021 ................................................................................................................................................................................  

2022 ................................................................................................................................................................................  

2023 ................................................................................................................................................................................  

36,563 

36,799 

35,161 

32,777 

2024 and later .................................................................................................................................................................  

$  418,038  

Held for sale 
classification 

Valuation of net 
assets 
Fair value less cost of 
disposal (FVLCD) 
determination 
Discontinued 
operations 
determination 

Canadian Truck 
Transportation (“TT Canada”) 
business 
Met the high probability criteria of the sale of the business, including the active marketing of the 
disposal groups.  

U.S. Logistics and 
Infrastructure disposal group 

Non-Core Environmental Services 
North (“ESN”) business 

Lower of carrying amount and FVLCD  

Market based model which is considered level 2 valuation 

Refer to “TT Canada” section 
below. 

Represent a separate major 
line of business and classified 
as discontinued operations. 

This disposal group provides 
truck transportation services in 
the U.S. and also includes a 
network of midstream 
infrastructure assets which are 
included within the Company’s 
Logistics and Infrastructure’s 
reportable segments.  

This business provides processing, 
recovery and disposal services 
from a network of midstream 
infrastructure assets located 
throughout Western Canada, 
which are included within the 
Company’s Infrastructure 
reportable segments.   

Does not represent a separate 
major line of business or 
geographical area of 
operations. 

Does not represent a separate 
major line of business or 
geographical area of operations. 

December 31, 

2018 

2017 

57,073   

(497,383)  

155,362   

1,156   

44,944 

(285,203) 

119,848 

1,828 

Assets and liabilities held for sale for all disposal groups as discussed above comprises of the following: 

Assets 
       Trade and other receivables .........................................................................................  
       Inventories ....................................................................................................................  
       Property, plant and equipment (note 10) .....................................................................  
       Right-of-use assets (note 11) ........................................................................................  
       Other assets and prepaids ............................................................................................  
       Total assets held for sale ...............................................................................................  

As at December 
31, 2018 

               $        37,403 
2,053 
159,540 
9,401 
1,041 
$       209,438 

Liabilities 
       Trade payables and accrued charges ............................................................................  
       Lease liability (note 16) .................................................................................................  
       Provisions (note 19) ......................................................................................................  
     Deferred income tax liability .........................................................................................  
       Total liabilities held for sale ..........................................................................................  

$         20,778     

8,965 
21,641 
7,429 

     $          58,813    

24 

Gibson Energy 

25 
73 

Consolidated Financial Statements

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

During the year ended December 31, 2018, the Company recorded impairment charges of $117.5 million relating to the disposal 
groups that are classified as held for sale or have been sold. 

U.S. Environmental Services business 

TT Canada 

During the year ended December 31, 2018, the Company met the criteria under IFRS 5 for its TT Canada business to be classified as 
discontinued operations. The TT Canada business provides hauling services for crude and other products for oil and gas producers and 
was reported historically within the Company’s Logistics reportable segment. Operating results related to these segments have been 
included in net income from discontinued operations in the consolidated statements of operations. Comparative period balances of 
the consolidated statements of operations and cash flows have been restated.  

The following tables set forth the operating results from discontinued operations for the year ended December 31, 2018 and 2017: 

Revenue – External and inter-segmental ................................................................  
Revenue – Inter-segmental .....................................................................................  
Revenue – External ..................................................................................................  
Cost of sales .............................................................................................................  
Gross loss .................................................................................................................  
Impairment of goodwill (note 14) ...........................................................................  
Finance cost and other (income), net .....................................................................  
(Loss) income before income taxes .........................................................................  
Income tax provision – current ...............................................................................  
Income tax recovery – deferred ..............................................................................  
Net (loss) income from discontinued operations, after tax ....................................  

Year ended 
December 31, 

2018 

2017 

$      217,408        
(26,765) 
190,643 
212,635 
(21,992) 
19,988 
(981) 
(40,999) 
3,410 
(14,822) 
$    (29,587) 

$       236,340 
               (31,981) 
               204,359 
       205,117 
         (758) 
- 
         (1,840) 
              1,082 
         1,797 
            (1,510) 
$             795 

During the year ended December 31, 2018, the Company met the criteria under IFRS 5 for its U.S. Environmental Services business to 

be classified as discontinued operations. This business was sold on May 3, 2018 for adjusted gross proceeds of $123.3 million (U.S.$96 

million) which resulted in recognition of an after-tax gain as follows:   

Sale price ...................................................................................................................................  

$  123,619 

Sale price adjustments ..............................................................................................................  

Total cash consideration ...........................................................................................................  

       Cash and cash equivalents ..................................................................................................                            1,127 

       Trade and other receivables ...............................................................................................  

       Inventories ..........................................................................................................................  

       Prepaid and other assets  ....................................................................................................  

       Property, plant and equipment (note 10) ...........................................................................  

       Right-of-use asset (note 11) ................................................................................................  

       Intangible assets .................................................................................................................  

       Deferred income tax asset ..................................................................................................  

       Other non-current assets ....................................................................................................  

       Trade payables and accrued charges ..................................................................................  

       Other current liabilities .......................................................................................................  

       Lease liabilities (note 16) ....................................................................................................  

       Provisions ............................................................................................................................  

Net assets disposed ...................................................................................................................  

Costs to sell ...............................................................................................................................  

Loss on sale before income taxes and reclassification of foreign currency translation gain ....  

Reclassification of foreign currency translation gain on disposal of foreign operations ..........  

Income tax provision – deferred ...............................................................................................  

(278) 

123,341 

50,225 

12,756 

1,999 

85,245 

19,679 

1,261 

22,945 

247 

(16,478) 

(2,431) 

(19,217) 

(17,309) 

140,049 

(13,634) 

(30,342) 

141,933 

16,069 

After-tax gain on sale ................................................................................................................  

$      95,522 

The U.S. Environmental Services business included the provision of environmental and production services, such as emulsion hauling 

and treating, water hauling and disposal services and oilfield waste management, as well as industrial lift, exploration support services 

and accommodation facilities. It was reported historically within Company’s Infrastructure, Logistics and Other reportable segments. 

Comparative period balances of the consolidated statements of operations and cash flows have been restated.  

The following tables set forth the operating results from discontinued operations for the year ended December 31, 2018 and 2017: 

Revenue ...................................................................................................................  

Cost of sales .............................................................................................................  

Gross profit (loss) ....................................................................................................  

Finance cost and other (income), net .....................................................................  

Income (loss) before income taxes .........................................................................  

Income tax recovery – current ................................................................................  

Income tax provision (recovery) – deferred ............................................................  

Net income (loss) from discontinued operations, after tax ....................................  

After-tax gain on sale ..............................................................................................  

Year ended 

December 31, 

2018 

2017 

$          93,281  

    $         236,834 

          86,481 

            6,800 

            1,364 

            5,436 

                  - 

            1,448 

            3,988 

          95,522 

       296,516 

       (59,682) 

            (1,247) 

       (58,435) 

              (41) 

         (8,210) 

       (50,184) 

                   - 

Gain (loss) from discontinued operations, after tax ...............................................  

      $          99,510  

     $        (50,184)     

Consolidated Financial Statements 

26 

74 

Gibson Energy

27 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

groups that are classified as held for sale or have been sold. 

TT Canada 

During the year ended December 31, 2018, the Company recorded impairment charges of $117.5 million relating to the disposal 

U.S. Environmental Services business 

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

During the year ended December 31, 2018, the Company met the criteria under IFRS 5 for its U.S. Environmental Services business to 
be classified as discontinued operations. This business was sold on May 3, 2018 for adjusted gross proceeds of $123.3 million (U.S.$96 
million) which resulted in recognition of an after-tax gain as follows:   

During the year ended December 31, 2018, the Company met the criteria under IFRS 5 for its TT Canada business to be classified as 

discontinued operations. The TT Canada business provides hauling services for crude and other products for oil and gas producers and 

was reported historically within the Company’s Logistics reportable segment. Operating results related to these segments have been 

included in net income from discontinued operations in the consolidated statements of operations. Comparative period balances of 

the consolidated statements of operations and cash flows have been restated.  

The following tables set forth the operating results from discontinued operations for the year ended December 31, 2018 and 2017: 

Revenue – External and inter-segmental ................................................................  

$      217,408        

$       236,340 

Revenue – Inter-segmental .....................................................................................  

Revenue – External ..................................................................................................  

Cost of sales .............................................................................................................  

Gross loss .................................................................................................................  

Impairment of goodwill (note 14) ...........................................................................  

Finance cost and other (income), net .....................................................................  

(Loss) income before income taxes .........................................................................  

Income tax provision – current ...............................................................................  

Income tax recovery – deferred ..............................................................................  

Net (loss) income from discontinued operations, after tax ....................................  

$    (29,587) 

Year ended 

December 31, 

2018 

2017 

(26,765) 

190,643 

212,635 

(21,992) 

19,988 

(981) 

(40,999) 

3,410 

(14,822) 

               (31,981) 

               204,359 

       205,117 

         (758) 

- 

         (1,840) 

              1,082 

         1,797 

            (1,510) 

$             795 

Sale price ...................................................................................................................................  
$  123,619 
Sale price adjustments ..............................................................................................................  
(278) 
123,341 
Total cash consideration ...........................................................................................................  
       Cash and cash equivalents ..................................................................................................                            1,127 
50,225 
       Trade and other receivables ...............................................................................................  
12,756 
       Inventories ..........................................................................................................................  
1,999 
       Prepaid and other assets  ....................................................................................................  
85,245 
       Property, plant and equipment (note 10) ...........................................................................  
19,679 
       Right-of-use asset (note 11) ................................................................................................  
1,261 
       Intangible assets .................................................................................................................  
22,945 
       Deferred income tax asset ..................................................................................................  
       Other non-current assets ....................................................................................................  
247 
(16,478) 
       Trade payables and accrued charges ..................................................................................  
(2,431) 
       Other current liabilities .......................................................................................................  
(19,217) 
       Lease liabilities (note 16) ....................................................................................................  
(17,309) 
       Provisions ............................................................................................................................  
140,049 
Net assets disposed ...................................................................................................................  
(13,634) 
Costs to sell ...............................................................................................................................  
Loss on sale before income taxes and reclassification of foreign currency translation gain ....  
(30,342) 
Reclassification of foreign currency translation gain on disposal of foreign operations ..........  
141,933 
16,069 
Income tax provision – deferred ...............................................................................................  
$      95,522 
After-tax gain on sale ................................................................................................................  

The U.S. Environmental Services business included the provision of environmental and production services, such as emulsion hauling 
and treating, water hauling and disposal services and oilfield waste management, as well as industrial lift, exploration support services 
and accommodation facilities. It was reported historically within Company’s Infrastructure, Logistics and Other reportable segments. 
Comparative period balances of the consolidated statements of operations and cash flows have been restated.  

The following tables set forth the operating results from discontinued operations for the year ended December 31, 2018 and 2017: 

Revenue ...................................................................................................................  
Cost of sales .............................................................................................................  
Gross profit (loss) ....................................................................................................  
Finance cost and other (income), net .....................................................................  
Income (loss) before income taxes .........................................................................  
Income tax recovery – current ................................................................................  
Income tax provision (recovery) – deferred ............................................................  
Net income (loss) from discontinued operations, after tax ....................................  
After-tax gain on sale ..............................................................................................  
Gain (loss) from discontinued operations, after tax ...............................................  

Year ended 
December 31, 

2018 
$          93,281  
          86,481 
            6,800 
            1,364 
            5,436 
                  - 
            1,448 
            3,988 
          95,522 
      $          99,510  

2017 
    $         236,834 
       296,516 
       (59,682) 
            (1,247) 
       (58,435) 
              (41) 
         (8,210) 
       (50,184) 
                   - 

     $        (50,184)     

26 

Gibson Energy 

27 
75 

Consolidated Financial Statements

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Wholesale Propane business 

During the year ended December 31, 2018, the Company met the criteria under IFRS 5 for its Wholesale Propane  business to be 
classified as held for sale. The Wholesale Propane business was engaged in the purchasing, selling, storing and blending of propane 
products and was reported historically within the Company’s Canadian and U.S. Wholesale operating segments. The business did not 
represent a major line of business or geographical operations, therefore the results for the period up to the sale has been included 
within continuing operations. On December 3, 2018, the Company completed the sale of the Wholesale Propane business for gross 
proceeds of $42.8 million, subject to purchase price adjustments, which resulted in recognition of a loss of $5.0 million included within 
other operating income in the consolidated statements of operations. Major net assets disposed consists of inventory of $13.0 million, 
property, plant and equipment of $10.6 million, right-of-use assets of $18.2 million, deferred income taxes of $8.1 million, goodwill 
of $13.4 million and finance lease liabilities of $16.2 million.  

Industrial Propane 

During the first quarter of 2017, the Company sold its Industrial Propane segment for cash proceeds of $433.1 million as disclosed in 
note 8 of the Company’s annual consolidated financial statements for the year ended December 31, 2017. The following tables set 
forth operating results from discontinued operations: 

       Revenue  .......................................................................................................................................  
       Cost of sales  .................................................................................................................................  
       Gross profit  ..................................................................................................................................  
       Other operating income ...............................................................................................................  
       Income before income taxes ........................................................................................................  
       Income tax provision – current ....................................................................................................  
       Income tax provision – deferred  .................................................................................................  
       Net income from discontinued operations, after tax ...................................................................  
       After-tax gain on sale ...................................................................................................................  
       Gain from discontinued operations, after tax ..............................................................................  

Year ended 
December 31, 2017 1 

$                  58,296 
44,678 
13,618 
(19) 
13,637 
4,161 
275 
9,201 
150,649 
$                159,850 

1.  The Company derecognized the Industrial Propane segment effective March 1, 2017, accordingly, results for year ended December 31, 2017 

represent the activity for the period January 1, 2017 to February 28, 2017. 

exchange rates ........................ 

201 

486 

8,554 

6,649 

9  Business combination 

On August 8, 2018, the Company acquired certain assets comprising of pipeline and gathering system for total consideration of $72 
million (U.S.$55 million). The purchase price is payable in two installments, with U.S.$25 million paid on August 8, 2018 and U.S.$30 
million payable by August 8, 2019. Acquisition costs of $0.1 million were incurred and charged to general and administrative expenses 
during the year ended December 31, 2018.  

The following table summarizes the fair value of assets acquired and liabilities assumed at the acquisition date: 

       Fair value 
       Property, Plant and Equipment .......................................................................................................  
       Intangible assets (1) ..........................................................................................................................  
       Provisions ........................................................................................................................................  
       Goodwill (2) .......................................................................................................................................  
       Net assets acquired .........................................................................................................................  

$                   20,038 
19,594 
(444) 
32,656 
$                   71,844 

(1) Consists of customer relationships attributed to a long-term customer contract. 
(2) The goodwill arising on this acquisition is expected to be deductible for income tax purposes.  

Consolidated Financial Statements 

28 

76 

Gibson Energy

29 

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

The goodwill arising from the acquisition was attributable to the expected synergies with the Company’s existing Pyote gathering 

system in the U.S. The goodwill for this acquisition was allocated to the Infrastructure reporting segment.  

Land & 

Pipelines and 

Buildings 

Connections 

Tanks 

Rolling 

Equipment & 

Stock 

Disposal wells 

Work in 

Progress 

Total 

Plant, 

At January 1, 2018 ......................    $ 189,090    $  225,679 

  $ 642,137    $  411,694    $  937,378 

  $ 185,739   $ 2,591,717 

2,296 

(1,477) 

3,194 

(3,112) 

8,348 

(72,897) 

13,074 

(37,307) 

224,816 

257,508 

(114,793) 

Reclassifications.......................... 

3,419 

59,696 

(149,101) 

5,780 

- 

19,097 

53,722 

- 

32,264 

1,761 

8,898 

- 

(36,389) 

- 

- 

- 

- 

- 

- 

- 

941 

3,386 

- 

10  Property, plant and equipment  

Cost: 

Additions .................................... 

Disposals ..................................... 

Acquisitions through business 

combinations (note 9) ............. 

Change in decommissioning 

provision (note 19) .................. 

Reclassed to net investment in 

finance leases (note 7) ............ 

Effect of movements in 

Transferred to held for sale and 

exchange rates ........................ 

1,067 

1,058 

1,124 

11,493 

9,406 

17 

24,165 

disposals (note 8) .................... 

(102,998) 

(7,868) 

(41,104) 

(293,869) 

(318,416) 

(4,565) 

(768,820) 

At December 31, 2018 ................     $   91,397   $  299,229 

  $ 607,012    $  64,769    $  668,158 

  $ 256,906   $ 1,987,471 

At January 1, 2018 ......................      $  37,865   $ 

  $ 121,173    $  286,181    $  444,618 

  $ 

-    $  972,029 

Accumulated depreciation and 

impairment: 

Depreciation ............................... 

Impairment ................................. 

Disposals ..................................... 

Effect of movements in 

5,494 

9,261 

(1,702) 

Transferred to held for sale and 

82,192 

10,485 

2,000 

(1) 

4 

23,083 

8,082 

16,186 

31,707 

53,640 

25,115 

(1,290) 

(59,976) 

(33,358) 

disposals (note 8) .................... 

(32,040) 

(4,239) 

(20,933) 

(238,320) 

(217,857) 

(513,389) 

At December 31, 2018 ................     $   19,079   $ 

90,441 

  $ 130,601    $  44,332    $  278,807 

  $ 

-    $  563,260 

Carrying amounts: 

At January 1, 2018 ......................     $ 151,225    $  143,487  

   $ 520,964    $  125,513    $   492,760  

  $  185,739   $  1,619,688 

At December 31, 2018 ................ 

$  72,318   $   208,788      $ 476,411  $    20,437    $   389,351 

$  256,906    $  1,424,211 

- 

- 

- 

- 

- 

- 

- 

- 

- 

20,038 

- 

14,045 

(36,389) 

108,888 

76,165 

(96,327) 

15,894 

 
 
 
 
 
 
 
 
 
 
 
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Wholesale Propane business 

During the year ended December 31, 2018, the Company met the criteria under IFRS 5 for its Wholesale Propane  business to be 

products and was reported historically within the Company’s Canadian and U.S. Wholesale operating segments. The business did not 

represent a major line of business or geographical operations, therefore the results for the period up to the sale has been included 

within continuing operations. On December 3, 2018, the Company completed the sale of the Wholesale Propane business for gross 

proceeds of $42.8 million, subject to purchase price adjustments, which resulted in recognition of a loss of $5.0 million included within 

other operating income in the consolidated statements of operations. Major net assets disposed consists of inventory of $13.0 million, 

property, plant and equipment of $10.6 million, right-of-use assets of $18.2 million, deferred income taxes of $8.1 million, goodwill 

of $13.4 million and finance lease liabilities of $16.2 million.  

Industrial Propane 

During the first quarter of 2017, the Company sold its Industrial Propane segment for cash proceeds of $433.1 million as disclosed in 

note 8 of the Company’s annual consolidated financial statements for the year ended December 31, 2017. The following tables set 

forth operating results from discontinued operations: 

       Revenue  .......................................................................................................................................  

$                  58,296 

       Cost of sales  .................................................................................................................................  

       Gross profit  ..................................................................................................................................  

       Other operating income ...............................................................................................................  

       Income before income taxes ........................................................................................................  

       Income tax provision – current ....................................................................................................  

       Income tax provision – deferred  .................................................................................................  

       Net income from discontinued operations, after tax ...................................................................  

       After-tax gain on sale ...................................................................................................................  

Year ended 

December 31, 2017 1 

44,678 

13,618 

(19) 

13,637 

4,161 

275 

9,201 

150,649 

       Gain from discontinued operations, after tax ..............................................................................  

$                159,850 

1.  The Company derecognized the Industrial Propane segment effective March 1, 2017, accordingly, results for year ended December 31, 2017 

represent the activity for the period January 1, 2017 to February 28, 2017. 

9  Business combination 

On August 8, 2018, the Company acquired certain assets comprising of pipeline and gathering system for total consideration of $72 

million (U.S.$55 million). The purchase price is payable in two installments, with U.S.$25 million paid on August 8, 2018 and U.S.$30 

million payable by August 8, 2019. Acquisition costs of $0.1 million were incurred and charged to general and administrative expenses 

during the year ended December 31, 2018.  

The following table summarizes the fair value of assets acquired and liabilities assumed at the acquisition date: 

       Fair value 

       Property, Plant and Equipment .......................................................................................................  

$                   20,038 

       Intangible assets (1) ..........................................................................................................................  

       Provisions ........................................................................................................................................  

       Goodwill (2) .......................................................................................................................................  

19,594 

(444) 

32,656 

       Net assets acquired .........................................................................................................................  

$                   71,844 

(1) Consists of customer relationships attributed to a long-term customer contract. 

(2) The goodwill arising on this acquisition is expected to be deductible for income tax purposes.  

classified as held for sale. The Wholesale Propane business was engaged in the purchasing, selling, storing and blending of propane 

10  Property, plant and equipment  

Land & 
Buildings 

Pipelines and 
Connections 

Tanks 

Rolling 
Stock 

Plant, 
Equipment & 
Disposal wells 

Work in 
Progress 

Total 

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

The goodwill arising from the acquisition was attributable to the expected synergies with the Company’s existing Pyote gathering 
system in the U.S. The goodwill for this acquisition was allocated to the Infrastructure reporting segment.  

Cost: 
At January 1, 2018 ......................    $ 189,090    $  225,679 
5,780 
Additions .................................... 
- 
Disposals ..................................... 
Acquisitions through business 

2,296 
(1,477) 

  $ 642,137    $  411,694    $  937,378 
13,074 
(37,307) 

8,348 
(72,897) 

3,194 
(3,112) 

  $ 185,739   $ 2,591,717 
257,508 
(114,793) 

224,816 
- 

combinations (note 9) ............. 
Reclassifications.......................... 
Change in decommissioning 

provision (note 19) .................. 

