.
lntelligent Energy. Greener Planet.
Annual Report
2023
©Ulrich Mertens, Atelier für Kunst und Fotografie
Photographed:
Nordsee One
maintenance crew
Table of Contents
4
9
Letter to Shareholders
Management’s Discussion and Analysis
56
Consolidated Financial Statements
57 Management’s Responsibility
58
63
64
65
66
68
69
Independent Auditors’ Report
Consolidated Statements of Financial Position
Consolidated Statements of Income (Loss)
Consolidated Statements of Comprehensive Income (Loss)
Consolidated Statements of Changes in Equity
Consolidated Statements of Cash Flows
Notes to the Consolidated Financial Statements
117 Corporate Information
3
Northland Power Annual Report | 2023
Photographed:
Mike Crawley,
President and
Chief Executive Officer
Dear Shareholders,
I’m proud to share with you Northland’s Annual Report, which highlights our collective success
across our diversified portfolio despite macro-economic headwinds that impacted the renewables
sector globally.
Resiliency was a defining trait for Northland in 2023. This was reflected in our ability to anticipate
changing market dynamics and make tough, but necessary, decisions at the right time, navigating
unique conditions with suppliers, partners and governments. Through it all, we continued to drive
progress in a year that wasn’t without challenge. As a result, we ended 2023 in a much stronger
position than we started with costs locked down, funds secured, and long-term PPAs in place on
three significant projects in our portfolio. These projects are expected to deliver approximately $570
to $615 million in incremental annual Adjusted EBITDA once operational and, with revenue contract
tenors of 20 to 30 years, they will solidify Northland’s foundation moving forward.
In 2024, there is a sense of optimism across the industry as inflation, interest rates and supply
chain constraints are predicted to start to ease. We’re seeing renewed confidence from investors,
and support for the build-out of renewables has increased beyond what we’ve witnessed before.
Governments globally are working to address roadblocks and are providing more favourable market
conditions for developers through incentives and new funding mechanisms. Policies like the Inflation
Reduction Act (IRA) in the United States, Income Tax Credits (ITCs) and Carbon Tax Credits (CTCs) in
Canada, and the Wind Power Package (WPP) from the European Commission, will provide material
benefits to the sector over the long term. Offtake auction prices are also rebounding in response to
government action as a mitigating factor.
With this renewed enthusiasm for renewables investment globally, Northland is well-positioned and
proud to be one of the major players leading global transition efforts for a cleaner future.
4
Northland Power Annual Report | 2023 Collective Focus in 2024
As reflected in our business plan, we enter a new chapter in our
business in 2024 – one anchored by a stronger focus on key
priorities, and largely centered around the flawless execution
of the $16 billion construction campaigns for Hai Long, Baltic
Power and Oneida. Delivering these projects on time, on budget
and without incident is Northland’s biggest priority over the
next 2-3 years and will build on our incredibly solid foundation.
Once these projects are fully operational (anticipated by 2027),
they will collectively generate an aggregate Adjusted EBITDA
and Free Cash Flow of $570 to $615 million and $185 to $210
million, respectively, resulting in significant value and accretion
for Northland’s shareholders. Hai Long, Baltic Power and Oneida
will also strengthen the quality of our cash flow and extend the
tenure of our contracted terms of our consolidated cash flow from
8 years to 16 years by 2027.
Despite our focus on project execution, development remains at
the core of who we are. With demand for renewable energy soaring
and governments continuing to procure renewable energy, we will
continue to look for opportunities to grow prudently, leveraging
opportunities to advance our existing pipeline in offshore wind in
South Korea and Scotland, and exploring new potential in priority
onshore markets including Ontario, Alberta and New York. We
don’t need to be active in every market across all technologies to
reach our growth targets and we recognize that.
Our diverse ~12 GW construction and development pipeline
brings us optionality, and with that we will continue to be strategic
and deliberate in our decision-making, bringing increased focus
to our balance sheet resilience and to optimization of our current
facilities to find more value in the near and long-term.