Reclassed to net investment in 

finance leases (note 7) ............ 

Effect of movements in 

exchange rates ........................ 
Transferred to held for sale and 
disposals (note 8) .................... 

- 
3,419 

19,097 
53,722 

- 
32,264 

- 

- 

1,761 

8,898 

- 

(36,389) 

- 
- 

- 

- 

941 
59,696 

- 
(149,101) 

3,386 

- 

- 

- 

20,038 
- 

14,045 

(36,389) 

1,067 

1,058 

1,124 

11,493 

9,406 

17 

24,165 

(7,868) 
At December 31, 2018 ................     $   91,397   $  299,229 

(102,998) 

(41,104) 

(318,416) 
  $ 607,012    $  64,769    $  668,158 

(293,869) 

Accumulated depreciation and 

impairment: 

At January 1, 2018 ......................      $  37,865   $ 
Depreciation ............................... 
Impairment ................................. 
Disposals ..................................... 
Effect of movements in 

5,494 
9,261 
(1,702) 

82,192 
10,485 
2,000 
(1) 

  $ 121,173    $  286,181    $  444,618 
53,640 
25,115 
(33,358) 

16,186 
31,707 
(59,976) 

23,083 
8,082 
(1,290) 

(4,565) 

(768,820) 
  $ 256,906   $ 1,987,471 

  $ 

-    $  972,029 
108,888 
- 
76,165 
- 
(96,327) 
- 

201 

4 

486 

8,554 

6,649 

- 

15,894 

At December 31, 2018 ................     $   19,079   $ 

(32,040) 

(4,239) 
90,441 

(20,933) 

(217,857) 
  $ 130,601    $  44,332    $  278,807 

(238,320) 

  $ 

- 
(513,389) 
-    $  563,260 

exchange rates ........................ 
Transferred to held for sale and 
disposals (note 8) .................... 

Carrying amounts: 
At January 1, 2018 ......................     $ 151,225    $  143,487  
At December 31, 2018 ................ 

   $ 520,964    $  125,513    $   492,760  
$  72,318   $   208,788      $ 476,411  $    20,437    $   389,351 

  $  185,739   $  1,619,688 
$  256,906    $  1,424,211 

28 

Gibson Energy 

29 
77 

Consolidated Financial Statements

 
 
 
 
 
 
 
 
 
 
 
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Land & 
Buildings 

Pipelines and 
Connections 

Tanks 

Rolling  
Stock 

Plant, 
Equipment 
& Disposal 
wells 

Cost: 
At January 1, 2017 ......................    $ 188,380    $  209,454 
5,177 
Additions .................................... 
- 
Disposals ..................................... 
Change in decommissioning 

2,204 
(4,640) 

  $ 608,344    $  457,871    $  920,843 
16,696 
(11,283) 

4,317 
(34,475) 

7,579 
(1,523) 

Work in 
Progress 

Total 

  $ 104,868    $ 2,489,760 
178,849 
(51,921) 

142,876 
- 

11  Right-of-use assets  

Cost: 

provision (note 19) .................. 
Reclassifications.......................... 
Effect of movements in 

- 
5,080 

2,151 
8,897 

3,956 
24,805 

- 
- 

4,606 
23,058 

- 
(61,840) 

10,713 
- 

exchange rates ........................ 

- 
At December 31, 2017 ................    $ 189,090    $  225,679 

(1,934) 

Accumulated depreciation and 

impairment: 

At January 1, 2017 ......................    $  31,778    $ 
Depreciation ............................... 
Impairment  ................................ 
Disposals ..................................... 
Effect of movements in 

6,663 
- 
(287) 

exchange rates ........................ 

(289) 

At December 31, 2017 ................    $  37,865    $ 

73,052 
9,140 
- 
- 

- 
82,192 

(1,024) 

(16,542) 
  $ 642,137    $  411,694    $  937,378 

(16,019) 

  $  96,609    $  275,002    $  370,025 
78,328 
17,089 
(11,143) 

42,511 
12,143 
(32,554) 

26,428 
- 
(1,408) 

(456) 

(9,681) 
  $121,173     $  286,181    $  444,618 

(10,921) 

(165) 

(35,684) 
  $ 185,739   $ 2,591,717 

  $ 

  $ 

-    $  846,466 
163,070 
- 
29,232 
- 
(45,392) 
- 

- 
(21,347) 
-    $  972,029 

Carrying amounts: 
At January 1, 2017 ......................    $ 156,602    $   136,402 
At December 31, 2017 ................  $ 151,225   $   143,487  

  $  511,735   $  182,869    $  550,818 
$  520,964  $  125,513  $  492,760  

  $ 104,868 

  $1,643,294 
$ 185,739   $1,619,688 

Additions to property, plant and equipment include capitalization of interest of $8.4  million and $4.7  million for the year ended 
December 31, 2018 and 2017, respectively. 

Property, plant and equipment are reviewed for impairment whenever events or conditions indicate that their net carrying amount 
may not be recoverable. During the year ended December 31, 2018, the Company recorded an impairment loss of $76.2 million, of 
which $74.7 million relates to assets held for sale relating to assets in the TT Canada business, Wholesale Propane business, non-core 
ESN business, Injection Stations, which are included within the Logistics and Infrastructure reportable segments (note 8), and $1.5 
million  included  within  the  cost  of  sales  in  the  statements  of  operations  related  to  the  U.S.  Truck  and  Transportation  business 
included within the Logistics reportable segment. Key assumptions used in the determination of the recoverable amounts include 
reference to management’s assessment of the expected proceeds to be received upon sale, as well as the depreciable replacement 
cost values where applicable.   

During the year ended December 31, 2017, the Company recorded an impairment loss of $29.2 million. The impairment loss related 
to assets within the U.S. Environmental Services business which was included within the Company's discontinued operations in cost 
of sales (note 8).  

Amounts in relation to tanks are under operating lease arrangements.  

Consolidated Financial Statements 

30 

78 

Gibson Energy

31 

Additions and adjustments .................  

Disposals ..............................................  

Effects of movements in exchange 

rates ....................................................  

Transferred to held for sale and 

Accumulated depreciation: 

Depreciation ........................................  

Disposals ..............................................  

Effects of movements in exchange 

rates ....................................................  

Transferred to held for sale and 

            Buildings 

          Rail cars 

        Surface leases 

         Other 

Total 

At January 1, 2018 (note 4) .................  

         $     57,706

  $    87,458            $         19,522 

  $  5,862             $    170,548 

4,232

(224)

588

12,529

-

-

619 

(683) 

493 

2,126 

- 

269 

19,506 

(907) 

1,350 

disposals (note 8) ................................  

(8,744)

(19,101)

(18,027) 

(3,922) 

(49,794) 

At December 31, 2018 .........................  

$     53,558

$    80,886            $            1,924 

$     4,335 

$    140,703 

At January 1, 2018 (note 4) .................  

  $ 

-

  $              -           $                  - 

  $            - 

  $ 

8,705

(81)

32,858                          805 

1,679 

-                          (32) 

50                  - 

                         11 

- 

44,047 

(113) 

111 

- 

50 

disposals (note 8) ................................  

(1,051)

(909)                       (436) 

(126) 

(2,522) 

At December 31, 2018 .........................  

$      7,623

$   31,949          $             348 

         $    1,603 

$     41,523 

Carrying amounts: 

At January 1, 2018 ...............................  

At December 31, 2018 .........................  

$    57,706

$    45,935

  $    87,458           $        19,522 

  $ 

 5,862 

  $  170,548 

$    48,937          $          1,576 

       $     2,732 

         $       99,180 

12  Long-term prepaid and other assets 

Long-term prepaid ...............................................................................................................  

$ 

Risk management assets (note 30) ......................................................................................  

Defined benefit pension plan assets ....................................................................................  

Other assets .........................................................................................................................  

U.S. tax receivable ...............................................................................................................  

December 31, 

2018 

348  

- 

530 

89 

3,836 

 4,803 

$ 

2017 

835 

1,367 

635 

1,008 

3,519 

7,364 

$ 

$ 

 
  
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

11  Right-of-use assets  

Cost: 

At January 1, 2017 ......................    $ 188,380    $  209,454 

  $ 608,344    $  457,871    $  920,843 

  $ 104,868    $ 2,489,760 

Cost: 

            Buildings 

          Rail cars 

        Surface leases 

         Other 

Total 

At January 1, 2018 (note 4) .................  
Additions and adjustments .................  
Disposals ..............................................  
Effects of movements in exchange 
rates ....................................................  
Transferred to held for sale and 
disposals (note 8) ................................  

         $     57,706
4,232
(224)

  $    87,458            $         19,522 
619 
(683) 

12,529
-

  $  5,862             $    170,548 
19,506 
(907) 

2,126 
- 

588

-

493 

269 

1,350 

(8,744)

(19,101)

(18,027) 

(3,922) 

(49,794) 

At December 31, 2018 .........................  

$     53,558

$    80,886            $            1,924 

$     4,335 

$    140,703 

Accumulated depreciation: 

At January 1, 2018 (note 4) .................  
Depreciation ........................................  
Disposals ..............................................  
Effects of movements in exchange 
rates ....................................................  
Transferred to held for sale and 
disposals (note 8) ................................  

  $ 

-
8,705
(81)

  $              -           $                  - 
32,858                          805 
-                          (32) 

  $            - 
1,679 
- 

  $ 

50                  - 

                         11 

(1,051)

(909)                       (436) 

50 

(126) 

- 
44,047 
(113) 

111 

(2,522) 

At December 31, 2018 .........................  

$      7,623

$   31,949          $             348 

         $    1,603 

$     41,523 

Carrying amounts: 
At January 1, 2018 ...............................  
At December 31, 2018 .........................  

12  Long-term prepaid and other assets 

$    57,706
$    45,935

  $    87,458           $        19,522 
$    48,937          $          1,576 

  $ 

 5,862 
       $     2,732 

  $  170,548 
         $       99,180 

Long-term prepaid ...............................................................................................................  
Risk management assets (note 30) ......................................................................................  
Defined benefit pension plan assets ....................................................................................  
Other assets .........................................................................................................................  
U.S. tax receivable ...............................................................................................................  

December 31, 
2018 

$ 

$ 

348  
- 
530 
89 
3,836 
 4,803 

2017 

835 
1,367 
635 
1,008 
3,519 
7,364 

$ 

$ 

Land & 

Pipelines and 

Buildings 

Connections 

Tanks 

Rolling  

Stock 

Work in 

Progress 

Total 

Plant, 

Equipment 

& Disposal 

wells 

Additions .................................... 

Disposals ..................................... 

Change in decommissioning 

2,204 

(4,640) 

provision (note 19) .................. 

- 

Reclassifications.......................... 

5,080 

Effect of movements in 

5,177 

- 

2,151 

8,897 

7,579 

(1,523) 

4,317 

(34,475) 

16,696 

(11,283) 

142,876 

3,956 

24,805 

- 

- 

4,606 

23,058 

(61,840) 

178,849 

(51,921) 

10,713 

- 

exchange rates ........................ 

(1,934) 

- 

(1,024) 

(16,019) 

(16,542) 

(165) 

(35,684) 

At December 31, 2017 ................    $ 189,090    $  225,679 

  $ 642,137    $  411,694    $  937,378 

  $ 185,739   $ 2,591,717 

Accumulated depreciation and 

impairment: 

Depreciation ............................... 

Impairment  ................................ 

Disposals ..................................... 

Effect of movements in 

At January 1, 2017 ......................    $  31,778    $ 

73,052 

  $  96,609    $  275,002    $  370,025 

  $ 

-    $  846,466 

6,663 

- 

(287) 

9,140 

26,428 

42,511 

12,143 

78,328 

17,089 

- 

(1,408) 

(32,554) 

(11,143) 

- 

- 

- 

163,070 

29,232 

(45,392) 

(21,347) 

exchange rates ........................ 

(289) 

(456) 

(10,921) 

(9,681) 

At December 31, 2017 ................    $  37,865    $ 

82,192 

  $121,173     $  286,181    $  444,618 

  $ 

-    $  972,029 

- 

- 

- 

- 

- 

- 

Carrying amounts: 

At January 1, 2017 ......................    $ 156,602    $   136,402 

  $  511,735   $  182,869    $  550,818 

  $ 104,868 

  $1,643,294 

At December 31, 2017 ................  $ 151,225   $   143,487  

$  520,964  $  125,513  $  492,760  

$ 185,739   $1,619,688 

Additions to property, plant and equipment include capitalization of interest of $8.4  million and $4.7  million for the year ended 

December 31, 2018 and 2017, respectively. 

Property, plant and equipment are reviewed for impairment whenever events or conditions indicate that their net carrying amount 

may not be recoverable. During the year ended December 31, 2018, the Company recorded an impairment loss of $76.2 million, of 

which $74.7 million relates to assets held for sale relating to assets in the TT Canada business, Wholesale Propane business, non-core 

ESN business, Injection Stations, which are included within the Logistics and Infrastructure reportable segments (note 8), and $1.5 

million  included  within  the  cost  of  sales  in  the  statements  of  operations  related  to  the  U.S.  Truck  and  Transportation  business 

included within the Logistics reportable segment. Key assumptions used in the determination of the recoverable amounts include 

reference to management’s assessment of the expected proceeds to be received upon sale, as well as the depreciable replacement 

cost values where applicable.   

of sales (note 8).  

During the year ended December 31, 2017, the Company recorded an impairment loss of $29.2 million. The impairment loss related 

to assets within the U.S. Environmental Services business which was included within the Company's discontinued operations in cost 

Amounts in relation to tanks are under operating lease arrangements.  

30 

Gibson Energy 

31 
79 

Consolidated Financial Statements

 
  
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

13  Intangible assets 

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Brands 

Customer 
relationships 

Long-term 
customer 
contracts 

Non-compete 
agreements 

Technology 
and Software 

Total 

Customer 

Brands 

relationships 

Non-compete 

Technology 

agreements 

and Software 

Total 

Long-term 

customer 

contracts 

- 
- 

Cost: 
At January 1, 2018 ................     $  45,512    $ 252,879 
- 
Additions ...............................  
Disposals ...............................  
- 
Acquisitions through 
business combinations 
(note 9)................................  
Effect of movements in 
exchange rates ....................  
Transferred to held for sale 
(159,552) 
and disposals (note 8) .........  
At December 31, 2018 ..........     $  34,837    $   99,431 

(11,051) 

6,104 

376 

- 

- 

Accumulated amortization 

and impairment: 

At January 1, 2018 ................     $  44,472    $ 250,560 
1,118 
Amortization .........................  
- 
Impairment (note 8) .............  
Disposals ...............................  
- 
Effect of movements in 
exchange rates ....................  
Transferred to held for sale 
(159,640) 
and disposals (note 8) .........  
At December 31, 2018 ..........     $  34,825    $   98,206  

727 
273 
- 

(11,030) 

6,168 

383 

  $  39,971 
- 
- 

  $  24,598 
- 
- 

     $     83,833 
             3,271 
              (134) 

  $ 446,793 
3,271 
(134) 

19,594 

- 

                     - 

19,594 

4,060 

124 

                593 

11,257 

- 
  $  63,625 

(4,324) 
  $  20,398  

        (12,921) 
     $    74,642  

(187,848) 
  $ 292,933  

  $  39,971 
508 
- 
- 

  $  24,551 
47 
- 
- 

    $     53,390 
          10,334 
            2,057 
             (125) 

  $ 412,944 
12,734 
2,330 
(125) 

3,195 

124 

             (229) 

9,641 

- 
  $  43,674 

(4,324) 
  $  20,398  

        (11,593) 
    $     53,834  

(186,587) 
  $ 250,937 

Cost: 

Effect of movements in 

Accumulated amortization 

and impairment: 

Effect of movements in 

Carrying amounts: 

At January 1, 2017 ...................     $  46,288    $ 264,587 

  $  42,539 

  $  25,290 

    $     78,052 

  $ 456,756 

Additions ..................................  

- 

- 

- 

- 

            6,575 

6,575 

exchange rates .......................  

(776) 

(11,708) 

(2,568) 

(692) 

             (794)  

(16,538) 

At December 31, 2017 .............     $  45,512    $ 252,879 

  $  39,971 

  $  24,598 

    $     83,833 

  $ 446,793 

At January 1, 2017 ...................     $  44,155    $ 250,665 

  $  29,634 

  $  24,037 

    $     42,179 

  $ 390,670 

Amortization ............................  

1,090 

Impairment (note 8) ................  

- 

5,095 

5,947 

12,188 

- 

1,202 

- 

          11,902 

                    - 

31,477 

5,947 

exchange rates .......................  

(773) 

(11,147) 

(1,851) 

(688) 

             (691) 

(15,150) 

At December 31, 2017 .............     $  44,472    $ 250,560 

  $  39,971 

  $  24,551 

   $      53,390 

  $ 412,944 

At January 1, 2017 ...................      $     2,133      $   13,922 

   $  12,905 

    $      1,253 

   $      35,873 

$    66,086 

At December 31, 2017 .............   $     1,040      $     2,319     $            -   

$            47         $       30,443  

$    33,849    

Intangible assets are reviewed for impairment whenever events or conditions indicate that their net carrying amount may not be 

recoverable. During the year ended December 31, 2018 and December 31, 2017, the Company recorded an impairment loss of $2.3 

million and $5.9 million, respectively, that was included in the statement of operations within discontinued operations (note 8).  

Opening balance ..........................................................................................................................  

$  381,965   

$  454,489 

Acquisitions through business combinations (note 9) .................................................................  

              32,656   

                          - 

Impairments  ................................................................................................................................  

Transfers to assets held for sale (note 8) .....................................................................................  

Effect of changes in foreign exchange rates ................................................................................  

(20,479) 

(33,342) 

1,548  

(69,414) 

- 

(3,110) 

Closing balance ............................................................................................................................  

$  362,348   

$  381,965 

Year ended 

December 31, 

2018 

2017 

$    33,849    
$    41,996         

14  Goodwill 

The changes in the carrying amount of goodwill are as follows: 

Carrying amounts: 
At January 1, 2018 ................      $     1,040          $     2,319         
At December 31, 2018 ..........  

    $            47           $     30,443  
   $     20,808  

$          12      $      1,225     $     19,951       $              -      

   $            -   

Consolidated Financial Statements 

32 

80 

Gibson Energy

33 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

13  Intangible assets 

At January 1, 2018 ................     $  45,512    $ 252,879 

  $  39,971 

  $  24,598 

     $     83,833 

  $ 446,793 

Customer 

Brands 

relationships 

Non-compete 

Technology 

agreements 

and Software 

Long-term 

customer 

contracts 

Total 

3,271 

(134) 

             3,271 

              (134) 

- 

- 

- 

19,594 

                     - 

19,594 

exchange rates ....................  

376 

6,104 

4,060 

124 

                593 

11,257 

and disposals (note 8) .........  

(11,051) 

(159,552) 

- 

(4,324) 

        (12,921) 

(187,848) 

At December 31, 2018 ..........     $  34,837    $   99,431 

  $  63,625 

  $  20,398  

     $    74,642  

  $ 292,933  

Cost: 

Additions ...............................  

Disposals ...............................  

Acquisitions through 

business combinations 

(note 9)................................  

Effect of movements in 

Transferred to held for sale 

Accumulated amortization 

and impairment: 

Amortization .........................  

Impairment (note 8) .............  

Disposals ...............................  

Effect of movements in 

exchange rates ....................  

Transferred to held for sale 

- 

- 

- 

727 

273 

- 

383 

- 

- 

- 

- 

- 

At January 1, 2018 ................     $  44,472    $ 250,560 

  $  39,971 

  $  24,551 

    $     53,390 

  $ 412,944 

1,118 

508 

47 

- 

- 

          10,334 

            2,057 

             (125) 

12,734 

2,330 

(125) 

6,168 

3,195 

124 

             (229) 

9,641 

and disposals (note 8) .........  

(11,030) 

(159,640) 

(4,324) 

        (11,593) 

(186,587) 

At December 31, 2018 ..........     $  34,825    $   98,206  

  $  43,674 

  $  20,398  

    $     53,834  

  $ 250,937 

Carrying amounts: 

At January 1, 2018 ................      $     1,040          $     2,319         

   $            -   

    $            47           $     30,443  

$    33,849    

At December 31, 2018 ..........  

$          12      $      1,225     $     19,951       $              -      

   $     20,808  

$    41,996         

- 

- 

- 

- 

- 

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Brands 

Customer 
relationships 

Long-term 
customer 
contracts 

Non-compete 
agreements 

Technology 
and Software 

Total 

Cost: 
At January 1, 2017 ...................     $  46,288    $ 264,587 
Additions ..................................  
- 
Effect of movements in 
(11,708) 
exchange rates .......................  
At December 31, 2017 .............     $  45,512    $ 252,879 

(776) 

- 

Accumulated amortization 

and impairment: 

At January 1, 2017 ...................     $  44,155    $ 250,665 
5,095 
Amortization ............................  
Impairment (note 8) ................  
5,947 
Effect of movements in 
(11,147) 
exchange rates .......................  
At December 31, 2017 .............     $  44,472    $ 250,560 

1,090 
- 

(773) 

  $  42,539 
- 

  $  25,290 
- 

    $     78,052 
            6,575 

  $ 456,756 
6,575 

(2,568) 
  $  39,971 

(692) 
  $  24,598 

             (794)  
    $     83,833 

(16,538) 
  $ 446,793 

  $  29,634 
12,188 
- 

  $  24,037 
1,202 
- 

    $     42,179 
          11,902 
                    - 

  $ 390,670 
31,477 
5,947 

(1,851) 
  $  39,971 

(688) 
  $  24,551 

             (691) 
   $      53,390 

(15,150) 
  $ 412,944 

Carrying amounts: 
At January 1, 2017 ...................      $     2,133      $   13,922 
   $  12,905 
At December 31, 2017 .............   $     1,040      $     2,319     $            -   

    $      1,253 

   $      35,873 
$            47         $       30,443  

$    66,086 
$    33,849    

Intangible assets are reviewed for impairment whenever events or conditions indicate that their net carrying amount may not be 
recoverable. During the year ended December 31, 2018 and December 31, 2017, the Company recorded an impairment loss of $2.3 
million and $5.9 million, respectively, that was included in the statement of operations within discontinued operations (note 8).  

14  Goodwill 

The changes in the carrying amount of goodwill are as follows: 

Year ended 
December 31, 
2018 

2017 

Opening balance ..........................................................................................................................  
Acquisitions through business combinations (note 9) .................................................................  
Impairments  ................................................................................................................................  
Transfers to assets held for sale (note 8) .....................................................................................  
Effect of changes in foreign exchange rates ................................................................................  
Closing balance ............................................................................................................................  

$  381,965   
              32,656   
(20,479) 
(33,342) 
1,548  
$  362,348   

$  454,489 
                          - 
(69,414) 
- 
(3,110) 
$  381,965 

32 

Gibson Energy 

33 
81 

Consolidated Financial Statements

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Goodwill  is  monitored  for  impairment  by  management  at  the  operating  segment  level.  The  following  is  a  summary  of  goodwill 
allocated to each operating segment: 

performance  as  well  as  expected  developments  in  the  respective  markets  and  in  the  overall  macro-economic  environment.  The 

calculation of the recoverable amount using the discounted cash flow approach was based on the following key assumptions:   

Terminals, Pipelines and Injection Stations ..............................................................................  
Moose Jaw Facility ....................................................................................................................  
TT Canada .................................................................................................................................  
Canadian Wholesale Marketing ................................................................................................  

December 31, 

2018 

2017             

  $     229,776 
89,017 
- 
43,555 
 362,348 

  $ 

  $  197,538 
89,017 
19,988 
75,422 
  $  381,965 

The goodwill recorded on the balance sheet represents the excess of the cost of acquisitions over the fair value of identifiable assets, 
liabilities and contingent liabilities acquired. Of the balance as at December 31, 2018, $325.6 million, net of impairment, relates to 
goodwill recognized on the acquisition of the Company on December 12, 2008. 

On March 31, 2018, the Company reviewed impairment indicators and determined that based on a review of the performance of the 
business during the period, impairment indicators existed in the Injection Stations operating segment. Accordingly, the Company 
performed an impairment test by comparing the FVLCD to the carrying value, including goodwill. As a result, it was determined that 
goodwill in this segment was impaired by $2.0 million (note 8).   

On September 30, 2018, the Company reviewed impairment indicators and determined that based on a review of the anticipated 
sale transaction, impairment indicators existed in the Wholesale Propane business disposal group within the Canadian Wholesale 
Marketing  segment.  Accordingly,  the  Company  performed  an  impairment  test  by  comparing  the  FVLCD  to  the  carrying  value, 
including goodwill. As a result, it was determined that goodwill in this segment was impaired by $18.5 million (note 8).   

On November 30, 2018, the Company carried out its annual impairment test with respect to goodwill. For all operating segments 
within  continuing  operations,  the  recoverable  amount  was  greater  than  the  carrying  value,  including  goodwill.  For  discontinued 
operations, management also performed its annual impairment test with respect to goodwill and as a result, an impairment of $20.0 
million within the TT Canada business was recorded.   

Key assumptions used in 2018 impairment test  

To calculate the recoverable amount, management uses the higher of the FVLCD and VIU. The recoverable amount was determined 
using either a discounted cash flow approach, an earnings multiple approach, or market based approach. The Company references 
Board  approved  budgets  and  cash  flow  forecasts,  trailing  twelve-month  (TTM)  earnings  before  interest,  taxes,  depreciation  and 
amortization and impairment (EBITDA), implied multiples and appropriate discount rates in the valuation calculations. The implied 
multiple is calculated by utilizing multiples of comparable public companies by operating segment. To determine fair value, an implied 
forward  multiple  was  applied  to  each  operating  segment’s  budgeted  EBITDA  less  corporate  expenses.  The  implied  multiple  is 
calculated by utilizing multiples of comparable public companies by operating segment. In calculating fair value for each operating 
segment, the Company used an implied average forward multiples that ranged from 8 to 11, and for businesses that are classified as 
held for sale the Company referenced management’s assessment of the expected proceeds to be received upon sale (note 8). The 
fair value of each operating segment was categorized as Level 2 fair value based on the observables inputs. 

Key assumptions used in 2017 impairment test 

On November 30, 2017, the Company carried out its annual impairment test with respect to goodwill. For all operating segments, 
other than the U.S. Truck and Transportation and U.S. Wholesale Marketing, the recoverable amount was greater than the carrying 
value, including goodwill. The carrying amount of the U.S. Truck and Transportation was determined to be higher than its recoverable 
amount of $46.0 million which resulted in recording an impairment write down of $41.2 million. The carrying amount of the U.S. 
Wholesale Marketing operating segment was determined to be higher than its recoverable amount of $16.9 million which resulted 
in recording an impairment write down of $28.2 million. The recoverable amount was determined by discounting the future cash 
flows generated from continued use of the operating segments. The model calculated the present value of the estimated future 
earnings  of  the  above  stated  operating  segments.  Estimating  future  earnings  requires  judgement,  considering  past  and  actual 

U.S. Truck and 

Transportation 

U.S. Wholesale 

Canadian Wholesale 

Marketing 

Marketing 

Discount rate ................................................................... 

Terminal value growth rate ............................................. 

12.1%

2.0%

12.9%

2.0%

12.9%

2.0%

(i) 

Cash flows were projected based on past experience, actual operating results and the five-year business plan. The range of the 

five-year average cash flow projections for these operating segments was between $1.0 million and $19.3 million. 

(ii) 

The terminal value growth rate is based on management's best estimate of the long-term growth rate for after the forecast 

period, considering historic performance and future economic forecasts. 

(iii) 

Each  operating  segment  discount  rate  reflects  their  individual  size,  risk  profile  and  circumstance  and  is  based  on  past 

experience and industry average weighted average cost of capital. 

The fair value of calculations are categorized as Level 3 fair value based on the unobservable inputs. 

15  Loans and Borrowings 

Revolving Credit Facility 

During the year ended December 31, 2018, the Company amended the unsecured revolving credit facility of  $560.0 million (the 

“Revolving Credit Facility”), to extend the maturity date of the facility to March 31, 2023 and amend certain financial covenants as 

noted below. In addition, the Company has three demand letter of credit facilities totaling $150.0 million. 

The Revolving Credit Facility permits letters of credit, swingline loans and borrowings in Canadian dollars and U.S. dollars. Borrowings 

under the Revolving Credit Facility bear interest at a rate equal to Canadian Prime Rate or U.S. Base  Rate or LIBOR or Canadian 

Bankers Acceptance Rate as the case may be, plus an applicable margin. The applicable margin for borrowings under the Revolving 

Credit Facility is subject to step up and step down based on the Company’s total debt leverage ratio. In addition, the Company must 

pay standby fees on the unused portion of the Revolving Credit Facility and customary letter of credit fees equal to the applicable 

margins based on the Company’s total debt leverage ratio. 

Under the terms of Revolving Credit Facility, the Company is required to adhere to certain financial and maintenance covenants 

including maintaining maximum consolidated senior and maximum consolidated total debt leverage ratios of 4.85 to 1.0 for the 2018 

fiscal  year,  4.5  to  1.0  for  the  2019  fiscal  year  and  4.0  to 1.0  thereafter.  In  addition,  the  Company  is  also  required  to  maintain  a 

minimum interest coverage ratio of no less than 2.5 to 1.0. As at December 31, 2018 and December 31, 2017, the Company was in 

compliance with all covenants under the Revolving Credit Facility. 

The  Company  had  $150.0  million  ($150.0  million;  U.S.$nil)  and  $230.2  million  ($105.0  million;  U.S.$100.0  million)  drawn  on  its 

Revolving Credit Facility as of December 31, 2018 and December 31, 2017, respectively, and had issued letters of credit totaling $70.9 

million  and  $68.9  million  under  its  bilateral  demand  letter  of  credit  facilities  as  at  December  31,  2018  and  December  31,  2017, 

respectively.   

Consolidated Financial Statements 

34 

82 

Gibson Energy

35 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Goodwill  is  monitored  for  impairment  by  management  at  the  operating  segment  level.  The  following  is  a  summary  of  goodwill 

allocated to each operating segment: 

performance  as  well  as  expected  developments  in  the  respective  markets  and  in  the  overall  macro-economic  environment.  The 
calculation of the recoverable amount using the discounted cash flow approach was based on the following key assumptions:   

Terminals, Pipelines and Injection Stations ..............................................................................  

  $     229,776 

  $  197,538 

Moose Jaw Facility ....................................................................................................................  

TT Canada .................................................................................................................................  

Canadian Wholesale Marketing ................................................................................................  

December 31, 

2018 

2017             

89,017 

- 

43,555 

89,017 

19,988 

75,422 

  $ 

 362,348 

  $  381,965 

The goodwill recorded on the balance sheet represents the excess of the cost of acquisitions over the fair value of identifiable assets, 

liabilities and contingent liabilities acquired. Of the balance as at December 31, 2018, $325.6 million, net of impairment, relates to 

goodwill recognized on the acquisition of the Company on December 12, 2008. 

On March 31, 2018, the Company reviewed impairment indicators and determined that based on a review of the performance of the 

business during the period, impairment indicators existed in the Injection Stations operating segment. Accordingly, the Company 

performed an impairment test by comparing the FVLCD to the carrying value, including goodwill. As a result, it was determined that 

goodwill in this segment was impaired by $2.0 million (note 8).   

On September 30, 2018, the Company reviewed impairment indicators and determined that based on a review of the anticipated 

sale transaction, impairment indicators existed in the Wholesale Propane business disposal group within the Canadian Wholesale 

Marketing  segment.  Accordingly,  the  Company  performed  an  impairment  test  by  comparing  the  FVLCD  to  the  carrying  value, 

including goodwill. As a result, it was determined that goodwill in this segment was impaired by $18.5 million (note 8).   

On November 30, 2018, the Company carried out its annual impairment test with respect to goodwill. For all operating segments 

within  continuing  operations,  the  recoverable  amount  was  greater  than  the  carrying  value,  including  goodwill.  For  discontinued 

operations, management also performed its annual impairment test with respect to goodwill and as a result, an impairment of $20.0 

million within the TT Canada business was recorded.   

Key assumptions used in 2018 impairment test  

To calculate the recoverable amount, management uses the higher of the FVLCD and VIU. The recoverable amount was determined 

using either a discounted cash flow approach, an earnings multiple approach, or market based approach. The Company references 

Board  approved  budgets  and  cash  flow  forecasts,  trailing  twelve-month  (TTM)  earnings  before  interest,  taxes,  depreciation  and 

amortization and impairment (EBITDA), implied multiples and appropriate discount rates in the valuation calculations. The implied 

multiple is calculated by utilizing multiples of comparable public companies by operating segment. To determine fair value, an implied 

forward  multiple  was  applied  to  each  operating  segment’s  budgeted  EBITDA  less  corporate  expenses.  The  implied  multiple  is 

calculated by utilizing multiples of comparable public companies by operating segment. In calculating fair value for each operating 

segment, the Company used an implied average forward multiples that ranged from 8 to 11, and for businesses that are classified as 

held for sale the Company referenced management’s assessment of the expected proceeds to be received upon sale (note 8). The 

fair value of each operating segment was categorized as Level 2 fair value based on the observables inputs. 

Key assumptions used in 2017 impairment test 

On November 30, 2017, the Company carried out its annual impairment test with respect to goodwill. For all operating segments, 

other than the U.S. Truck and Transportation and U.S. Wholesale Marketing, the recoverable amount was greater than the carrying 

value, including goodwill. The carrying amount of the U.S. Truck and Transportation was determined to be higher than its recoverable 

amount of $46.0 million which resulted in recording an impairment write down of $41.2 million. The carrying amount of the U.S. 

Wholesale Marketing operating segment was determined to be higher than its recoverable amount of $16.9 million which resulted 

in recording an impairment write down of $28.2 million. The recoverable amount was determined by discounting the future cash 

flows generated from continued use of the operating segments. The model calculated the present value of the estimated future 

earnings  of  the  above  stated  operating  segments.  Estimating  future  earnings  requires  judgement,  considering  past  and  actual 

U.S. Truck and 
Transportation 

U.S. Wholesale 
Marketing 

Canadian Wholesale 
Marketing 

Discount rate ................................................................... 
Terminal value growth rate ............................................. 

12.1%
2.0%

12.9%
2.0%

12.9%
2.0%

Cash flows were projected based on past experience, actual operating results and the five-year business plan. The range of the 

(i) 
five-year average cash flow projections for these operating segments was between $1.0 million and $19.3 million. 

The terminal value growth rate is based on management's best estimate of the long-term growth rate for after the forecast 

(ii) 
period, considering historic performance and future economic forecasts. 

Each  operating  segment  discount  rate  reflects  their  individual  size,  risk  profile  and  circumstance  and  is  based  on  past 

(iii) 
experience and industry average weighted average cost of capital. 

The fair value of calculations are categorized as Level 3 fair value based on the unobservable inputs. 

15  Loans and Borrowings 

Revolving Credit Facility 

During the year ended December 31, 2018, the Company amended the unsecured revolving credit facility of  $560.0 million (the 
“Revolving Credit Facility”), to extend the maturity date of the facility to March 31, 2023 and amend certain financial covenants as 
noted below. In addition, the Company has three demand letter of credit facilities totaling $150.0 million. 

The Revolving Credit Facility permits letters of credit, swingline loans and borrowings in Canadian dollars and U.S. dollars. Borrowings 
under the Revolving Credit Facility bear interest at a rate equal to Canadian Prime Rate or U.S. Base  Rate or LIBOR or Canadian 
Bankers Acceptance Rate as the case may be, plus an applicable margin. The applicable margin for borrowings under the Revolving 
Credit Facility is subject to step up and step down based on the Company’s total debt leverage ratio. In addition, the Company must 
pay standby fees on the unused portion of the Revolving Credit Facility and customary letter of credit fees equal to the applicable 
margins based on the Company’s total debt leverage ratio. 

Under the terms of Revolving Credit Facility, the Company is required to adhere to certain financial and maintenance covenants 
including maintaining maximum consolidated senior and maximum consolidated total debt leverage ratios of 4.85 to 1.0 for the 2018 
fiscal  year,  4.5  to  1.0  for  the  2019  fiscal  year  and  4.0  to 1.0  thereafter.  In  addition,  the  Company  is  also  required  to  maintain  a 
minimum interest coverage ratio of no less than 2.5 to 1.0. As at December 31, 2018 and December 31, 2017, the Company was in 
compliance with all covenants under the Revolving Credit Facility. 

The  Company  had  $150.0  million  ($150.0  million;  U.S.$nil)  and  $230.2  million  ($105.0  million;  U.S.$100.0  million)  drawn  on  its 
Revolving Credit Facility as of December 31, 2018 and December 31, 2017, respectively, and had issued letters of credit totaling $70.9 
million  and  $68.9  million  under  its  bilateral  demand  letter  of  credit  facilities  as  at  December  31,  2018  and  December  31,  2017, 
respectively.   

34 

Gibson Energy 

35 
83 

Consolidated Financial Statements

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Long-term debt 

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

16  Lease Liabilities 

December 31,  

2018 

2017 

Revolving credit facility, due March 31, 2023 ........................................................................  
$300 million 5.375% Notes due July 15, 2022 ........................................................................  
$600 million 5.25% Notes due July 15, 2024 ..........................................................................  
Unamortized issue discount and debt issue costs .................................................................  
Long-term debt ......................................................................................................................  

  $       150,000  
300,000 
600,000 
(10,422) 
  $  1,039,578 

  $  230,180 
300,000 
600,000 
(12,061)
  $ 1,118,119 

The Notes agreements contain certain redemption options whereby the Company can redeem all or part of the Notes, at prices set 
forth in the agreements, from proceeds of an equity offering or on the dates specified in the agreement. In addition, the Notes 
holders have the right to require the Company to redeem the Notes at the redemption prices set forth in the agreement in the event 
of  a  change  in  control  or  in  the  event  certain  asset  sale  proceeds  are  not  re-invested  in  the  time  and  manner  specified  in  the 
agreement.  

The Company’s long-term debt contains non-financial covenants and customary events of default clauses. As of December 31, 2018 
and December 31, 2017, the Company was in compliance with all of its covenants.  

The components of finance costs are as follows: 

December 31, 

2018 

2017             

        Interest expense, net of capitalized interest  ...........................................................................  
        Interest expense, finance lease (note 16)  ................................................................................  
        Interest income .........................................................................................................................  
        Foreign exchange loss (gain) on long-term debt  .....................................................................  
Debt extinguishment costs .......................................................................................................  
        Total finance cost, net ..............................................................................................................  

  $ 
69,674  
                5,907 
(1,492)  
                4,403 
- 
78,492  

  $ 

  $ 
78,863 
                        - 
(1,782) 
(18,788) 
60,492 
  $  118,785 

Opening balance (note 4) ..............................................................................................................  

  $ 

Additions .......................................................................................................................................  

Disposals ........................................................................................................................................  

Interest expense ............................................................................................................................  

Interest expense from discontinued operations (note 8) .............................................................  

Lease payments .............................................................................................................................  

Effect of movements in exchange rates ........................................................................................  

Transferred to held for sale and disposals (note 8).......................................................................  

Ending balance  .............................................................................................................................  

Less: current portion .....................................................................................................................  

Ending balance – non-current portion ..........................................................................................  

  $ 

Year ended 

December 31, 

2018 

172,834

19,506

(834)

5,907

616

(52,848)

8,309

(44,419)

109,071

36,200

72,871

Year ended 

December 31, 

2018 1 

Variable lease payments .............................................................................................................. 

    $         176,328      

Short-term and low-value leases.................................................................................................. 

6,737 

Total ............................................................................................................................................. 

            $         183,065      

1.  Variable lease payments, short-term and low-value leases on discontinued operations of $152 million for the year ended December 31, 2018 are 

included in the above amounts. 

The Company incurs lease payments related to rail cars, head office facilities, vehicles and equipment, and surface leases. Leases are 

entered  into  and  exited  in  coordination  with  specific  business  requirements  which  includes  the  assessment  of  the  appropriate 

durations for the related leased assets. The Company has recognised lease liabilities in relation to all lease arrangements measured 

at  the  present  value  of  the  remaining  lease  payments  from  commitments  disclosed  as  at  December  31,  2018  at  an  incremental 

Short-term leases are leases with a lease term of twelve months or less while low-value assets comprised of information technology 

and miscellaneous equipment. Such items are charged to cost of sales and general and administrative expenses in the consolidated 

borrowing rate of 5.0%.   

statements of operations. 

17  Convertible debentures 

Liability 

Component 

Equity 

Component 

Balance as at January 1, 2017 ..............................................................................................  

$ 

87,312  

$ 

7,151

Accretion of issue costs .......................................................................................................  

Deferred taxes .....................................................................................................................  

Balance as at December 31, 2017 .......................................................................................  

Accretion of issue costs........................................................................................................  

Balance as at December 31, 2018 .......................................................................................  

2,607  

                           - 

89,919  

$ 

-

2,547

(128)

7,023

-

92,466  

  $ 

7,023

$ 

$ 

At December 31, 2018, the Company has an aggregate of $100.0 million principal amount of unsecured subordinated convertible 

debentures (“the Debentures”) outstanding. The Debentures issued at par, bear interest at a rate of 5.25% per annum, payable semi-

annually on July 15 and January 15 in each year commencing January 15, 2017, will mature on July 15, 2021, and may be redeemed, 

in certain circumstances, on or after July 15, 2019. The Debentures are convertible at the holder's option into common shares at any 

Consolidated Financial Statements 

36 

84 

Gibson Energy

37 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Long-term debt 

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

16  Lease Liabilities 

December 31,  

2018 

2017 

Revolving credit facility, due March 31, 2023 ........................................................................  

  $       150,000  

  $  230,180 

$300 million 5.375% Notes due July 15, 2022 ........................................................................  

$600 million 5.25% Notes due July 15, 2024 ..........................................................................  

Unamortized issue discount and debt issue costs .................................................................  

300,000 

600,000 

(10,422) 

300,000 

600,000 

(12,061)

Long-term debt ......................................................................................................................  

  $  1,039,578 

  $ 1,118,119 

The Notes agreements contain certain redemption options whereby the Company can redeem all or part of the Notes, at prices set 

forth in the agreements, from proceeds of an equity offering or on the dates specified in the agreement. In addition, the Notes 

holders have the right to require the Company to redeem the Notes at the redemption prices set forth in the agreement in the event 

of  a  change  in  control  or  in  the  event  certain  asset  sale  proceeds  are  not  re-invested  in  the  time  and  manner  specified  in  the 

agreement.  

The Company’s long-term debt contains non-financial covenants and customary events of default clauses. As of December 31, 2018 

and December 31, 2017, the Company was in compliance with all of its covenants.  

The components of finance costs are as follows: 

December 31, 

2018 

2017             

        Interest expense, net of capitalized interest  ...........................................................................  

  $ 

69,674  

  $ 

78,863 

        Interest expense, finance lease (note 16)  ................................................................................  

                5,907 

                        - 

        Interest income .........................................................................................................................  