With demand for renewable energy set to outpace previous years,
and significant long-term growth in EBITDA locked in, I am excited
about the next chapter in Northland’s journey.
On behalf of Northland, I thank you for your ongoing support and
confidence.
Mike Crawley
President and Chief Executive
Officer
Watch Our Look North Video
Learn what makes Northland an
industry leader.
5
Northland Power Annual Report | 2023
Key
Accomplishments
in 2023
Photograph above:
Nordsee One,
North Sea, Germany
Business Highlights:
• Closed approximately $15 billion in corporate and project financings:
◦ Secured financing and began construction on the Oneida Energy
Storage Project (250MW) in Ontario. Oneida is Canada’s first utility-scale
energy storage project to reach financial close and enter construction,
with operations set to commence in 2025.
◦ Secured award-winning financing deals for two major offshore wind
projects, Hai Long (1,022 MW) in Taiwan and Baltic Power (1,140 MW)
in Poland. Both projects mark respective firsts in their markets and are
expected to commence operations in 2026-2027.
◦ Closed our inaugural offering of $500 million of Fixed-to-Fixed Rate
Green Subrodinated Notes, due June 30, 2083 (the “Green Notes“).
•
Executed on long-term strategic partnerships to add value and
diversify risk:
◦ Continued to build on our strategic partnership model by divesting
a 24.5% interest in both Scottish offshore wind projects with ESB, a
leading Irish energy company, to share in the projects‘ value creation.
This partnership demonstrates the interest in developing offshore wind
in Scotland and provides an opportunity to bring in a strong and long-
term partner.
◦ Closed our partnership with Gentari for the acquisition of a 49% of
Northland’s 60% ownership in the Hai Long offshore wind project, and
a 49% interest in our CanWind and NorthWind Taiwanese offshore
development projects.
6
Northland Power Annual Report | 2023 • Received industry accolades and recognition for project financing and industry innovation,
including:
Baltic Power
◦ Project Finance International 2023 – Europe Deal of the Year
◦
IJGlobal Award 2023 Renewable Energy Deal of the Year – Offshore Wind, Europe.
Hai Long
◦ Project Finance International 2023 – Asia-Pacifi Offshore Wind Deal of the Year
◦
◦
FinanceAsia 2023 - Best Infrastructure Deal (North Asia)
FinanceAsia 2023 – Best Project Finance Deal (North Asia)
Oneida
◦ Ontario Energy Conference Awards 2023 - Innovation Award
◦ Energy Storage Canada Awards 2023 – Project Milestone Award
• Reached commercial operations on Bluestone (112 MW) and Ball Hill (108 MW), our first
projects energized in the U.S., as well as our La Lucha (130 MW) solar facility in Mexico.
• Maintained strong performance of our operating assets, with availability of 95.7% across all
facilities.
•
Strengthened our leadership, welcoming Yonni Fushman, Chief Administrative & Legal
Officer and Corporate Secretary and Pierre-Emmanuel Frot, Executive Vice President of
Project Management Office, and in 2024, Toby Edmonds, Executive Vice President of
Offshore Wind. We also welcomed Ellen Smith, who brings over 35 years of experience in
the power and utilities sector to our Board of Directors.
2023 Financial Highlights:
• Achieved financial guidance for Adjusted EBITDA and exceeded our financial guidance on
Adjusted Free Cash Flow and Free Cash Flow metrics. Our Adjusted EBITDA for the year was
$1.24 billion, in line with our guidance. Our Adjusted Free Cash Flow and Free Cash Flow per
share were $1.97 and $1.68, respectively, well above our guidance.
These achievements are the result of the relentless
commitment and determination from our people and
partners, and reflect our experience as developers and
early-movers in the right markets.
7
Northland Power Annual Report | 2023 Our
Value
1,344
Experts
6
Countries with
active development
2.6 M 3.4 GW
Tons of
avoided CO2e
Of gross
operating capacity
Experienced
developer with
proven track record
• Over 35 years of success developing, constructing and operating renewable power
projects across a range of technologies
Significant depth of management experience.