(1,492)  

        Foreign exchange loss (gain) on long-term debt  .....................................................................  

                4,403 

Debt extinguishment costs .......................................................................................................  

- 

(1,782) 

(18,788) 

60,492 

        Total finance cost, net ..............................................................................................................  

  $ 

78,492  

  $  118,785 

Opening balance (note 4) ..............................................................................................................  
Additions .......................................................................................................................................  
Disposals ........................................................................................................................................  
Interest expense ............................................................................................................................  
Interest expense from discontinued operations (note 8) .............................................................  
Lease payments .............................................................................................................................  
Effect of movements in exchange rates ........................................................................................  
Transferred to held for sale and disposals (note 8).......................................................................  
Ending balance  .............................................................................................................................  
Less: current portion .....................................................................................................................  
Ending balance – non-current portion ..........................................................................................  

Year ended 
December 31, 
2018 

  $ 

  $ 

172,834
19,506
(834)
5,907
616
(52,848)
8,309
(44,419)
109,071
36,200
72,871

Year ended 
December 31, 
2018 1 

Variable lease payments .............................................................................................................. 
Short-term and low-value leases.................................................................................................. 
Total ............................................................................................................................................. 

    $         176,328      

6,737 

            $         183,065      

1.  Variable lease payments, short-term and low-value leases on discontinued operations of $152 million for the year ended December 31, 2018 are 

included in the above amounts. 

The Company incurs lease payments related to rail cars, head office facilities, vehicles and equipment, and surface leases. Leases are 
entered  into  and  exited  in  coordination  with  specific  business  requirements  which  includes  the  assessment  of  the  appropriate 
durations for the related leased assets. The Company has recognised lease liabilities in relation to all lease arrangements measured 
at  the  present  value  of  the  remaining  lease  payments  from  commitments  disclosed  as  at  December  31,  2018  at  an  incremental 
borrowing rate of 5.0%.   

Short-term leases are leases with a lease term of twelve months or less while low-value assets comprised of information technology 
and miscellaneous equipment. Such items are charged to cost of sales and general and administrative expenses in the consolidated 
statements of operations. 

17  Convertible debentures 

Liability 
Component 

Equity 
Component 

Balance as at January 1, 2017 ..............................................................................................  
Accretion of issue costs .......................................................................................................  
Deferred taxes .....................................................................................................................  
Balance as at December 31, 2017 .......................................................................................  
Accretion of issue costs........................................................................................................  
Balance as at December 31, 2018 .......................................................................................  

$ 

$ 

$ 

87,312  
2,607  

-

89,919  
2,547
92,466  

$ 

7,151
                           - 
(128)
7,023
-
7,023

  $ 

$ 

36 

Gibson Energy 

37 
85 

Consolidated Financial Statements

At December 31, 2018, the Company has an aggregate of $100.0 million principal amount of unsecured subordinated convertible 
debentures (“the Debentures”) outstanding. The Debentures issued at par, bear interest at a rate of 5.25% per annum, payable semi-
annually on July 15 and January 15 in each year commencing January 15, 2017, will mature on July 15, 2021, and may be redeemed, 
in certain circumstances, on or after July 15, 2019. The Debentures are convertible at the holder's option into common shares at any 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

time prior to the earlier of the Maturity Date and the business day immediately preceding the date fixed for redemption by the 
Company at a conversion price of $21.65 per Share (the "Conversion Price"), being a ratio of approximately 46.1894 Shares per $1,000 
principal amount of Debentures. The Debentures are subordinated to the Company's senior indebtedness. 

20  Other long-term liabilities  

The Debentures are treated as a compound financial instrument and have been classified as a liability, net of issue costs and net of 
the fair value of the conversion feature at the date of issue, which has been classified as shareholders’ equity. The liability component 
will accrete up to the principal balance at maturity. The accretion of the liability component and interest payable are expensed in the 
statements of operations. The fair value of the conversion feature was determined at the time of issuance as the difference between 
the principal value of the Debentures and the discounted cash flows assuming a 7.8% rate which was the estimated rate for debt 
with similar terms with no conversion feature. If the Debentures are converted into common shares, a portion of the value of the 
conversion feature under shareholders’ equity and the liability component will be reclassified to shareholders’ equity along with the 
conversion price. 

21  Share capital 

Authorized 

Defined benefit plan obligations (note 28) ...............................................................................  

$ 

Risk management liabilities (note 30).......................................................................................  

Other post-retirement benefits obligations (note 28) ..............................................................  

December 31, 

2018 

967   

154   

2017 

1,262 

492 

4,758 

6,512 

$ 

$ 

15,198   

$  16,319   

18  Trade payables and accrued charges 

Trade payables and accrued charges include the following items: 

Trade payables ..........................................................................................................................  
Accrued compensation charges ................................................................................................  
Accrued payment obligation (note 8 & 9) ................................................................................  
Indirect taxes payable  ..............................................................................................................  
Risk management liabilities (note 30) ......................................................................................  
Defined benefit plan obligations ..............................................................................................  
Interest payable ........................................................................................................................  
Insurance payable .....................................................................................................................  
Other .........................................................................................................................................  

19  Provisions 

December 31, 

2018 

2017 

$  246,799  
20,146 
39,156 
1,840 
7,715 
253 
24,590 
6,266 
18,645 
$  365,410  

$  413,745 
30,523 
- 
3,122 
11,276 
286 
25,607 
7,114 
8,989 
$  500,662 

The aggregate carrying amounts of the obligation associated with decommissioning and site restoration on the retirement of assets 
and environmental costs are as follows: 

Opening balance ........................................................................................................................ 
Settlements ............................................................................................................................... 
Additions ................................................................................................................................... 
Acquisitions through business combinations (note 9)  ............................................................. 
Change in discount rate ............................................................................................................. 
Unwinding of discount .............................................................................................................. 
Transfer to liabilities held for sale (note 8) ............................................................................... 
Effect of changes in foreign exchange rates .............................................................................. 
Closing balance .......................................................................................................................... 

Year ended 
December 31, 

2018 

2017 

$  183,527 
(2,577) 
8,038 
444 
7,477 
3,916 
(38,950)   
936 
$  162,811  

$ 171,038 
(3,146) 
3,656 
- 
9,607 
3,912 
- 
(1,540) 
$ 183,527 

The Company currently estimates the total undiscounted future value amount, including an inflation factor of 2.0%, of estimated 
cash  flows  to  settle  the  future  liability  for  asset  retirement  and  remediation  obligations  to  be  approximately  $342.8  million  and 
$327.2 million at December 31, 2018 and 2017, respectively. In order to determine the current provision related to these future 
values, the estimated future values were discounted using an average risk-free rate of 2.2% and 2.2% at December 31, 2018 and 
2017, respectively. The provision is expected to be settled to 39 years into the future. A one percent increase or decrease in the risk-
free rate would decrease or increase the provision by $46.7 million, respectively, with a corresponding adjustment to property, plant 
and equipment. 

The Company is authorized to issue an unlimited number of common shares and preferred shares. 

Holders  of  common  shares  are  entitled  to  one  vote  per  common  share  at  meetings  of  shareholders  of  the  Company,  to  receive 

dividends if, as and when declared by the Board and to receive pro rata the remaining property and assets of the Company upon its 

dissolution, liquidation or winding-up, subject to the rights of shares having priority over the common shares. 

The preferred shares are issuable in series and have such rights, restrictions, conditions and limitations as the Board may from time 

to  time  determine.  The  preferred  shares  shall  rank  senior  to  the  common  shares  with  respect  to  the  payment  of  dividends  or 

distribution of assets or return of capital of the Company in the event of a dissolution, liquidation or winding up of the Company. 

There were no issued and outstanding preferred shares as at December 31, 2018 or 2017. 

Common Shares – Issued and outstanding 

The following table below sets forth the issued and outstanding common shares for the years ended December 31, 2018 and 2017.  

Common Shares 

Number of 

Common 

Shares 

Balance as at January 1, 2017 .........................................................................................................  

141,733,032   

$  1,909,032 

Issuance in connection with the exercise of stock options  ............................................................  

Issuance in connection with other equity awards ..........................................................................  

323,625 

1,147,731 

Reclassification of contributed surplus on issuance of awards under equity incentive plans ........  

Balance as at December 31, 2017 ...................................................................................................  

143,204,388   

$  1,932,103 

Issuance in connection with the exercise of stock options.............................................................  

Issuance in connection with other equity awards ..........................................................................  

Reclassification of contributed surplus on issuance of awards under equity incentive plans ........  

- 

- 

104,897 

1,249,505 

Balance as at December 31, 2018 ...................................................................................................  

144,558,790   

$  1,955,146 

A dividend of $0.33 per share, declared on November 8, 2018, was paid on January 17, 2019. For the year ended December 31, 2018 

the Company declared total dividends of $1.32 per common share. 

Amount 

2,822 

20,249 

1,056 

21,987 

- 

- 

Consolidated Financial Statements 

38 

86 

Gibson Energy

39 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

time prior to the earlier of the Maturity Date and the business day immediately preceding the date fixed for redemption by the 

20  Other long-term liabilities  

Company at a conversion price of $21.65 per Share (the "Conversion Price"), being a ratio of approximately 46.1894 Shares per $1,000 

principal amount of Debentures. The Debentures are subordinated to the Company's senior indebtedness. 

Defined benefit plan obligations (note 28) ...............................................................................  
Risk management liabilities (note 30).......................................................................................  
Other post-retirement benefits obligations (note 28) ..............................................................  

21  Share capital 

Authorized 

December 31, 
2018 

$ 

967   
154   
15,198   
$  16,319   

$ 

$ 

2017 

1,262 
492 
4,758 
6,512 

The Company is authorized to issue an unlimited number of common shares and preferred shares. 

Holders  of  common  shares  are  entitled  to  one  vote  per  common  share  at  meetings  of  shareholders  of  the  Company,  to  receive 
dividends if, as and when declared by the Board and to receive pro rata the remaining property and assets of the Company upon its 
dissolution, liquidation or winding-up, subject to the rights of shares having priority over the common shares. 

The preferred shares are issuable in series and have such rights, restrictions, conditions and limitations as the Board may from time 
to  time  determine.  The  preferred  shares  shall  rank  senior  to  the  common  shares  with  respect  to  the  payment  of  dividends  or 
distribution of assets or return of capital of the Company in the event of a dissolution, liquidation or winding up of the Company. 
There were no issued and outstanding preferred shares as at December 31, 2018 or 2017. 

Common Shares – Issued and outstanding 

The following table below sets forth the issued and outstanding common shares for the years ended December 31, 2018 and 2017.  

Balance as at January 1, 2017 .........................................................................................................  
Issuance in connection with the exercise of stock options  ............................................................  
Issuance in connection with other equity awards ..........................................................................  
Reclassification of contributed surplus on issuance of awards under equity incentive plans ........  
Balance as at December 31, 2017 ...................................................................................................  
Issuance in connection with the exercise of stock options.............................................................  
Issuance in connection with other equity awards ..........................................................................  
Reclassification of contributed surplus on issuance of awards under equity incentive plans ........  
Balance as at December 31, 2018 ...................................................................................................  

Common Shares 

Number of 
Common 
Shares 

141,733,032   
323,625 
1,147,731 
- 
143,204,388   
104,897 
1,249,505 
- 
144,558,790   

Amount 

$  1,909,032 
2,822 
- 
20,249 
$  1,932,103 
1,056 
- 
21,987 
$  1,955,146 

A dividend of $0.33 per share, declared on November 8, 2018, was paid on January 17, 2019. For the year ended December 31, 2018 
the Company declared total dividends of $1.32 per common share. 

The Debentures are treated as a compound financial instrument and have been classified as a liability, net of issue costs and net of 

the fair value of the conversion feature at the date of issue, which has been classified as shareholders’ equity. The liability component 

will accrete up to the principal balance at maturity. The accretion of the liability component and interest payable are expensed in the 

statements of operations. The fair value of the conversion feature was determined at the time of issuance as the difference between 

the principal value of the Debentures and the discounted cash flows assuming a 7.8% rate which was the estimated rate for debt 

with similar terms with no conversion feature. If the Debentures are converted into common shares, a portion of the value of the 

conversion feature under shareholders’ equity and the liability component will be reclassified to shareholders’ equity along with the 

conversion price. 

18  Trade payables and accrued charges 

Trade payables and accrued charges include the following items: 

Trade payables ..........................................................................................................................  

$  246,799  

$  413,745 

Accrued compensation charges ................................................................................................  

Accrued payment obligation (note 8 & 9) ................................................................................  

Indirect taxes payable  ..............................................................................................................  

Risk management liabilities (note 30) ......................................................................................  

Defined benefit plan obligations ..............................................................................................  

Interest payable ........................................................................................................................  

Insurance payable .....................................................................................................................  

Other .........................................................................................................................................  

19  Provisions 

December 31, 

2018 

2017 

20,146 

39,156 

1,840 

7,715 

253 

24,590 

6,266 

18,645 

30,523 

- 

3,122 

11,276 

286 

25,607 

7,114 

8,989 

$  365,410  

$  500,662 

The aggregate carrying amounts of the obligation associated with decommissioning and site restoration on the retirement of assets 

and environmental costs are as follows: 

Opening balance ........................................................................................................................ 

$  183,527 

$ 171,038 

Settlements ............................................................................................................................... 

Additions ................................................................................................................................... 

Acquisitions through business combinations (note 9)  ............................................................. 

Change in discount rate ............................................................................................................. 

Unwinding of discount .............................................................................................................. 

Transfer to liabilities held for sale (note 8) ............................................................................... 

Effect of changes in foreign exchange rates .............................................................................. 

Closing balance .......................................................................................................................... 

$  162,811  

Year ended 

December 31, 

2018 

2017 

(2,577) 

8,038 

444 

7,477 

3,916 

(38,950)   

936 

(3,146) 

3,656 

9,607 

3,912 

- 

- 

(1,540) 

$ 183,527 

The Company currently estimates the total undiscounted future value amount, including an inflation factor of 2.0%, of estimated 

cash  flows  to  settle  the  future  liability  for  asset  retirement  and  remediation  obligations  to  be  approximately  $342.8  million  and 

$327.2 million at December 31, 2018 and 2017, respectively. In order to determine the current provision related to these future 

values, the estimated future values were discounted using an average risk-free rate of 2.2% and 2.2% at December 31, 2018 and 

2017, respectively. The provision is expected to be settled to 39 years into the future. A one percent increase or decrease in the risk-

free rate would decrease or increase the provision by $46.7 million, respectively, with a corresponding adjustment to property, plant 

and equipment. 

38 

Gibson Energy 

39 
87 

Consolidated Financial Statements

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

22  Income tax  

The major components of income tax are as follows: 

Year ended 
December 31, 
2018 

Current tax expense (recovery) ........................................................................................  
Adjustments and true-ups in respect of prior years .........................................................  
Current tax expense – discontinued operations (note 8) .................................................  
Total current tax provision (recovery) ............................................................................  
Deferred tax recovery.......................................................................................................  
Origination and reversal of temporary differences ..........................................................  
Deferred tax expense (recovery) – discontinued operations (note 8) .............................  
Total deferred tax recovery .............................................................................................  
Net income tax expense (recovery) ................................................................................  

$ 

$ 

64,303  
 (4,125) 
3,410  
63,588  
(10,593) 
6,028 
2,695  
(1,870) 
 61,718     

2017 

(30,721) 
(4,981) 
32,094 
(3,608) 
(25,048) 
2,546 
(9,445) 
(31,947) 
(35,555) 

$ 

$ 

The income tax recovery differs from the amounts which would be obtained by applying the Canadian statutory income tax rate to 
income (loss) before income taxes. These differences result from the following items: 

Income (loss) before income taxes, continuing operations  ............................................  
Income before income taxes, discontinued operations  ..................................................  
Income before income taxes  ...........................................................................................  
Statutory income tax rate  ...............................................................................................  
Computed income tax expense ........................................................................................  
Changes in income tax expense (recovery) resulting from: 

Recognition of previously unrecognized capital losses, net  ....................................  
Foreign exchange gain, other  ...................................................................................  
Non-taxable portion of the loss (gain) on sale of net assets held for sale (note 8) ..  
Share based compensation  ......................................................................................  
Rate differential on foreign taxes  ............................................................................  
Goodwill impairment ................................................................................................  
Impact of corporate rate changes in U.S. .................................................................  
Adjustments and true ups in respect of prior years .................................................  
Other .........................................................................................................................  

Year ended 
December 31, 

2018 

2017 

$  136,738     

$ 

               76,028  
             212,766  
26.99% 
57,426 

-  

(38,834)    
24,996  
4,789  
702  
10,388  
-  
1,904  
347  
61,718 

$ 

$ 

(124,530) 
133,110 
8,580 
26.96% 
2,313 

(19,975) 
(2,520) 
(26,177) 
5,627 
(18,039) 
- 
32,758 
(4,981) 
(4,561) 
(35,555) 

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Effective income tax rate – continuing operations  .........................................................  

Effective income tax rate – discontinued operations .......................................................  

40.7  % 

8.0  % 

46.7% 

17.0% 

Year ended 

December 31, 

2018 

2017 

       $       60,178  

                  3,410  

     $     (35,702) 

               32,094 

$      63,588      

    $         (3,608) 

Current tax, from continuing operations .........................................................................  

Current tax, from discontinued operations ......................................................................  

Deferred tax, from continuing operations .......................................................................  

         $      (4,565)      

     $     (22,502) 

Deferred tax, from discontinued operations ....................................................................  

                 2,695           

            (9,445) 

      $     (1,870) 

     $    (31,947) 

Total current and deferred, from continuing operations .................................................  

Total current and deferred, from discontinued operations .............................................  

       $      55,613 

       $        6,105 

     $      (58,204) 

     $        22,649 

 The analysis of deferred tax assets and deferred tax liabilities is as follows: 

     Deferred tax assets: 

    Deferred tax liabilities: 

Deferred tax asset to be settled after more than 12 months ...................................  

$ 

Deferred tax asset to be settled within 12 months ...................................................  

33,274    

2,600   

$ 

70,021 

5,200 

$       35,874   

$       75,221 

Deferred tax liability to be settled after more than 12 months ................................  

$       77,440   

$       99,823 

Deferred tax liability to be settled within 12 months ...............................................  

200   

1,000 

$       77,640   

$     100,823 

Deferred tax liabilities, net ...............................................................................................  

$ 

41,766    

$ 

25,602 

The gross movement on the deferred income tax account is as follows: 

Opening balance ..................................................................................................................  

$ 

$ 

Effect of changes in foreign exchange rates ........................................................................  

Transfers to assets held for sale (note 8) ............................................................................  

Income statement recovery ................................................................................................  

Tax credit relating to components of other comprehensive income ..................................  

Closing balance ....................................................................................................................  

$ 

$ 

25,602 

Year ended 

December 31, 

2018   

25,602   

(4,164)  

25,108   

(1,870)  

(2,910)  

41,766   

2017 

55,185 

2,388 

- 

(31,947) 

(24) 

Consolidated Financial Statements 

40 

88 

Gibson Energy

41 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
  
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

22  Income tax  

The major components of income tax are as follows: 

Year ended 

December 31, 

2018 

2017 

Current tax expense (recovery) ........................................................................................  

$ 

$ 

(30,721) 

Adjustments and true-ups in respect of prior years .........................................................  

Current tax expense – discontinued operations (note 8) .................................................  

Total current tax provision (recovery) ............................................................................  

Deferred tax recovery.......................................................................................................  

Origination and reversal of temporary differences ..........................................................  

Deferred tax expense (recovery) – discontinued operations (note 8) .............................  

Total deferred tax recovery .............................................................................................  

64,303  

 (4,125) 

3,410  

63,588  

(10,593) 

6,028 

2,695  

(1,870) 

Net income tax expense (recovery) ................................................................................  

$ 

 61,718     

$ 

The income tax recovery differs from the amounts which would be obtained by applying the Canadian statutory income tax rate to 

income (loss) before income taxes. These differences result from the following items: 

Year ended 

December 31, 

2018 

2017 

Income (loss) before income taxes, continuing operations  ............................................  

$  136,738     

$ 

(124,530) 

Income before income taxes, discontinued operations  ..................................................  

Income before income taxes  ...........................................................................................  

Statutory income tax rate  ...............................................................................................  

Computed income tax expense ........................................................................................  

Changes in income tax expense (recovery) resulting from: 

Recognition of previously unrecognized capital losses, net  ....................................  

Foreign exchange gain, other  ...................................................................................  

Non-taxable portion of the loss (gain) on sale of net assets held for sale (note 8) ..  

Share based compensation  ......................................................................................  

Rate differential on foreign taxes  ............................................................................  

Goodwill impairment ................................................................................................  

Impact of corporate rate changes in U.S. .................................................................  

Adjustments and true ups in respect of prior years .................................................  

Other .........................................................................................................................  

               76,028  

             212,766  

26.99% 

57,426 

-  

(38,834)    

24,996  

4,789  

702  

10,388  

-  

1,904  

347  

(4,981) 

32,094 

(3,608) 

(25,048) 

2,546 

(9,445) 

(31,947) 

(35,555) 

133,110 

8,580 

26.96% 

2,313 

(19,975) 

(2,520) 

(26,177) 

5,627 

(18,039) 

- 

32,758 

(4,981) 

(4,561) 

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Effective income tax rate – continuing operations  .........................................................  
Effective income tax rate – discontinued operations .......................................................  

40.7  % 
8.0  % 

46.7% 
17.0% 

Year ended 
December 31, 

2018 

2017 

Current tax, from continuing operations .........................................................................  
Current tax, from discontinued operations ......................................................................  

       $       60,178  
                  3,410  

$      63,588      

     $     (35,702) 
               32,094 
    $         (3,608) 

Deferred tax, from continuing operations .......................................................................  
Deferred tax, from discontinued operations ....................................................................  

         $      (4,565)      
                 2,695           
      $     (1,870) 

     $     (22,502) 
            (9,445) 
     $    (31,947) 

Total current and deferred, from continuing operations .................................................  
Total current and deferred, from discontinued operations .............................................  

       $      55,613 
       $        6,105 

     $      (58,204) 
     $        22,649 

 The analysis of deferred tax assets and deferred tax liabilities is as follows: 

     Deferred tax assets: 

Deferred tax asset to be settled after more than 12 months ...................................  
Deferred tax asset to be settled within 12 months ...................................................  

    Deferred tax liabilities: 

Deferred tax liability to be settled after more than 12 months ................................  
Deferred tax liability to be settled within 12 months ...............................................  

$ 

33,274    
2,600   
$       35,874   

$       77,440   
200   
$       77,640   

$ 

70,021 
5,200 
$       75,221 

$       99,823 
1,000 
$     100,823 

Deferred tax liabilities, net ...............................................................................................  

$ 

41,766    

$ 

25,602 

The gross movement on the deferred income tax account is as follows: 

$ 

61,718 

$ 

(35,555) 

Opening balance ..................................................................................................................  
Effect of changes in foreign exchange rates ........................................................................  
Transfers to assets held for sale (note 8) ............................................................................  
Income statement recovery ................................................................................................  
Tax credit relating to components of other comprehensive income ..................................  
Closing balance ....................................................................................................................  

Year ended 
December 31, 

2018   
25,602   
(4,164)  
25,108   
(1,870)  
(2,910)  
41,766   

$ 

$ 

2017 
55,185 
2,388 
- 
(31,947) 
(24) 
25,602 

$ 

$ 

40 

Gibson Energy 

41 
89 

Consolidated Financial Statements

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
  
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

The  movement  in  the  significant  components  of  deferred  income  tax  assets  and  liabilities  during  the  year,  without  taking  into 
consideration the offsetting balances within the same tax jurisdiction, is as follows: 

23  Revenue 

Deferred tax assets 

At January 1, 2017 ..................................................  
(Charged) credited to the statement of operations
 .........................................................................  
Charged to other comprehensive income ..............  
Effect of changes in foreign exchange rates ...........  
At January 1, 2018 ..................................................  
(Charged) credited to the statement of operations
 .........................................................................  
Charged to other comprehensive income ..............  
Transfers from assets held for sale (note 8) ...........  
Effect of changes in foreign exchange rates ...........  
At December 31, 2018 ............................................  

Non-capital 
losses carried 
forward 

Asset 
retirement 
obligations 

Retirement 
benefit 
obligations 

Goodwill, 
Intangibles, 
and other 

Total 

  $  62,599 

  $ 20,279 

  $  1,369 

  $  29,453 

  $113,700 

(15,402) 
- 
(2,108) 
  $  45,089 
(15,692)  

820 
- 
(299) 
  $ 20,800 
3,618 

137 
24 
- 
  $  1,530 
(152) 

5,107 
- 
(826) 
  $  33,734 
6,205  

(9,338) 
24 
(3,233) 
  $101,153 
(6,021)  

-  
(9,175)  
1,750  
  $  21,972 

-  
(3,509)    
67 
  $ 20,976 

2,910  
-  
-  
  $  4,288 

-  

(23,913)    
2,890  
  $  18,916 

2,910  
(36,597)  
4,707 
  $ 66,152 

Deferred tax liabilities 

At January 1, 2017 .....................................................................  
Credited to the statement of operations ..................................  
Effect of changes in foreign exchange rates ..............................  
At January 1, 2018 .....................................................................  
Credited to the statement of operations ..................................  
Transfers to assets held for sale (note 8) ..................................  
Effect of changes in foreign exchange rates ..............................  
At December 31, 2018 ...............................................................  

Income tax losses carry forward 

Right-of-use 
asset, 
Property, 
Plant and 
Equipment 

  $ (151,559) 
23,305 
1,499 
  $ (126,755) 
7,891 
11,489 
(543) 
  $ (107,918) 

Goodwill, 
Intangibles, 
and other 

Total 

Infrastructure 

Logistics 

Wholesale 

Total 

  $ 

17,980   
(654)   

  $ (17,326)      $ (168,885) 
41,285 
845 
-      $ (126,755) 
-   
7,891 
11,489 
-   
-   
(543) 
-      $ (107,918) 

  $ 

At December 31, 2018 and 2017, the Company had losses available to offset income for tax purposes of $89.8 million and $174.9 
million, respectively. At December 31, 2018, the Company has $89.8 million of the losses available mainly in the U.S. that expire as 
follows: 

December 31, 2035 ........................................................................................................................................................  
December 31, 2036 ........................................................................................................................................................  
December 31, 2037 ........................................................................................................................................................  
December 31, 2038 ........................................................................................................................................................  

19,245 
64,568 
5,450 
537 
$  89,800 

No income tax liability has been recognized in respect of temporary differences associated with investments in subsidiaries, except 
for as disclosed in note 8 for assets held for sale, as the Company can control the timing of the reversal of the temporary difference 
and the reversal is not probable in the foreseeable future. 

Consolidated Financial Statements 

42 

90 

Gibson Energy

43 

Year ended 

December 31, 

2018 

20171 

Revenue from contracts with customers recognized at a point in time (2017 – Products) ....  

  $  6,559,568  

  $  5,395,472 

Revenue from contracts with customers recognized over time (2017 – Services) .................  

Total revenue from contracts with customers ...................... ………………………………………………. 

Total revenue from lease arrangements ............................... ………………………………………………. 

164,221  

6,723,789 

122,800 

264,174 

5,659,646 

- 

  $  6,846,589 

  $  5,659,646 

1.  Due to the adoption of IFRS 15 effective January 1, 2018 as discussed in note 4, the comparative information has not been restated and, 

therefore, the results may not be comparable. 

During the year ended December 31, 2018, the Company recognized $12.7 million of revenues which were included in the contract 

liability balance at the beginning of the period.   

Year ended December 31, 2018 

Canada 

External Service Revenue 

Terminals storage and throughput/pipeline 

transportation and services .....................................   

Rail services .............................................................  

PRD and other services ...........................................  

External Product Revenue 

Crude and diluent ...................................................  

Propane and other NGL ..........................................  

Refined products .....................................................  

  $      80,510     

$                   -

  $                     -

     $          80,510          

28,105

17,409

               -

                  -

2,899

4,616,627

368,006

224,882

-

-

28,105

20,308

4,616,627

368,006

224,882

6,675

Other .......................................................................  

               6,675

Total revenue – Canada .............................................  

$   132,699                 $                  -

$    5,212,414        $     5,345,113                   

U.S. 

External Service Revenue 

External Product Revenue 

Hauling and transportation and other services ....  

$        4,366                $       30,932                              

$                    -

$          35,298                                 

Crude and diluent .................................................  

Propane and other NGL ........................................  

Refined products ..................................................  

               -

                -

727,750

392,492

223,136

727,750

392,492

223,136

Total revenue – U.S.  ..................................................  

$       4,366                            

$       30,932                        

$    1,343,378                        

$     1,378,676                       

Total revenue from contract with customers ............    

$   137,065             $       30,932                $    6,555,792            $     6,723,789           

-

-

-

-

-

-

-

-

-

-

-

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Deferred tax assets 

Non-capital 

losses carried 

forward 

Asset 

retirement 

obligations 

Retirement 

benefit 

obligations 

Goodwill, 

Intangibles, 

and other 

Total 

At January 1, 2017 ..................................................  

  $  62,599 

  $ 20,279 

  $  1,369 

  $  29,453 

  $113,700 

(Charged) credited to the statement of operations

 .........................................................................  

(15,402) 

Charged to other comprehensive income ..............  

Effect of changes in foreign exchange rates ...........  

- 

(2,108) 

820 

- 

(299) 

137 

24 

- 

5,107 

- 

(826) 

(9,338) 

24 

(3,233) 

At January 1, 2018 ..................................................  

  $  45,089 

  $ 20,800 

  $  1,530 

  $  33,734 

  $101,153 

(Charged) credited to the statement of operations

(15,692)  

3,618 

(152) 

6,205  

(6,021)  

 .........................................................................  

Charged to other comprehensive income ..............  

Transfers from assets held for sale (note 8) ...........  

Effect of changes in foreign exchange rates ...........  

-  

(9,175)  

1,750  

(3,509)    

-  

67 

2,910  

-  

-  

-  

(23,913)    

2,890  

2,910  

(36,597)  

4,707 

At December 31, 2018 ............................................  

  $  21,972 

  $ 20,976 

  $  4,288 

  $  18,916 

  $ 66,152 

Right-of-use 

asset, 

Property, 

Plant and 

Equipment 

Goodwill, 

Intangibles, 

and other 

Deferred tax liabilities 

At January 1, 2017 .....................................................................  

  $ (151,559) 

  $ (17,326)      $ (168,885) 

At January 1, 2018 .....................................................................  

  $ (126,755) 

  $ 

-      $ (126,755) 

Credited to the statement of operations ..................................  

Effect of changes in foreign exchange rates ..............................  

Credited to the statement of operations ..................................  

Transfers to assets held for sale (note 8) ..................................  

Effect of changes in foreign exchange rates ..............................  

23,305 

1,499 

7,891 

11,489 

(543) 

17,980   

(654)   

-   

-   

-   

At December 31, 2018 ...............................................................  

  $ (107,918) 

  $ 

-      $ (107,918) 

Total 

41,285 

845 

7,891 

11,489 

(543) 

Income tax losses carry forward 

follows: 

At December 31, 2018 and 2017, the Company had losses available to offset income for tax purposes of $89.8 million and $174.9 

million, respectively. At December 31, 2018, the Company has $89.8 million of the losses available mainly in the U.S. that expire as 

December 31, 2035 ........................................................................................................................................................  

December 31, 2036 ........................................................................................................................................................  

December 31, 2037 ........................................................................................................................................................  

December 31, 2038 ........................................................................................................................................................  

19,245 

64,568 

5,450 

537 

$  89,800 

No income tax liability has been recognized in respect of temporary differences associated with investments in subsidiaries, except 

for as disclosed in note 8 for assets held for sale, as the Company can control the timing of the reversal of the temporary difference 

and the reversal is not probable in the foreseeable future. 

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

The  movement  in  the  significant  components  of  deferred  income  tax  assets  and  liabilities  during  the  year,  without  taking  into 

23  Revenue 

consideration the offsetting balances within the same tax jurisdiction, is as follows: 

Revenue from contracts with customers recognized at a point in time (2017 – Products) ....  
Revenue from contracts with customers recognized over time (2017 – Services) .................  
Total revenue from contracts with customers ...................... ………………………………………………. 
Total revenue from lease arrangements ............................... ………………………………………………. 

Year ended 
December 31, 

2018 

20171 

  $  6,559,568  
164,221  
6,723,789 
122,800 
  $  6,846,589 

  $  5,395,472 
264,174 
5,659,646 
- 
  $  5,659,646 

1.  Due to the adoption of IFRS 15 effective January 1, 2018 as discussed in note 4, the comparative information has not been restated and, 

therefore, the results may not be comparable. 

During the year ended December 31, 2018, the Company recognized $12.7 million of revenues which were included in the contract 
liability balance at the beginning of the period.   

Year ended December 31, 2018 

Infrastructure 

Logistics 

Wholesale 

Total 

Canada 
External Service Revenue 

Terminals storage and throughput/pipeline 
transportation and services .....................................   
Rail services .............................................................  
PRD and other services ...........................................  

External Product Revenue 

  $      80,510     

28,105
17,409

$                   -
-
-

  $                     -
-
2,899

Crude and diluent ...................................................  
Propane and other NGL ..........................................  
Refined products .....................................................  
Other .......................................................................  
Total revenue – Canada .............................................  

               -
-
-
               6,675

                  -
-
-
-
$   132,699                 $                  -

U.S. 
External Service Revenue 

     $          80,510          

28,105
20,308

4,616,627
368,006
224,882
6,675

4,616,627
368,006
224,882
-

$    5,212,414        $     5,345,113                   

Hauling and transportation and other services ....  

$        4,366                $       30,932                              

$                    -

$          35,298                                 

External Product Revenue 

Crude and diluent .................................................  
Propane and other NGL ........................................  
Refined products ..................................................  
Total revenue – U.S.  ..................................................  
Total revenue from contract with customers ............    

               -
-
-

                -
-
-
$       30,932                        

727,750
392,492
223,136

727,750
392,492
223,136

$       4,366                            
$   137,065             $       30,932                $    6,555,792            $     6,723,789           

$    1,343,378                        

$     1,378,676                       

42 

Gibson Energy 

43 
91 

Consolidated Financial Statements

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

24  Depreciation, amortization and impairment 

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Compensation of key management 

Depreciation and impairment of property, plant and equipment (note 10) ........................  
Depreciation of right-of-use asset (note 11) ........................................................................  
Amortization and impairment of intangible assets (note 13)...............................................  

Year ended 
December 31, 

2018 

2017 

  $ 
 143,160 
             43,184 
10,870  
197,214  

  $ 

  $ 
100,837 
                       - 
23,340 
124,177 

  $ 

Depreciation and impairment of property, plant and equipment, right-of-use asset and amortization and impairment of intangible 
assets have been expensed as follows: 

Cost of sales ..........................................................................................................................  
General and administrative ..................................................................................................  

25  Employee salaries and benefits 

Salaries and wages ................................................................................................................  
Post-employment benefits ...................................................................................................  
Share based compensation ..................................................................................................  
Termination benefits and restructuring costs ......................................................................  

Employee salaries and benefits have been expensed as follows: 

Cost of sales ..........................................................................................................................  
General and administrative ..................................................................................................  

Year ended 
December 31, 

2018 

2017 

  $ 

  $ 

179,986   
 17,228   
197,214   

  $ 

  $ 

112,308  
 11,869 
124,177 

Year ended 
December 31, 

2018 

2017 

  $ 

  $ 

98,037  
4,910 
19,124 
2,608 
124,679  

  $ 

  $ 

103,728 
4,972 
23,244 
16,786 
148,730 

Year ended 
December 31, 
2018 

2017 

  $ 

  $ 

86,825  
37,854 
124,679  

  $ 

  $ 

108,464 
40,266 
148,730 

Key management includes the Company’s directors, executive officers, business unit leaders and other non-business unit senior vice 

presidents. Compensation awarded to key management was: 

Salaries and short-term employee benefits .........................................................................  

  $ 

  $ 

Post-employment benefits ...................................................................................................  

Share based compensation ..................................................................................................  

Termination costs .................................................................................................................  

26  Other operating income 

Sublease income   .................................................................................................................  

$         (3,670) 

$                   - 

Loss on sale of net assets held for sale (note 8)  ..................................................................  

Other income   ......................................................................................................................  

4,974 

(3,395) 

(2,091) 

  $ 

  $ 

- 

(1,423) 

(1,423) 

27  Per share amounts  

The following table shows the number of shares used in the calculation of earnings per share for continuing operations: 

Year ended 

December 31, 

2018 

6,047  

311 

6,886 

62 

2017 

5,852 

 1,094 

8,191 

3,967 

  $ 

13,306  

  $ 

19,104 

Year ended 

December 31, 

2018 

2017 

Year ended 

December 31, 

2018 

2017 

Weighted average common shares outstanding – Basic ......................................................  

143,970,969 

142,500,793 

Dilutive effect of: 

Stock options and other awards ....................................................................................  

Weighted average common shares – Diluted ......................................................................  

2,506,591 

146,477,560 

- 

142,500,793 

The dilutive effect of 2.5 million stock options and other awards, and the potential common stock that would be issued upon the 

conversion of the Debentures for the year ended December 31, 2018 have been included in the determination of the weighted 

average number of common shares outstanding for continuing and discontinued operations.  The impact of 1.1 million stock options 

have not been included in the determination of weighted average number of common shares outstanding as the inclusion would be 

anti-dilutive to the net income from continuing and discontinued operations per share.  

The dilutive effect of 3.0 million stock options and other awards, and the potential common stock that would be issued upon the 

conversion of the Debentures for the year ended December 31, 2017 have not been included in the determination of the weighted 

average number of common shares outstanding as the inclusion would be anti-dilutive to the net loss from continuing operations 

per share. The dilutive effect of 3.0 million stock options and other awards, and the potential common stock that would be issued 

upon the conversion of the Debentures for the year ended December 31, 2017 have been included in the determination of the 

weighted average number of common shares outstanding for discontinued operations per share. 

Consolidated Financial Statements 

44 

92 

Gibson Energy

45 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

24  Depreciation, amortization and impairment 

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Compensation of key management 

Key management includes the Company’s directors, executive officers, business unit leaders and other non-business unit senior vice 
presidents. Compensation awarded to key management was: 

Depreciation and impairment of property, plant and equipment (note 10) ........................  

Depreciation of right-of-use asset (note 11) ........................................................................  

  $ 

 143,160 

             43,184 

Amortization and impairment of intangible assets (note 13)...............................................  

10,870  

  $ 

100,837 

                       - 

23,340 

  $ 

197,214  

  $ 

124,177 

Salaries and short-term employee benefits .........................................................................  
Post-employment benefits ...................................................................................................  
Share based compensation ..................................................................................................  
Termination costs .................................................................................................................  

Depreciation and impairment of property, plant and equipment, right-of-use asset and amortization and impairment of intangible 

assets have been expensed as follows: 

26  Other operating income 

Cost of sales ..........................................................................................................................  

General and administrative ..................................................................................................  

25  Employee salaries and benefits 

Sublease income   .................................................................................................................  
Loss on sale of net assets held for sale (note 8)  ..................................................................  
Other income   ......................................................................................................................  

27  Per share amounts  

Year ended 
December 31, 
2018 

  $ 

  $ 

6,047  
311 
6,886 
62 
13,306  

  $ 

  $ 

2017 

5,852 
 1,094 
8,191 
3,967 
19,104 

Year ended 
December 31, 

2018 

2017 

$         (3,670) 
4,974 
(3,395) 
(2,091) 

  $ 

$                   - 
- 
(1,423) 
(1,423) 

  $ 

Salaries and wages ................................................................................................................  

  $ 

  $ 

103,728 

Post-employment benefits ...................................................................................................  

Share based compensation ..................................................................................................  

Termination benefits and restructuring costs ......................................................................  

Employee salaries and benefits have been expensed as follows: 

Cost of sales ..........................................................................................................................  

  $ 

General and administrative ..................................................................................................  

The following table shows the number of shares used in the calculation of earnings per share for continuing operations: 

Year ended 
December 31, 

2018 

2017 

Weighted average common shares outstanding – Basic ......................................................  
Dilutive effect of: 

Stock options and other awards ....................................................................................  
Weighted average common shares – Diluted ......................................................................  

143,970,969 

142,500,793 

2,506,591 
146,477,560 

- 
142,500,793 

The dilutive effect of 2.5 million stock options and other awards, and the potential common stock that would be issued upon the 
conversion of the Debentures for the year ended December 31, 2018 have been included in the determination of the weighted 
average number of common shares outstanding for continuing and discontinued operations.  The impact of 1.1 million stock options 
have not been included in the determination of weighted average number of common shares outstanding as the inclusion would be 
anti-dilutive to the net income from continuing and discontinued operations per share.  

The dilutive effect of 3.0 million stock options and other awards, and the potential common stock that would be issued upon the 
conversion of the Debentures for the year ended December 31, 2017 have not been included in the determination of the weighted 
average number of common shares outstanding as the inclusion would be anti-dilutive to the net loss from continuing operations 
per share. The dilutive effect of 3.0 million stock options and other awards, and the potential common stock that would be issued 
upon the conversion of the Debentures for the year ended December 31, 2017 have been included in the determination of the 
weighted average number of common shares outstanding for discontinued operations per share. 

Year ended 

December 31, 

2018 

2017 

Year ended 

December 31, 

2018 

2017 

  $ 

  $ 

179,986   

 17,228   

197,214   

  $ 

112,308  

 11,869 

124,177 

  $ 

Year ended 

December 31, 

2018 

2017 

98,037  

4,910 

19,124 

2,608 

4,972 

23,244 

16,786 

  $ 

124,679  

  $ 

148,730 

Year ended 

December 31, 

2018 

2017 

86,825  

37,854 

  $ 

124,679  

  $ 

  $ 

108,464 

40,266 

148,730 

44 

Gibson Energy 

45 
93 

Consolidated Financial Statements

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

28  Post-retirement benefits    

Defined benefit plans 

The Company maintains a funded defined benefit pension plan and an unfunded defined benefit other post-retirement benefits plan 
(“OPRB”). 

The Company’s defined benefit pension plans are funded based upon the advice of independent actuaries. The Company is required 
to file an actuarial valuation of the defined benefit pension plan with the provincial regulator every three years, with the most recent 
actuarial valuation filing as at December 31, 2016. Based on the actuarial valuations as at December 31, 2018 and 2017, the status 
of the defined benefit plans was as follows: 

Accrued benefit obligation 

Year ended 
December 31, 

2018 

2017 

Pension 

OPRB 

Pension 

OPRB 

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

The significant weighted average actuarial assumptions adopted in measuring the Company’s defined benefit plan obligation are as 

follows: 

Year ended 

December 31, 

2018 

2017 

Discount rate .........................................................................................................................................  

Rate of compensation increase ............................................................................................................  

3.75%   

3.0%   

3.50% 

3.0% 

The assumed discount rate has an effect on the amounts reported for the defined benefit plan obligations. A one-percentage point 

change in the discount rate would have the following impact:  

One % point 

One % point 

increase 

decrease 

Increase/(decrease) in defined benefit plans obligations ..................................................................  