Ability to deliver on time, on budget and without incident
•
•
A growth mindset
with a focus on
execution
• ~6 GW by 2027 and 7-10% CAGR EBITDA
• Healthy total shareholder return, ~12% CAGR total shareholder annualised return since
IPO
Balance sheet resiliency
Partnership philosophy and forward-thinking culture
Contracted and high-quality cash flows
Visible long-term growth
•
•
•
•
Early mover
advantage
• Delivering industry first milestones
• Award-winning offshore wind project financing
Diversified global
portfolio
• High-quality power infrastructure with over 3.4 GW of gross operating capacity
• Deep 12 GW pipeline to support growth optionality
8
Northland Power Annual Report | 2023 ©Ulrich Mertens, Atelier für Kunst und Fotografie
Management’s Discussion
and Analysis
9
Northland Power Annual Report | 2023 Management’s Discussion and Analysis
of Northland Power’s Financial Position and Operating Results
Table of Contents
SECTION 1: OVERVIEW . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
SECTION 2: STRATEGY AND KEY FACTORS SUPPORTING SUSTAINABLE PERFORMANCE AND GROWTH . . . . . . . . . . . . . . . . . .
SECTION 3: NORTHLAND’S BUSINESS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
SECTION 4: CONSOLIDATED HIGHLIGHTS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.1: Significant Events . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
4.2: Operating Highlights . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
SECTION 5: RESULTS OF OPERATIONS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5.1: Operating Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5.2: General and Administrative Costs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5.3: Growth Expenditures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5.4: Consolidated Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5.5: Adjusted EBITDA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5.6: Adjusted Free Cash Flow and Free Cash Flow . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5.7: Reconciliation to 'Non-IFRS Measures Before Definition Change' . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
SECTION 6: CHANGES IN FINANCIAL POSITION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
SECTION 7: EQUITY, LIQUIDITY AND CAPITAL RESOURCES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
SECTION 8: SUMMARY OF QUARTERLY CONSOLIDATED RESULTS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
SECTION 9: CONSTRUCTION, DEVELOPMENT AND ACQUISITION ACTIVITIES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
SECTION 10: OUTLOOK . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
SECTION 11: LITIGATION, CLAIMS AND CONTINGENCIES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
SECTION 12: ESG AND CLIMATE CHANGE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
SECTION 13: FINANCIAL RISKS AND UNCERTAINTIES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
SECTION 14: CRITICAL ACCOUNTING ESTIMATES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
SECTION 15: FUTURE ACCOUNTING POLICIES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
SECTION 16: CONTROLS AND PROCEDURES OVER FINANCIAL REPORTING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
11
14
16
18
18
22
23
24
29
30
30
33
34
37
38
39
46
47
49
50
50
51
54
54
54
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I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
SECTION 1: OVERVIEW
Introduction
The purpose of this Management’s Discussion and Analysis (“MD&A”) is to explain the financial results of Northland Power
Inc. (“Northland” or the “Company”) and to assist the reader in understanding the nature and importance of changes and
trends as well as the risks and uncertainties that may affect the operating results and financial position of the Company.
This MD&A should be read in conjunction with Northland’s audited consolidated financial statements for the year ended
December 31, 2023, and 2022, and Northland’s most recent Annual Information Form for the year ended December 31,
2023, dated February 21, 2024 (“2023 AIF”). These materials are available on the Company’s SEDAR+ profile at
www.sedarplus.ca and on Northland’s website at www.northlandpower.com.
This MD&A, dated February 21, 2024, compares Northland’s financial results and financial position for the year ended
December 31, 2023, with those for the year ended December 31, 2022. Certain prior period disclosures have been
reclassified for consistency with the current period presentation. Northland’s Audit Committee reviewed this MD&A and
the associated audited consolidated financial statements and notes, and its Board of Directors approved these documents
prior to their release.
All dollar amounts set out herein are in thousands of Canadian dollars, unless otherwise stated.