  $ 

(4,286)  

  $ 

5,458 

Accrued benefit obligation, beginning of year .........................................................  
Current service cost ...........................................................................................   
Interest cost .......................................................................................................  
Benefits paid ......................................................................................................  
Actuarial loss (gain) ...........................................................................................  
Other ..................................................................................................................  
Accrued benefit obligation, end of year ...................................................................  

   $   16,317  $    4,758   
             62 
      1,350   
           528           235   
         (655)         (445)   
         (633)        9,300   
         (952)                - 
   $   14,667  $  15,198   

     $  16,869 $      4,612
146
53
-
584
-
(1,886)
-
693
4
-
     $  16,317    $     4,758

Defined contribution pension plan 

respectively.  

29  Share based compensation  

The Company operates defined contribution plans whereby, in some cases, contributions made by participants are matched by the 

Company up to specified annual limits and in other cases, contributions are fully funded by the Company. The total expense recorded 

for  the  defined  contribution  pension  plans  was  $4.2  million  and  $4.7  million  for  the  year  ended  December  31,  2018  and  2017, 

Plan assets 

Year ended 
December 31, 

2018 

2017 

Pension 

OPRB 

Pension 

OPRB 

Fair value of pension plan assets, beginning of year ................................................  
Interest on plan assets .......................................................................................  
Actual contributions ..........................................................................................  
Actual benefits paid ...........................................................................................  
Actuarial gain (loss) ...........................................................................................  
Other ..................................................................................................................  
Fair value of pension plan assets, end of year ..........................................................  

  $      15,404   $         - 
484             - 
871         445   
(655)       (445)   

(1,068)             - 
(1,589)             - 
 $      13,447   $         - 

     $  16,126
528
613
(2,466)
603
-
     $  15,404

$           -
             -
             -
             -
             -
             -
   $           -

Accrued benefit liability 

Year ended 
December 31, 

2018 

2017 

Pension 

OPRB 

Pension 

OPRB 

Accrued benefit obligation .......................................................................................   $   (14,667)  $ (15,198)  
     13,447 
Fair value of plan assets ............................................................................................  
               - 
$    (1,220)  $ (15,198)  
Accrued benefit liability ............................................................................................  

   $ (16,317) $    (4,758)
         15,404 
-
  (913)    $    (4,758)
  $  

The Company has established an equity incentive plan which permits the award of stock options, RSUs, PSUs and DSUs for executives, 

directors,  employees  and  consultants  of  the  Company.  Stock  options  provide  the  holder  with  the  right  to  exercise  an  option  to 

purchase a common share, upon vesting, at a price determined on the date of grant. RSUs give the holder the right to receive, upon 

vesting, either a common share or a cash payment, subject to consent of the Board, or its equivalent in fully paid common shares 

equal to the fair market value of the Company’s common shares at the date of such payment. The RSUs granted in 2018 and 2017 

were expected to be settled by delivery of common shares and accordingly, were considered an equity–settled award for accounting 

purposes.  Stock options and  RSUs granted generally  vest  equally each year over a three year period. RSUs granted with specific 

performance criteria are designated as PSUs. PSU’s vest at the end of the three year period and granting depends on the achievement 

of certain performance criteria. DSUs are similar to RSUs except that DSUs may not be redeemed until the holder ceases to hold all 

offices, employment and directorships.  

At December 31, 2018, awards available to grant under the equity incentive plan totalled approximately 10.1 million. 

Consolidated Financial Statements 

46 

94 

Gibson Energy

47 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
                
 
 
 
 
 
 
 
 
   
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

The significant weighted average actuarial assumptions adopted in measuring the Company’s defined benefit plan obligation are as 
follows: 

Discount rate .........................................................................................................................................  
Rate of compensation increase ............................................................................................................  

3.75%   
3.0%   

Year ended 
December 31, 
2018 

2017 

3.50% 
3.0% 

The assumed discount rate has an effect on the amounts reported for the defined benefit plan obligations. A one-percentage point 
change in the discount rate would have the following impact:  

One % point 
increase 

One % point 
decrease 

Increase/(decrease) in defined benefit plans obligations ..................................................................  

  $ 

(4,286)  

  $ 

5,458 

Accrued benefit obligation, beginning of year .........................................................  

   $   16,317  $    4,758   

     $  16,869 $      4,612

Defined contribution pension plan 

The Company operates defined contribution plans whereby, in some cases, contributions made by participants are matched by the 
Company up to specified annual limits and in other cases, contributions are fully funded by the Company. The total expense recorded 
for  the  defined  contribution  pension  plans  was  $4.2  million  and  $4.7  million  for  the  year  ended  December  31,  2018  and  2017, 
respectively.  

29  Share based compensation  

The Company has established an equity incentive plan which permits the award of stock options, RSUs, PSUs and DSUs for executives, 
directors,  employees  and  consultants  of  the  Company.  Stock  options  provide  the  holder  with  the  right  to  exercise  an  option  to 
purchase a common share, upon vesting, at a price determined on the date of grant. RSUs give the holder the right to receive, upon 
vesting, either a common share or a cash payment, subject to consent of the Board, or its equivalent in fully paid common shares 
equal to the fair market value of the Company’s common shares at the date of such payment. The RSUs granted in 2018 and 2017 
were expected to be settled by delivery of common shares and accordingly, were considered an equity–settled award for accounting 
purposes.  Stock options and  RSUs granted generally  vest  equally each year over a three year period. RSUs granted with specific 
performance criteria are designated as PSUs. PSU’s vest at the end of the three year period and granting depends on the achievement 
of certain performance criteria. DSUs are similar to RSUs except that DSUs may not be redeemed until the holder ceases to hold all 
offices, employment and directorships.  

At December 31, 2018, awards available to grant under the equity incentive plan totalled approximately 10.1 million. 

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

28  Post-retirement benefits    

Defined benefit plans 

(“OPRB”). 

The Company maintains a funded defined benefit pension plan and an unfunded defined benefit other post-retirement benefits plan 

The Company’s defined benefit pension plans are funded based upon the advice of independent actuaries. The Company is required 

to file an actuarial valuation of the defined benefit pension plan with the provincial regulator every three years, with the most recent 

actuarial valuation filing as at December 31, 2016. Based on the actuarial valuations as at December 31, 2018 and 2017, the status 

of the defined benefit plans was as follows: 

Accrued benefit obligation 

Year ended 

December 31, 

2018 

2017 

Pension 

OPRB 

Pension 

OPRB 

Current service cost ...........................................................................................   

             62 

      1,350   

Interest cost .......................................................................................................  

           528           235   

Benefits paid ......................................................................................................  

         (655)         (445)   

(1,886)

Actuarial loss (gain) ...........................................................................................  

         (633)        9,300   

Other ..................................................................................................................  

         (952)                - 

53

584

693

4

146

-

-

-

-

Accrued benefit obligation, end of year ...................................................................  

   $   14,667  $  15,198   

     $  16,317    $     4,758

Year ended 

December 31, 

2018 

2017 

Pension 

OPRB 

Pension 

OPRB 

Fair value of pension plan assets, beginning of year ................................................  

  $      15,404   $         - 

     $  16,126

Interest on plan assets .......................................................................................  

Actual contributions ..........................................................................................  

Actual benefits paid ...........................................................................................  

Actuarial gain (loss) ...........................................................................................  

Other ..................................................................................................................  

484             - 

871         445   

(655)       (445)   

(1,068)             - 

(1,589)             - 

(2,466)

528

613

603

-

$           -

             -

             -

             -

             -

             -

Fair value of pension plan assets, end of year ..........................................................  

 $      13,447   $         - 

     $  15,404

   $           -

Plan assets 

Accrued benefit liability 

Year ended 

December 31, 

2018 

2017 

Pension 

OPRB 

Pension 

OPRB 

Accrued benefit obligation .......................................................................................   $   (14,667)  $ (15,198)  

   $ (16,317) $    (4,758)

Fair value of plan assets ............................................................................................  

     13,447 

               - 

         15,404 

-

Accrued benefit liability ............................................................................................  

$    (1,220)  $ (15,198)  

  $  

  (913)    $    (4,758)

46 

Gibson Energy 

47 
95 

Consolidated Financial Statements

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
                
 
 
 
 
 
 
 
 
   
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

A summary of stock option activity is as follows: 

Number of Shares 

Weighted-Average 
Exercise Price 
(in dollars) 

Balance at January 1, 2017 ............................................................................................  
Granted ...................................................................................................................  
Exercised .................................................................................................................  
Forfeited .................................................................................................................  
Balance at December 31, 2017 ......................................................................................  
Granted ...................................................................................................................  
Exercised .................................................................................................................  
Forfeited .................................................................................................................  
Balance at December 31, 2018 ......................................................................................  
Vested and exercisable at December 31, 2018 .............................................................  
Vested and exercisable at December 31, 2017 .............................................................  

3,067,865 
1,191,571 
(323,625) 
(639,096) 
3,296,715 
126,939 
(104,897) 
(1,035,140) 
2,283,617 
1,520,569 
2,046,485 

$ 

$ 

$ 
$ 
$ 

24.24 
17.48 
8.72 
26.45 
22.89 
16.70 
10.07 
26.77 
21.39  
 23.40 
25.89 

Additional information regarding stock options outstanding as of December 31, 2018 is as follows: 

Outstanding 
Weighted Average 
Remaining 
Contractual Life 
(Years) 
4.2 
3.6 
0.5 
2.4 
3.2 
1.4 
2.2 
2.8 
3.1 

Number 
Outstanding 
116,157 
1,186,292 
30,123 
32,791 
295,122 
216,550 
392,034 
14,548 
2,283,617 

  $ 

Exercise 
Price 
(in dollars) 
16.70 
17.41 
22.03 
23.83 
25.32 
25.99 
28.54 
35.51 

A summary of RSUs, PSUs and DSUs activity is set forth below: 

Exercisable 
Weighted-Average 
Remaining 
Contractual Life 
(Years) 
4.2 
3.6 
0.5 
2.4 
3.2 
1.4 
2.2 
2.8 
2.8 

Number 
Outstanding 
116,157 
423,244 
30,123 
32,791 
295,122 
216,550 
392,034 
14,548 
1,520,569 

  $ 

Exercise 
Price 
(in dollars) 
16.70 
17.45 
22.03 
23.83 
25.32 
25.99 
28.54 
35.51 

Balance at January 1, 2017 ...........................................................................  
Granted .................................................................................................  
Issued for common shares ....................................................................  
Forfeited ................................................................................................  
Balance at December 31, 2017 .....................................................................  
Granted .................................................................................................  
Issued for common shares ....................................................................  
Forfeited ................................................................................................  
Balance at December 31, 2018 .....................................................................  
Vested, Balance at December 31, 2018........................................................  
Vested, Balance at December 31, 2017........................................................  

RSUs 
1,112,791 
876,261 
(830,803) 
(220,948) 
937,301 
692,210 
(641,811) 
(220,145) 
767,555 
- 
24,492 

Number of Shares 

PSUs 

1,530,320   
535,921 
(295,283) 
(740,123) 
1,030,835 
617,802 
(381,536) 
(519,716) 
747,385 

-   
-     

DSUs 
196,582 
330,756 
(21,646) 
- 
505,692 
237,895 
(226,148) 
(1,091) 
516,348 
516,348 
505,692 

Share  based  compensation  expense  was  $17.7  million  and  $22.1  million  for  the  years  ended  December  31,  2018  and  2017, 
respectively, and is included in general and administrative expenses. 

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

The fair value of the options granted was estimated at $1.99 and $2.36 per option for the year ended December 31, 2018 and 2017. 

The fair value of options was calculated by using the Black-Scholes model with the following weighted average assumptions: 

Expected dividend rate .............................................................................................................  

Expected volatility ....................................................................................................................  

Risk-free interest rate ...............................................................................................................  

Expected life of option (years) ..................................................................................................  

The fair value of RSUs, PSUs and DSUs was determined using the five days weighted average stock price prior to the date of grant. 

Year ended 

December 31, 

Year ended 

December 31, 

2018 

7.9% 

31.7% 

1.9% 

3.0 

2017 

7.7% 

35.3% 

1.1% 

3.0 

30  Financial instruments  

Non-Derivative financial instruments   

Non-derivative financial instruments comprise cash and cash equivalents, trade and other receivables, net investment in finance 

lease, trade payables and accrued charges, amounts borrowed under the credit facilities, dividends payable, Debentures and long-

term debt.  

Cash and cash equivalents, trade and other receivables, trade payables and accrued charges and dividends payable are recorded at 

amortized cost which approximates fair value due to the short term nature of these instruments.  

Long-term debt including credit facility are recorded at amortized cost using the effective interest method of amortization. As at 

December 31, 2018, the carrying amount of long-term debt was $1,050.0 million less debt discount and issue costs of $10.4 million 

and the fair value of long-term debt based on period end trading prices on the secondary market (Level 2) was $1,038.6 million. As 

at December 31, 2017, the carrying amount of long-term debt was $1,130.2 million less debt discount and issue costs of $12.1 million 

and the fair value of long-term debt based on period end trading prices on the secondary market (Level 2) was $1,144.1 million.  

The  Debentures  liability  component  is  recorded  at  amortized  cost  using  the  effective  interest  method  of  amortization.  As  at 

December 31, 2018, the total carrying amount of the debentures liability and equity components was $100.0 million less debt 

discount and issue costs of $2.5 million, less deferred taxes relating to the equity component of $2.8 million. The fair value of the 

Debentures based on period end trading prices on the secondary market (Level 2) was $98.1 million (December 31, 2017 – $105.0 

million). 

Financial assets and liabilities are only offset if the Company has the current legal right to offset and intends to settle on a net basis 

or settle the asset and liability simultaneously. The following table provides a summary of the Company’s offsetting trade and other 

receivables and trade payables and accrued charges:   

December 31, 

2018 

December 31, 

2017 

Trade and 

other 

receivables 

Trade payable 

and accrued 

charges 

Trade and 

other 

receivables 

Trade 

payable and 

accrued 

charges 

Gross amounts ...................................................................  

   $     139,239   

  $     112,059  

  $  530,965   

  $  433,272 

Amount offset ...................................................................  

(90,573) 

(90,573) 

(340,589) 

(340,589) 

Net amount included in the consolidated 

financial statements.......................................................     $      48,666  

    $      21,486  

  $  190,376 

    $ 

92,683 

Consolidated Financial Statements 

48 

96 

Gibson Energy

49 

 
  
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

A summary of stock option activity is as follows: 

Number of Shares 

Weighted-Average 

Exercise Price 

(in dollars) 

Balance at January 1, 2017 ............................................................................................  

Granted ...................................................................................................................  

Exercised .................................................................................................................  

Forfeited .................................................................................................................  

Balance at December 31, 2017 ......................................................................................  

Granted ...................................................................................................................  

Exercised .................................................................................................................  

Forfeited .................................................................................................................  

Balance at December 31, 2018 ......................................................................................  

Vested and exercisable at December 31, 2018 .............................................................  

Vested and exercisable at December 31, 2017 .............................................................  

3,067,865 

1,191,571 

(323,625) 

(639,096) 

3,296,715 

126,939 

(104,897) 

(1,035,140) 

2,283,617 

1,520,569 

2,046,485 

$ 

$ 

$ 

$ 

$ 

24.24 

17.48 

8.72 

26.45 

22.89 

16.70 

10.07 

26.77 

21.39  

 23.40 

25.89 

Additional information regarding stock options outstanding as of December 31, 2018 is as follows: 

Outstanding 

Weighted Average 

Remaining 

Contractual Life 

(Years) 

Exercise 

Price 

(in dollars) 

  $ 

16.70 

17.41 

22.03 

23.83 

25.32 

25.99 

28.54 

35.51 

4.2 

3.6 

0.5 

2.4 

3.2 

1.4 

2.2 

2.8 

3.1 

Number 

Outstanding 

116,157 

1,186,292 

30,123 

32,791 

295,122 

216,550 

392,034 

14,548 

2,283,617 

A summary of RSUs, PSUs and DSUs activity is set forth below: 

Exercisable 

Weighted-Average 

Remaining 

Contractual Life 

(Years) 

Exercise 

Price 

(in dollars) 

  $ 

16.70 

17.45 

22.03 

23.83 

25.32 

25.99 

28.54 

35.51 

4.2 

3.6 

0.5 

2.4 

3.2 

1.4 

2.2 

2.8 

2.8 

Number 

Outstanding 

116,157 

423,244 

30,123 

32,791 

295,122 

216,550 

392,034 

14,548 

1,520,569 

Balance at January 1, 2017 ...........................................................................  

1,112,791 

Granted .................................................................................................  

Issued for common shares ....................................................................  

Forfeited ................................................................................................  

Balance at December 31, 2017 .....................................................................  

Granted .................................................................................................  

Issued for common shares ....................................................................  

Forfeited ................................................................................................  

Balance at December 31, 2018 .....................................................................  

Vested, Balance at December 31, 2018........................................................  

Vested, Balance at December 31, 2017........................................................  

RSUs 

876,261 

(830,803) 

(220,948) 

937,301 

692,210 

(641,811) 

(220,145) 

767,555 

- 

24,492 

Number of Shares 

PSUs 

1,530,320   

535,921 

(295,283) 

(740,123) 

1,030,835 

617,802 

(381,536) 

(519,716) 

747,385 

-   

-     

DSUs 

196,582 

330,756 

(21,646) 

- 

505,692 

237,895 

(226,148) 

(1,091) 

516,348 

516,348 

505,692 

Share  based  compensation  expense  was  $17.7  million  and  $22.1  million  for  the  years  ended  December  31,  2018  and  2017, 

respectively, and is included in general and administrative expenses. 

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

The fair value of the options granted was estimated at $1.99 and $2.36 per option for the year ended December 31, 2018 and 2017. 
The fair value of options was calculated by using the Black-Scholes model with the following weighted average assumptions: 

Expected dividend rate .............................................................................................................  
Expected volatility ....................................................................................................................  
Risk-free interest rate ...............................................................................................................  
Expected life of option (years) ..................................................................................................  

Year ended 
December 31, 
2018 
7.9% 
31.7% 
1.9% 
3.0 

Year ended 
December 31, 
2017 
7.7% 
35.3% 
1.1% 
3.0 

The fair value of RSUs, PSUs and DSUs was determined using the five days weighted average stock price prior to the date of grant. 

30  Financial instruments  

Non-Derivative financial instruments   

Non-derivative financial instruments comprise cash and cash equivalents, trade and other receivables, net investment in finance 
lease, trade payables and accrued charges, amounts borrowed under the credit facilities, dividends payable, Debentures and long-
term debt.  

Cash and cash equivalents, trade and other receivables, trade payables and accrued charges and dividends payable are recorded at 
amortized cost which approximates fair value due to the short term nature of these instruments.  

Long-term debt including credit facility are recorded at amortized cost using the effective interest method of amortization. As at 
December 31, 2018, the carrying amount of long-term debt was $1,050.0 million less debt discount and issue costs of $10.4 million 
and the fair value of long-term debt based on period end trading prices on the secondary market (Level 2) was $1,038.6 million. As 
at December 31, 2017, the carrying amount of long-term debt was $1,130.2 million less debt discount and issue costs of $12.1 million 
and the fair value of long-term debt based on period end trading prices on the secondary market (Level 2) was $1,144.1 million.  

The  Debentures  liability  component  is  recorded  at  amortized  cost  using  the  effective  interest  method  of  amortization.  As  at 
December 31, 2018, the total carrying amount of the debentures liability and equity components was $100.0 million less debt 
discount and issue costs of $2.5 million, less deferred taxes relating to the equity component of $2.8 million. The fair value of the 
Debentures based on period end trading prices on the secondary market (Level 2) was $98.1 million (December 31, 2017 – $105.0 
million). 

Financial assets and liabilities are only offset if the Company has the current legal right to offset and intends to settle on a net basis 
or settle the asset and liability simultaneously. The following table provides a summary of the Company’s offsetting trade and other 
receivables and trade payables and accrued charges:   

December 31, 
2018 

December 31, 
2017 

Trade and 
other 
receivables 

Trade payable 
and accrued 
charges 

Trade and 
other 
receivables 

Trade 
payable and 
accrued 
charges 

Gross amounts ...................................................................  
Amount offset ...................................................................  
Net amount included in the consolidated 

   $     139,239   
(90,573) 

  $     112,059  
(90,573) 

  $  530,965   
(340,589) 

  $  433,272 
(340,589) 

financial statements.......................................................     $      48,666  

    $      21,486  

  $  190,376 

    $ 

92,683 

48 

Gibson Energy 

49 
97 

Consolidated Financial Statements

 
  
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Derivative financial instruments (recurring fair value measurements) 

The following is a summary of the Company’s risk management contracts outstanding: 

December 31, 
2018 

December 31, 
2017 

Assets 

Liabilities 

Assets 

Liabilities 

Commodity futures ...............................................................     $      1,937  
2,565 
Commodity swaps .................................................................  
677 
Equity swaps ..........................................................................  
504 
Foreign currency forwards ....................................................  
Total .......................................................................................     $      5,683  
Less non-current portion: 

    $         616   
2,887   
2,915   
1,451   
  $      7,869    

  $ 

  $ 

Commodity futures ........................................................  
Commodity swaps ..........................................................  
Equity swaps ...................................................................  
Foreign currency forwards .............................................  

Current portion......................................................................     $ 

- 
- 
- 
- 
- 
5,683  

  $ 

-   
-   
154   
-   
154   
7,715   

  $ 

384 
4,808 
324 
1,883 
7,399 

384 
567 
294 
122 
1,367 
6,032 

  $ 

6,257 
2,214 
3,297 
- 
  $  11,768 

215 
- 
277 
- 
492 
  $  11,276 

The fair value of financial instruments is classified as a non-current asset (long-term prepaid expense and other assets) or liability 
(other long-term liabilities) if the remaining maturity is more than 12 months and, as a current asset or liability, if the maturity is less 
than 12 months. 

(i)  Commodity financial instruments 

Futures, options and swaps 

The Company enters into futures, options and swap contracts to manage the price risk associated with sales, purchases and 
inventories of crude oil, natural gas liquids and petroleum products.  

During the year ended December 31, 2018, the Company entered into certain WTI differential futures to manage the exposure 
to price risks associated with the purchases of crude oil feedstock.  

(ii)  Currency financial instruments 

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

The value of the Company’s derivative financial instruments is determined using inputs that are either readily available in public 

markets or are quoted by counterparties to these contracts. In situations where the Company obtains inputs via quotes from its 

counterparties, these quotes are verified for reasonableness via similar quotes from another source for each date for which financial 

statements  are  presented.  The  Company  has  consistently  applied  these  valuation  techniques  in  all  periods  presented  and  the 

Company believes it has obtained the most accurate information available for the types of financial instrument contracts held. The 

Company has categorized the inputs  for these  contracts  as Level 1, defined as observable inputs  such as quoted prices in active 

markets; Level 2 defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; or 

Level 3  defined  as  unobservable  inputs  in  which  little  or  no  market  data  exists  therefore  requiring  an  entity  to  develop  its  own 

assumptions.  

 

 

The Company used the following techniques to value financial instruments categorized in Level 2: 

The fair value of commodity swaps is calculated as the present value of the estimated future cash flows based on the difference 

between contract price and commodity price forecast.  

The fair value of foreign currency forward contracts is determined using the forward exchange rates at the measurement date, 

with the resulting value discounted back to present values. 

The fair value of financial instrument contracts by fair value hierarchy at December 31, 2018 was: 

Assets from financial instrument contracts 

Commodity futures ..................................................................  

  $  1,937  

  $  1,937 

  $ 

 $ 

Commodity swaps ....................................................................  

Equity swaps .............................................................................  

Foreign currency forwards .......................................................  

2,565 

677 

504 

677 

- 

- 

Total assets ...............................................................................  

  $  5,683  

  $  2,614 

  $  3,069 

 $ 

Total 

Level 1 

Level 2 

Level 3 

Liabilities from financial instrument contracts 

Commodity futures ..................................................................  

  $ 

616  

  $ 

561 

  $ 

 $ 

Commodity swaps ....................................................................  

Equity swaps .............................................................................  

Foreign currency forwards .......................................................  

2,887 

2,915 

1,451 

2,915 

- 

- 

Total liabilities ..........................................................................  

  $  7,869  

  $  3,476 

  $  4,393 

 $ 

The Company enters into forward and options contracts to buy and sell U.S. dollars in exchange for Canadian dollars to fix the 
exchange rate on its estimated future net cash inflows denominated in U.S. dollars and long-term borrowings denominated in 
U.S. dollars.  

There were no contracts entered into during the year ended December 31, 2018. 

During the year ended December 31, 2017, the Company entered into U.S. dollar forward contracts to buy U.S. dollars on a 
notional amount of US$480.0 million at a weighted average rate of $1.33 for US$1.00 which settled on March 22, 2017 and on 
October 5, 2017. The overall value of the U.S. dollar forward contracts settlement was $2.2 million loss during the year ended 
December 31, 2017. 

The fair value of financial instrument contracts by fair value hierarchy at December 31, 2017 was: 

Assets from financial instrument contracts 

Commodity futures ..................................................................  

  $ 

384  

  $ 

384 

  $ 

 $ 

Commodity swaps ....................................................................  

Equity swaps .............................................................................  

Foreign currency forwards .......................................................  

4,808 

324 

1,883 

324 

- 

- 

4,808 

1,883 

Total assets ...............................................................................  

  $  7,399  

  $ 

708 

  $  6,691 

 $ 

Total 

Level 1 

Level 2 

Level 3 

(iii)  Equity price financial instruments 

During 2018, the Company had equity swaps of 1.5 million notional amount common shares at an average price of $20.18 per 
share (2017 – $20.18 per share) for settlement over a two year period. The Company entered into these equity swap contracts 
to help manage equity price and dilution exposure to shares that it issues under its share based compensation programs. During 
the year ended December 31, 2018 the Company recognized an unrealized gain of $0.9 million (2017 – unrealized loss of $1.2 
million). 

Liabilities from financial instrument contracts 

Commodity futures ..................................................................  

  $  6,257  

  $  6,257 

  $ 

$ 

Commodity swaps ....................................................................  

Equity swaps .............................................................................  

2,214 

3,297 

- 

3,297 

2,214 

Total liabilities ..........................................................................  

  $  11,768  

  $  9,554 

  $  2,214 

 $ 

2,565 

- 

- 

504 

55 

2,887 

- 

1,451 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

- 

-  

- 

- 

- 

Consolidated Financial Statements 

50 

98 

Gibson Energy

51 

 
 
 
 
 
 
 
 
   
 
 
   
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Derivative financial instruments (recurring fair value measurements) 

The following is a summary of the Company’s risk management contracts outstanding: 

Commodity futures ...............................................................     $      1,937  

    $         616   

  $ 

  $ 

Commodity swaps .................................................................  

Equity swaps ..........................................................................  

Foreign currency forwards ....................................................  

2,565 

677 

504 

Total .......................................................................................     $      5,683  

  $      7,869    

  $ 

  $  11,768 

Less non-current portion: 

Commodity futures ........................................................  

Commodity swaps ..........................................................  

Equity swaps ...................................................................  

Foreign currency forwards .............................................  

December 31, 

2018 

December 31, 

2017 

Assets 

Liabilities 

Assets 

Liabilities 

2,887   

2,915   

1,451   

-   

-   

-   

154   

154   

- 

- 

- 

- 

- 

384 

4,808 

324 

1,883 

7,399 

384 

567 

294 

122 

1,367 

6,032 

6,257 

2,214 

3,297 

- 

- 

- 

215 

277 

492 

Current portion......................................................................     $ 

5,683  

  $ 

7,715   

  $ 

  $  11,276 

The fair value of financial instruments is classified as a non-current asset (long-term prepaid expense and other assets) or liability 

(other long-term liabilities) if the remaining maturity is more than 12 months and, as a current asset or liability, if the maturity is less 

than 12 months. 

(i)  Commodity financial instruments 

Futures, options and swaps 

The Company enters into futures, options and swap contracts to manage the price risk associated with sales, purchases and 

inventories of crude oil, natural gas liquids and petroleum products.  

During the year ended December 31, 2018, the Company entered into certain WTI differential futures to manage the exposure 

to price risks associated with the purchases of crude oil feedstock.  

(ii)  Currency financial instruments 

The Company enters into forward and options contracts to buy and sell U.S. dollars in exchange for Canadian dollars to fix the 

exchange rate on its estimated future net cash inflows denominated in U.S. dollars and long-term borrowings denominated in 

U.S. dollars.  

There were no contracts entered into during the year ended December 31, 2018. 

During the year ended December 31, 2017, the Company entered into U.S. dollar forward contracts to buy U.S. dollars on a 

notional amount of US$480.0 million at a weighted average rate of $1.33 for US$1.00 which settled on March 22, 2017 and on 

October 5, 2017. The overall value of the U.S. dollar forward contracts settlement was $2.2 million loss during the year ended 

December 31, 2017. 

(iii)  Equity price financial instruments 

During 2018, the Company had equity swaps of 1.5 million notional amount common shares at an average price of $20.18 per 

share (2017 – $20.18 per share) for settlement over a two year period. The Company entered into these equity swap contracts 

to help manage equity price and dilution exposure to shares that it issues under its share based compensation programs. During 

the year ended December 31, 2018 the Company recognized an unrealized gain of $0.9 million (2017 – unrealized loss of $1.2 

million). 

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

The value of the Company’s derivative financial instruments is determined using inputs that are either readily available in public 
markets or are quoted by counterparties to these contracts. In situations where the Company obtains inputs via quotes from its 
counterparties, these quotes are verified for reasonableness via similar quotes from another source for each date for which financial 
statements  are  presented.  The  Company  has  consistently  applied  these  valuation  techniques  in  all  periods  presented  and  the 
Company believes it has obtained the most accurate information available for the types of financial instrument contracts held. The 
Company has categorized the inputs  for these  contracts  as Level 1, defined as observable inputs  such as quoted prices in active 
markets; Level 2 defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; or 
Level 3  defined  as  unobservable  inputs  in  which  little  or  no  market  data  exists  therefore  requiring  an  entity  to  develop  its  own 
assumptions.  

The Company used the following techniques to value financial instruments categorized in Level 2: 

 

 

The fair value of commodity swaps is calculated as the present value of the estimated future cash flows based on the difference 
between contract price and commodity price forecast.  

The fair value of foreign currency forward contracts is determined using the forward exchange rates at the measurement date, 
with the resulting value discounted back to present values. 

The fair value of financial instrument contracts by fair value hierarchy at December 31, 2018 was: 

Total 

Level 1 

Level 2 

Level 3 

Assets from financial instrument contracts 

Commodity futures ..................................................................  
Commodity swaps ....................................................................  
Equity swaps .............................................................................  
Foreign currency forwards .......................................................  
Total assets ...............................................................................  

  $  1,937  
2,565 
677 
504 
  $  5,683  

  $  1,937 
- 
677 
- 
  $  2,614 

  $ 

- 
2,565 
- 
504 
  $  3,069 

Liabilities from financial instrument contracts 

Commodity futures ..................................................................  
Commodity swaps ....................................................................  
Equity swaps .............................................................................  
Foreign currency forwards .......................................................  
Total liabilities ..........................................................................  

  $ 

616  
2,887 
2,915 
1,451 
  $  7,869  

  $ 

561 
- 
2,915 
- 
  $  3,476 

  $ 

55 
2,887 
- 
1,451 
  $  4,393 

 $ 

 $ 

 $ 

 $ 

- 
- 
- 
- 
- 

- 
- 
- 
- 
- 

The fair value of financial instrument contracts by fair value hierarchy at December 31, 2017 was: 

Total 

Level 1 

Level 2 

Level 3 

Assets from financial instrument contracts 

Commodity futures ..................................................................  
Commodity swaps ....................................................................  
Equity swaps .............................................................................  
Foreign currency forwards .......................................................  
Total assets ...............................................................................  

  $ 

384  
4,808 
324 
1,883 
  $  7,399  

  $ 

  $ 

384 
- 
324 
- 
708 

  $ 

- 
4,808 
- 
1,883 
  $  6,691 

Liabilities from financial instrument contracts 

Commodity futures ..................................................................  
Commodity swaps ....................................................................  
Equity swaps .............................................................................  
Total liabilities ..........................................................................  

  $  6,257  
2,214 
3,297 
  $  11,768  

  $  6,257 
- 
3,297 
  $  9,554 

  $ 

- 
2,214 
- 
  $  2,214 

 $ 

 $ 

$ 

 $ 

- 
- 
- 
- 
- 

-  
- 
- 
- 

50 

Gibson Energy 

51 
99 

Consolidated Financial Statements

 
 
 
 
 
 
 
 
   
 
 
   
 
 
   
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

The  impact  of  the  movement  in  the  fair  value  of  financial  instruments  has  been  expensed  in  the  consolidated  statements  of 
operations as follows:  

c) 

Commodity price risk 

Year ended 
December 31, 
2018 

2017 

price movements. These financial instruments are not designated as hedges. Based on the Company’s risk management policies, all 

of the financial instruments are employed in connection with an underlying asset/liability and/or forecasted transaction and are not 

Cost of sales gain ......................................................................................................................  
Share based compensation gain (loss)......................................................................................  

$             1,197 
                  923 
$            2,120 

  $ 

  $ 

2,803 
(1,188) 
1,615 

Financial Risk Management 

The Company’s activities expose it to certain financial risks, including foreign exchange risk, interest rate risk, commodity price risk, 
credit  risk  and  liquidity  risk.  The  Company’s  risk  management  strategy  seeks  to  reduce  potential  adverse  effects  on  its  financial 
performance. As a part of its strategy, both primary and derivative financial instruments are used to hedge its risk exposures.  

There are clearly defined objectives and principles for managing financial risk, with policies, parameters and procedures covering the 
specific areas of funding, banking relationships, interest rate exposures and cash management. The Company’s treasury and risk 
management  functions  are  responsible  for  implementing  the  policies  and  providing  a  centralised  service  to  the  Company  for 
identifying, evaluating and monitoring financial risks.  

d) 

Credit risk 

a) 

Foreign currency exchange risk 

Foreign exchange risks arise from future transactions and cash flows and from recognized monetary assets and liabilities that are not 
denominated in the functional currency of the Company’s operations.  

The Company’s credit risk arises from its outstanding trade receivables, including receivables from customers who have entered into 

fixed term contractual arrangements to have dedicated use of certain of the Company’s tanks. A significant portion of the Company’s 

trade receivables are due from entities in the oil and gas industry. Concentration of credit risk is mitigated by having a broad customer 

base  and  by  dealing  with  credit-worthy  counterparties  in  accordance  with  established  credit  approval  practices.  The  Company 

actively monitors the financial strength of its customers and, in select cases, has tightened credit terms to minimize the risk of default 

The exposure to exchange rate movements in significant future transactions and cash flows is managed by using foreign currency 
forward  contracts  and  options.  These  financial  instruments  have  not  been  designated  in  a  hedge  relationship.  No  speculative 
positions are entered into by the Company. 

on trade receivables.  

Foreign currency exchange rate sensitivity 

If the Canadian dollar strengthened or weakened by 5% relative to the U.S. dollar and all other variables, in particular interest rates 
remain constant, the impact on net income and equity would be as follows: 

U.S. Dollar Forwards  

Favorable 5% change ............................................................................................................. 
Unfavorable 5% change ......................................................................................................... 

  $ 

1,928  
(1,928) 

  $ 

3,419 
(3,419) 

The movement is a result of a change in the fair value of U.S. dollar forward contracts and options.  

The  impact  of  translating  the  net  assets  of  the  Company’s  U.S  operations  into  Canadian  dollars  is  excluded  from  this  sensitivity 
analysis. 

December 31, 
2018 

2017 

b) 

Interest rate risk 

e) 

Equity price risk 

Interest  rate  risk  is  the  risk  that  the  fair  value  of  a  financial  instrument  will  be  affected  by  changes  in  market  interest  rates.  At 
December 31, 2018, the Company has insignificant exposure to changes to market interest rates that relate to the $150.0 million 
(2017 – $230.2 million) drawn on the Company’s credit facility.  

Consolidated Financial Statements 

52 

100 

Gibson Energy

53 

The  Company  is  exposed  to  changes  in  the  price  of  crude  oil,  NGLs,  oil  related  products  and  electricity  commodities,  which  are 

monitored regularly. Crude oil and NGL priced futures, options and swaps are used to manage the exposure to these commodities’ 

entered into with the objective of speculating on commodity prices.  

The  following  table  summarizes  the  impact  to  net  income  and  equity  due  to a  change  in  fair  value  of  the  Company’s  derivative 

positions because of fluctuations in commodity prices leaving all other variables constant, in particular, foreign currency rates. The 

Company believes that a 15% volatility in crude oil and NGL related prices is a reasonable assumption. 

Crude oil and NGL related prices 

Favorable 15% change ..............................................................................................................    $ 

Unfavorable 15% change .......................................................................................................... 

7,275  

(7,275)  

  $ 

6,224 

(6,224) 

December 31, 

2018 

2017 

At December 31, 2018, impairment from expected credit losses under the simplified approach was $0.1 million (note 5) including the 

impact of IFRS 9 adoption (note 4). At December 31, 2018, approximately 7% of net trade receivables were 30 days past the due date 

but not considered impaired (December 31, 2017 – 2%). The maximum exposure to credit risk related to trade receivables is their 

carrying value as disclosed in these financial statements.  

The Company establishes guidelines for customer credit limits and terms. The Company review includes financial statements and 

external  ratings  when  available.  The  Company  does  not  usually  require  collateral  in  respect  of  trade  and  other  receivables.  The 

Company provides adequate provisions for expected losses from the credit risks associated with trade receivables. The provision is 

based on an individual account-by-account analysis and prior credit history. 

The  Company  is  exposed  to  credit  risk  associated  with  possible  non-performance  by  financial  instrument  counterparties.  The 

Company  does  not  generally  require  collateral  from  its  counterparties  but  believes  the  risk  of  non-performance  is  low.  The 

counterparties are generally major financial institutions or commodity brokers with investment grade credit ratings as determined 

by recognized credit rating agencies. 

The Company’s cash equivalents are placed in time deposits with investment grade international banks and financial institutions. 

The Company is exposed to changes in the Company’s share price with respect to equity swap contracts. If the Company’s share price 

increased or decreased by 10%, the impact on net income and equity would be as follows: 

Equity Swaps 

Favorable 10% change ........................................................................................................ 

$       1,998 

Unfavorable 10% change .................................................................................................... 

(1,998) 

$ 

1,930 

(1,930) 

December 31, 

2018 

2017 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

operations as follows:  

Year ended 

December 31, 

2018 

2017 

$             1,197 

                  923 

$            2,120 

  $ 

  $ 

2,803 

(1,188) 

1,615 

Cost of sales gain ......................................................................................................................  

Share based compensation gain (loss)......................................................................................  

Financial Risk Management 

The Company’s activities expose it to certain financial risks, including foreign exchange risk, interest rate risk, commodity price risk, 

credit  risk  and  liquidity  risk.  The  Company’s  risk  management  strategy  seeks  to  reduce  potential  adverse  effects  on  its  financial 

performance. As a part of its strategy, both primary and derivative financial instruments are used to hedge its risk exposures.  

There are clearly defined objectives and principles for managing financial risk, with policies, parameters and procedures covering the 

specific areas of funding, banking relationships, interest rate exposures and cash management. The Company’s treasury and risk 

management  functions  are  responsible  for  implementing  the  policies  and  providing  a  centralised  service  to  the  Company  for 

identifying, evaluating and monitoring financial risks.  

a) 

Foreign currency exchange risk 

Foreign exchange risks arise from future transactions and cash flows and from recognized monetary assets and liabilities that are not 

denominated in the functional currency of the Company’s operations.  

The exposure to exchange rate movements in significant future transactions and cash flows is managed by using foreign currency 

forward  contracts  and  options.  These  financial  instruments  have  not  been  designated  in  a  hedge  relationship.  No  speculative 

positions are entered into by the Company. 

Foreign currency exchange rate sensitivity 

If the Canadian dollar strengthened or weakened by 5% relative to the U.S. dollar and all other variables, in particular interest rates 

remain constant, the impact on net income and equity would be as follows: 

analysis. 

b) 

Interest rate risk 

Interest  rate  risk  is  the  risk  that  the  fair  value  of  a  financial  instrument  will  be  affected  by  changes  in  market  interest  rates.  At 

December 31, 2018, the Company has insignificant exposure to changes to market interest rates that relate to the $150.0 million 

(2017 – $230.2 million) drawn on the Company’s credit facility.  

The  impact  of  the  movement  in  the  fair  value  of  financial  instruments  has  been  expensed  in  the  consolidated  statements  of 

c) 

Commodity price risk 

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

The  Company  is  exposed  to  changes  in  the  price  of  crude  oil,  NGLs,  oil  related  products  and  electricity  commodities,  which  are 
monitored regularly. Crude oil and NGL priced futures, options and swaps are used to manage the exposure to these commodities’ 
price movements. These financial instruments are not designated as hedges. Based on the Company’s risk management policies, all 
of the financial instruments are employed in connection with an underlying asset/liability and/or forecasted transaction and are not 
entered into with the objective of speculating on commodity prices.  

The  following  table  summarizes  the  impact  to  net  income  and  equity  due  to a  change  in  fair  value  of  the  Company’s  derivative 
positions because of fluctuations in commodity prices leaving all other variables constant, in particular, foreign currency rates. The 
Company believes that a 15% volatility in crude oil and NGL related prices is a reasonable assumption. 

Crude oil and NGL related prices 

Favorable 15% change ..............................................................................................................    $ 
Unfavorable 15% change .......................................................................................................... 

7,275  
(7,275)  

  $ 

6,224 
(6,224) 

December 31, 

2018 

2017 

d) 

Credit risk 

The Company’s credit risk arises from its outstanding trade receivables, including receivables from customers who have entered into 
fixed term contractual arrangements to have dedicated use of certain of the Company’s tanks. A significant portion of the Company’s 
trade receivables are due from entities in the oil and gas industry. Concentration of credit risk is mitigated by having a broad customer 
base  and  by  dealing  with  credit-worthy  counterparties  in  accordance  with  established  credit  approval  practices.  The  Company 
actively monitors the financial strength of its customers and, in select cases, has tightened credit terms to minimize the risk of default 
on trade receivables.  

At December 31, 2018, impairment from expected credit losses under the simplified approach was $0.1 million (note 5) including the 
impact of IFRS 9 adoption (note 4). At December 31, 2018, approximately 7% of net trade receivables were 30 days past the due date 
but not considered impaired (December 31, 2017 – 2%). The maximum exposure to credit risk related to trade receivables is their 
carrying value as disclosed in these financial statements.  

U.S. Dollar Forwards  

Favorable 5% change ............................................................................................................. 

  $ 

Unfavorable 5% change ......................................................................................................... 

1,928  

(1,928) 

  $ 

3,419 

(3,419) 

The movement is a result of a change in the fair value of U.S. dollar forward contracts and options.  

December 31, 

2018 

2017 

The Company establishes guidelines for customer credit limits and terms. The Company review includes financial statements and 
external  ratings  when  available.  The  Company  does  not  usually  require  collateral  in  respect  of  trade  and  other  receivables.  The 
Company provides adequate provisions for expected losses from the credit risks associated with trade receivables. The provision is 
based on an individual account-by-account analysis and prior credit history. 

The  Company  is  exposed  to  credit  risk  associated  with  possible  non-performance  by  financial  instrument  counterparties.  The 
Company  does  not  generally  require  collateral  from  its  counterparties  but  believes  the  risk  of  non-performance  is  low.  The 
counterparties are generally major financial institutions or commodity brokers with investment grade credit ratings as determined 
by recognized credit rating agencies. 

The  impact  of  translating  the  net  assets  of  the  Company’s  U.S  operations  into  Canadian  dollars  is  excluded  from  this  sensitivity 

The Company’s cash equivalents are placed in time deposits with investment grade international banks and financial institutions. 

e) 

Equity price risk 

The Company is exposed to changes in the Company’s share price with respect to equity swap contracts. If the Company’s share price 
increased or decreased by 10%, the impact on net income and equity would be as follows: 

Equity Swaps 

Favorable 10% change ........................................................................................................ 
Unfavorable 10% change .................................................................................................... 

$       1,998 
(1,998) 

$ 

1,930 
(1,930) 

December 31, 

2018 

2017 

52 

Gibson Energy 

53 
101 

Consolidated Financial Statements

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

f) 

Liquidity risk 

Liquidity risk is the risk that the Company will not be able to meet its financial obligations as they fall due. This risk relates to the 
Company’s ability to generate or obtain sufficient cash or cash equivalents to satisfy these financial obligations as they become due. 
The Company’s process for managing liquidity risk includes preparing and monitoring capital and operating budgets, coordinating 
and  authorizing  project  expenditures  and  authorization  of  contractual  agreements.  The  Company  may  seek  additional  financing 
based on the results of these processes. The budgets are updated with forecasts when required and as conditions change. Cash and 
cash equivalents and the Revolving Credit Facility are available and are expected to be available to satisfy the Company’s short and 
long-term requirements. The Company has a Revolving Credit Facility of $560.0 million and three bilateral demand letter of credit 
facilities  totaling  $150.0  million.  At  December  31,  2018,  $150.0  million  was  drawn  against  the  Revolving  Credit  Facility  and  the 
Company had outstanding issued letters of credit of $70.9 million. 

The terms of the Notes and Revolving Credit Facility require the Company to comply with certain covenants. If the Company fails to 
comply  with  these  covenants  the  lenders  may  declare  an  event  of  default.  At  December  31,  2018  and  December  31,  2017,  the 
Company was in compliance with these covenants. 

Set out below is a maturity analyses of  certain of the  Company’s financial contractual obligations as at December  31, 2018.  The 
maturity dates are the contractual maturities of the obligations and the amounts are the contractual undiscounted cash flows. 

the terms on which financing is available and consideration of the balance between shareholder value creation and prudent financial 

risk management. 

Net debt is calculated as total borrowings (including ‘current and non-current borrowings’ as shown in the consolidated balance 

sheet, lease liabilities, and the Debentures), less cash and cash equivalents. Total capital is calculated as net debt plus share capital 

as shown in the consolidated balance sheet. 

December 31, 

2018 

2017 

Total financial liability borrowings ..........................................................................................  

  $   1,148,649  

Debentures (liability component) (1) .......................................................................................  

             89,765 

  $  1,118,119 

               89,765 

Less: cash and cash equivalents ..............................................................................................  

Net debt ..................................................................................................................................  

Total share capital (including Debentures – equity component) ...........................................  

(95,301) 

1,143,113 

1,962,169 

(32,138) 

1,175,746 

1,939,126 

Total capital ............................................................................................................................  

  $  3,105,282 

  $  3,114,872 

(1)  The Debentures are included in the above total capital calculation in accordance with the Company’s view of its capital structure which includes 

shareholders’ equity, long-term debt, the Debentures, the Revolving Credit Facility, and working capital. The Debentures and associated interest 

payments  are  excluded  from  the  definition  of  net  debt  included  in  the  consolidated  senior  and  total  debt  covenant  ratios,  as  well  as  the 

consolidated interest coverage covenant ratio. 

On demand or 
within one 
year 

Between one 
and five years   

After 

five years   

Total 

Credit Facility and the bilateral demand letter of credit facilities are sufficient to service this debt and support ongoing operations.  

If the Company is in a net debt position, the Company will assess whether the projected cash flow and availability under the Revolving 

Trade payables and accrued charges (excluding derivative 

financial instruments and accrued interest)......................  
Dividend payable ....................................................................  
Long-term debt .......................................................................  
Credit facilities ........................................................................  
Debentures (debt and equity component) .............................  
Interest on long-term debt and Debentures ..........................  
Commodity futures .................................................................  
Commodity swaps...................................................................  
Equity swap .............................................................................  
Foreign currency forwards ......................................................  
Lease liabilities ........................................................................  

Capital management 

$  333,105  
47,704  
-  
-  
-  
52,875  
616  
2,887  
2,761  
1,451  
39,824  
$  481,223  

$ 

- 
- 
300,000 
150,000    
100,000 
175,064 
- 
- 
154 
- 
59,627 
$  784,845 

  $ 

- 
- 
600,000 
- 
- 
18,375 
- 
- 
- 
- 
26,373 
  $  644,748 

  $ 

333,105 
47,704 
900,000 
150,000 
100,000 
246,314 
616 
2,887 
2,915 
1,451 
125,824 
  $  1,910,816 

31  Commitments and contingencies  

Commitments 

Lease  obligations  primarily  relate  to  office  leases,  rail  cars,  vehicles,  field  buildings,  various  equipment  and  terminal  services 

arrangements. The minimum payments required under these commitments, net of sub-lease income, are as follows: 

2019 ....................................................................................................................................................................  

$ 

48,624  

2020 ....................................................................................................................................................................  

2021 ....................................................................................................................................................................  

2022 ....................................................................................................................................................................  

2023 ....................................................................................................................................................................  

2024 and later .....................................................................................................................................................  

27,160 

18,265 

13,069 

10,613 

32,251 

$  149,982  

With respect to capital expenditures, at December 31, 2018, the Company had an estimated amount of $290.0 million remaining to 

be spent that relates to projects approved at that date. 

The Company's objectives when managing its capital structure are to maintain financial flexibility so as to preserve the Company’s 
ability  to  meet  its  financial  obligations  and  to  finance  internally  generated  growth  capital  requirements  as  well  as  potential 
acquisitions.  

Contingencies 

The  Company manages its capital structure and  makes adjustments to it in  light of changes in  economic conditions  and the risk 
characteristics of the underlying assets. The Company considers its capital structure to include shareholders' equity, long-term debt, 
the Debentures, the Revolving Credit Facility, lease liabilities and working capital. To maintain or adjust the capital structure, the 
Company may draw on its revolving credit facility, issue notes or issue equity and/or adjust its operating costs and/or capital spending 
to manage its current and projected debt levels. 

The Company is involved in various claims and actions arising in the course of operations and is subject to various legal actions and 

exposures. Although the outcome of these claims are uncertain, the Company does not expect these matters to have a material 

adverse effect on the Company’s financial position, cash flows or operational results. If an unfavorable outcome were to occur, there 

exists  the  possibility  of  a  material  adverse  impact  on  the Company’s  consolidated  net  income  or  loss  in  the  period  in  which  the 

outcome is determined. Accruals for litigation, claims and assessments are recognized if the Company determines that the loss is 

probable and the amount can be reasonably estimated. The Company believes it has made adequate provision for such legal claims. 

While fully supportable in the Company’s view, some of these positions, if challenged may not be fully sustained on review. 

Financing decisions are made by management and the Board based on forecasts of the expected timing and level  of capital and 
operating expenditure required to meet the Company’s commitments and development plans. Factors considered when determining 
whether to issue new debt or to seek equity financing include the amount of financing required, the availability of financial resources, 

The  Company  is  subject  to  various  regulatory  and  statutory  requirements  relating  to  the  protection  of  the  environment.  These 

requirements,  in  addition  to  the  contractual  agreements  and  management  decisions,  result  in  the  recognition  of  estimated 

decommissioning  obligations  and  environmental  remediation.  Estimates  of  decommissioning  obligations  and  environmental 

Consolidated Financial Statements 

54 

102 

Gibson Energy

55 

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

f) 

Liquidity risk 

Liquidity risk is the risk that the Company will not be able to meet its financial obligations as they fall due. This risk relates to the 

Company’s ability to generate or obtain sufficient cash or cash equivalents to satisfy these financial obligations as they become due. 

The Company’s process for managing liquidity risk includes preparing and monitoring capital and operating budgets, coordinating 

and  authorizing  project  expenditures  and  authorization  of  contractual  agreements.  The  Company  may  seek  additional  financing 

based on the results of these processes. The budgets are updated with forecasts when required and as conditions change. Cash and 

cash equivalents and the Revolving Credit Facility are available and are expected to be available to satisfy the Company’s short and 

long-term requirements. The Company has a Revolving Credit Facility of $560.0 million and three bilateral demand letter of credit 

facilities  totaling  $150.0  million.  At  December  31,  2018,  $150.0  million  was  drawn  against  the  Revolving  Credit  Facility  and  the 

Company had outstanding issued letters of credit of $70.9 million. 

The terms of the Notes and Revolving Credit Facility require the Company to comply with certain covenants. If the Company fails to 

comply  with  these  covenants  the  lenders  may  declare  an  event  of  default.  At  December  31,  2018  and  December  31,  2017,  the 

Company was in compliance with these covenants. 

Set out below is a maturity analyses of  certain of the  Company’s financial contractual obligations as at December  31, 2018.  The 

maturity dates are the contractual maturities of the obligations and the amounts are the contractual undiscounted cash flows. 

the terms on which financing is available and consideration of the balance between shareholder value creation and prudent financial 
risk management. 

Net debt is calculated as total borrowings (including ‘current and non-current borrowings’ as shown in the consolidated balance 
sheet, lease liabilities, and the Debentures), less cash and cash equivalents. Total capital is calculated as net debt plus share capital 
as shown in the consolidated balance sheet. 

December 31, 
2018 

2017 

Total financial liability borrowings ..........................................................................................  
Debentures (liability component) (1) .......................................................................................  
Less: cash and cash equivalents ..............................................................................................  
Net debt ..................................................................................................................................  
Total share capital (including Debentures – equity component) ...........................................  
Total capital ............................................................................................................................  

  $   1,148,649  
             89,765 
(95,301) 
1,143,113 
1,962,169 
  $  3,105,282 

  $  1,118,119 
               89,765 
(32,138) 
1,175,746 
1,939,126 
  $  3,114,872 

(1)  The Debentures are included in the above total capital calculation in accordance with the Company’s view of its capital structure which includes 
shareholders’ equity, long-term debt, the Debentures, the Revolving Credit Facility, and working capital. The Debentures and associated interest 
payments  are  excluded  from  the  definition  of  net  debt  included  in  the  consolidated  senior  and  total  debt  covenant  ratios,  as  well  as  the 
consolidated interest coverage covenant ratio. 

On demand or 

within one 

Between one 

After 

year 

and five years   

five years   

Total 

If the Company is in a net debt position, the Company will assess whether the projected cash flow and availability under the Revolving 
Credit Facility and the bilateral demand letter of credit facilities are sufficient to service this debt and support ongoing operations.  

Trade payables and accrued charges (excluding derivative 

financial instruments and accrued interest)......................  

$  333,105  

$ 

  $ 

  $ 

333,105 

Dividend payable ....................................................................  

47,704  

31  Commitments and contingencies  

Commitments 

Lease  obligations  primarily  relate  to  office  leases,  rail  cars,  vehicles,  field  buildings,  various  equipment  and  terminal  services 
arrangements. The minimum payments required under these commitments, net of sub-lease income, are as follows: 

2019 ....................................................................................................................................................................  
2020 ....................................................................................................................................................................  
2021 ....................................................................................................................................................................  
2022 ....................................................................................................................................................................  
2023 ....................................................................................................................................................................  
2024 and later .....................................................................................................................................................  

$ 

48,624  
27,160 
18,265 
13,069 
10,613 
32,251 
$  149,982  

With respect to capital expenditures, at December 31, 2018, the Company had an estimated amount of $290.0 million remaining to 
be spent that relates to projects approved at that date. 

The Company's objectives when managing its capital structure are to maintain financial flexibility so as to preserve the Company’s 

ability  to  meet  its  financial  obligations  and  to  finance  internally  generated  growth  capital  requirements  as  well  as  potential 

Contingencies 

The  Company manages its capital structure and  makes adjustments to it in  light of changes in  economic conditions  and the risk 

characteristics of the underlying assets. The Company considers its capital structure to include shareholders' equity, long-term debt, 

the Debentures, the Revolving Credit Facility, lease liabilities and working capital. To maintain or adjust the capital structure, the 

Company may draw on its revolving credit facility, issue notes or issue equity and/or adjust its operating costs and/or capital spending 

to manage its current and projected debt levels. 

The Company is involved in various claims and actions arising in the course of operations and is subject to various legal actions and 
exposures. Although the outcome of these claims are uncertain, the Company does not expect these matters to have a material 
adverse effect on the Company’s financial position, cash flows or operational results. If an unfavorable outcome were to occur, there 
exists  the  possibility  of  a  material  adverse  impact  on  the Company’s  consolidated  net  income  or  loss  in  the  period  in  which  the 
outcome is determined. Accruals for litigation, claims and assessments are recognized if the Company determines that the loss is 
probable and the amount can be reasonably estimated. The Company believes it has made adequate provision for such legal claims. 
While fully supportable in the Company’s view, some of these positions, if challenged may not be fully sustained on review. 

Financing decisions are made by management and the Board based on forecasts of the expected timing and level  of capital and 

operating expenditure required to meet the Company’s commitments and development plans. Factors considered when determining 

whether to issue new debt or to seek equity financing include the amount of financing required, the availability of financial resources, 

The  Company  is  subject  to  various  regulatory  and  statutory  requirements  relating  to  the  protection  of  the  environment.  These 
requirements,  in  addition  to  the  contractual  agreements  and  management  decisions,  result  in  the  recognition  of  estimated 
decommissioning  obligations  and  environmental  remediation.  Estimates  of  decommissioning  obligations  and  environmental 

54 

Gibson Energy 

55 
103 

Consolidated Financial Statements

Long-term debt .......................................................................  

Credit facilities ........................................................................  

Debentures (debt and equity component) .............................  

Interest on long-term debt and Debentures ..........................  

Commodity futures .................................................................  

Commodity swaps...................................................................  

Equity swap .............................................................................  

Foreign currency forwards ......................................................  

Lease liabilities ........................................................................  

-  

-  

-  

52,875  

616  

2,887  

2,761  

1,451  

39,824  

300,000 

150,000    

100,000 

175,064 

600,000 

18,375 

- 

- 

- 

- 

- 

154 

- 

- 

- 

- 

- 

- 

- 

- 

47,704 

900,000 

150,000 

100,000 

246,314 

616 

2,887 

2,915 

1,451 

$  481,223  

$  784,845 

  $  644,748 

  $  1,910,816 

59,627 

26,373 

125,824 

Capital management 

acquisitions.  

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Gibson Energy Inc. 
Notes to Consolidated Financial Statements 
(tabular amounts in thousands of Canadian dollars, except where noted)  

remediation  costs  can  change  significantly  based  on  such  factors  such  as  operating  experience  and  changes  in  legislation  and 
regulations.  

32  Subsequent Events 

On March 4, 2019, the Company announced that the Board declared a quarterly dividend of $0.33 per common share for the first 
quarter on its outstanding common shares. The common share dividend is payable on April 17, 2019 to shareholders of record at the 
close of business on March 29, 2019. 

On February 28, 2019, the Company completed the sale of its non-core ESN business for gross proceeds of $51.8 million, subject to 
closing adjustments. 

33  Supplemental cash flow information 

Year ended 
December 31, 
2018 

2017 
(note 8) 

Cash flow from operating activities 

Net income (loss) from continuing operations  .....................................................................  
Adjustments for non-cash items: 

Finance costs, net .............................................................................................................  
Income tax expense (recovery) ........................................................................................  
Depreciation and impairment of property, plant and equipment ...................................  
Depreciation of right-of-use asset ....................................................................................  
Amortization and impairment of intangible assets ..........................................................  
Impairment of goodwill ....................................................................................................  
Share based compensation ..............................................................................................  
Loss (gain) on sale of property, plant and equipment .....................................................  
Other ................................................................................................................................  
Net gain on fair value movement of financial instruments ..............................................  
Subtotal of adjustments .........................................................................................................  
Changes in items of working capital: 

Trade and other receivables  ............................................................................................  
Inventories  ......................................................................................................................  
Other current assets  ........................................................................................................  
Trade payables and accrued charges  ..............................................................................  
Deferred revenue .............................................................................................................  
Contract liabilities (note 4) ...............................................................................................  
       Subtotal of changes in items of working capital ...................................................................  
Income taxes received, net  ...................................................................................................  
Cash provided by operating activities from continuing operations  ...........................................  
Cash provided by operating activities from discontinued operations (note 8) ...........................  
Net cash provided by operating activities ...................................................................................  

$ 

81,125   

$       (66,326)

78,492  
55,613  
143,160  
43,184  
10,870  
20,479  
19,124  
1,700  
10,238  
(1,197)  
               381,663  

118,785
(58,204)
100,837
-
23,340
69,414
23,244
(2,813)
(4,065)
(1,615)
268,923

134,586  
53,101  
2,726  
(148,633)  
-  
8,442  
50,222  
14,076  
$       527,086  
36,652  
$       563,738  

(43,404)
(26,862)
(2,619)
48,331
(2,771)
-
(27,325)
-
$     175,272
22,107
$     197,379

Consolidated Financial Statements 

56 

104 

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Gibson Energy Inc. 

Notes to Consolidated Financial Statements 

(tabular amounts in thousands of Canadian dollars, except where noted)  

regulations.  

32  Subsequent Events 

close of business on March 29, 2019. 

closing adjustments. 

33  Supplemental cash flow information 

remediation  costs  can  change  significantly  based  on  such  factors  such  as  operating  experience  and  changes  in  legislation  and 

On March 4, 2019, the Company announced that the Board declared a quarterly dividend of $0.33 per common share for the first 

quarter on its outstanding common shares. The common share dividend is payable on April 17, 2019 to shareholders of record at the 

On February 28, 2019, the Company completed the sale of its non-core ESN business for gross proceeds of $51.8 million, subject to 

Cash flow from operating activities 

Adjustments for non-cash items: 

Net income (loss) from continuing operations  .....................................................................  

$ 

81,125   

$       (66,326)

Finance costs, net .............................................................................................................  

Income tax expense (recovery) ........................................................................................  

Depreciation and impairment of property, plant and equipment ...................................  

Depreciation of right-of-use asset ....................................................................................  

Amortization and impairment of intangible assets ..........................................................  

Impairment of goodwill ....................................................................................................  

Share based compensation ..............................................................................................  

Loss (gain) on sale of property, plant and equipment .....................................................  

Other ................................................................................................................................  

Net gain on fair value movement of financial instruments ..............................................  

Changes in items of working capital: 

Trade and other receivables  ............................................................................................  

Inventories  ......................................................................................................................  

Other current assets  ........................................................................................................  

Trade payables and accrued charges  ..............................................................................  

Deferred revenue .............................................................................................................  

Contract liabilities (note 4) ...............................................................................................  

       Subtotal of changes in items of working capital ...................................................................  

Income taxes received, net  ...................................................................................................  

Subtotal of adjustments .........................................................................................................  

               381,663  

268,923

Year ended 

December 31, 

2018 

2017 

(note 8) 

78,492  

55,613  

143,160  

43,184  

10,870  

20,479  

19,124  

1,700  

10,238  

(1,197)  

134,586  

53,101  

2,726  

(148,633)  

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14,076  

118,785

(58,204)

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23,244

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(4,065)

(1,615)

(43,404)

(26,862)

(2,619)

48,331

(2,771)

(27,325)

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Cash provided by operating activities from continuing operations  ...........................................  

$       527,086  

$     175,272

Cash provided by operating activities from discontinued operations (note 8) ...........................  

36,652  

22,107

Net cash provided by operating activities ...................................................................................  

$       563,738  

$     197,379

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Consolidated Financial Statements 

106 

Gibson Energy

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
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Management

Steve Spaulding 
President & Chief Executive Officer

Sean Brown 
SVP & Chief Financial Officer

Sean Wilson 
SVP & Chief Administrative Officer

Mike Lindsay 
SVP, Operations & Engineering

Directors

James M. Estey 
Chair of the Board

Douglas P. Bloom

James J. Cleary

John L. Festival

Susan C. Jones

Marshall L. McRae

Mary Ellen Peters

Steven R. Spaulding

CORPORATE INFORMATION

Head Office

1700, 440–2nd Ave SW 
Calgary, AB Canada 
T2P 5E9

Phone: (403) 206-4000 
Fax: (403) 206-4001

Website: www.gibsonenergy.com

Auditors

PricewaterhouseCoopers LLP

Bankers

Royal Bank of Canada 
JPMorgan Chase Bank, N.A.

Legal Counsel

Bennett Jones LLP

Trustee, Registrar & Transfer Agent

Computershare Trust Company of Canada 
Calgary, Alberta

Stock Exchange

Toronto Stock Exchange 
Trading Symbol: GEI

Investor Relations & Media

Mark Chyc-Cies 
Vice President, Strategy, Planning & Investor Relations 
Phone: (403) 776-3146 
Email: investor.relations@gibsonenergy.com

Media Inquiries 
Phone: (403) 476-6334 
Email: communications@gibsonenergy.com

Gibson Energy Inc.
1700, 440 - 2 Avenue SW
Calgary, AB T2P 5E9
(403) 206-4000
gibsonenergy.com