Forward-Looking Statements
This MD&A contains forward-looking statements that are based on certain estimates and assumptions that were considered
reasonable on February 21, 2024; actual results may differ materially. Forward-looking statements are provided for the
purpose of presenting information about management’s current expectations and plans. Readers are cautioned that such
statements may not be appropriate for other purposes. Northland’s actual results could differ materially from those
expressed in, or implied by, these forward-looking statements and, accordingly, the events anticipated by the forward-
looking statements may or may not transpire or occur. Forward-looking statements include statements that are not
historical facts and are predictive in nature, depend upon or refer to future events or conditions, or include words such as
“expects,” “anticipates,” “plans,” “predicts,” “believes,” “estimates,” “intends,” “targets,” “projects,” “forecasts” or negative
versions thereof and other similar expressions or future or conditional verbs such as “may,” “will,” “should,” “would” and
“could.” These statements may include, without limitation, statements regarding future Adjusted EBITDA, Adjusted Free
Cash Flow and Free Cash Flow, including respective per share amounts, dividend payments and dividend payout ratios, the
timing for and attainment of the Hai Long and Baltic Power offshore wind and Oneida energy storage projects’ anticipated
contributions to Adjusted EBITDA, Adjusted Free Cash Flow and Free Cash Flow, the expected generating capacity of certain
projects, guidance, the completion of construction, acquisitions, dispositions, whether partial or full, investments or
financings and the timing thereof, the timing for and attainment of financial close and commercial operations, for each
project, the potential for future production from project pipelines, cost and output of development projects, the all-in
interest cost for debt financing, the impact of currency and interest rate hedges, litigation claims, anticipated results from
the optimization of the Thorold Co-Generation facility and the timing related thereto, future funding requirements, and the
future operations, business, financial condition, financial results, priorities, ongoing objectives, strategies and the outlook of
Northland, its subsidiaries and joint ventures. These statements are based upon certain material factors or assumptions that
were applied in developing the forward-looking statements, including the design specifications of development projects, the
provisions of contracts to which Northland or a subsidiary is a party, management’s current plans and its perception of
historical trends, current conditions and expected future developments, the ability to obtain necessary approvals, satisfy any
closing conditions, satisfy any project finance lender conditions to closing sell-downs or obtain adequate financing regarding
contemplated construction, acquisitions, dispositions, investments or financings, as well as other factors, estimates and
assumptions that are believed to be appropriate in the circumstances. Although these forward-looking statements are based
upon management’s current reasonable expectations and assumptions, they are subject to numerous risks and
uncertainties. Some of the factors that could cause results or events to differ from current expectations include, but are not
limited to, risks associated with further regulatory and policy changes in Spain which could impair current guidance and
expected returns, risks associated with merchant pool pricing and revenues, risks associated with sales contracts, the
emergence of widespread health emergencies or pandemics, Northland’s reliance on the performance of its offshore wind
facilities at Gemini, Nordsee One and Deutsche Bucht for over 50% of its Adjusted EBITDA, counterparty and joint venture
risks, contractual operating performance, variability of sales from generating facilities powered by intermittent renewable
resources, wind and solar resource risk, unplanned maintenance risk, offshore wind concentration, natural gas and power
market risks, commodity price risks, operational risks, recovery of utility operating costs, Northland’s ability to resolve
issues/delays with the relevant regulatory and/or government authorities, permitting, construction risks, project
development risks, integration and acquisition risks, procurement and supply chain risks, financing risks, disposition and
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
11
joint-venture risks, competition risks, interest rate and refinancing risks, liquidity risk, inflation risks, commodity availability
and cost risk, construction material cost risks, impacts of regional or global conflicts, credit rating risk, currency fluctuation
risk, variability of cash flow and potential impact on dividends, taxation, natural events, environmental risks, climate
change, health and worker safety risks, market compliance risk, government regulations and policy risks, utility rate
regulation risks, international activities, cybersecurity, data protection and reliance on information technology, labour
relations, labour shortage risk, management transition risk, geopolitical risk in and around the regions Northland operates
in, large project risk, reputational risk, insurance risk, risks relating to co-ownership, bribery and corruption risk, terrorism
and security, litigation risk and legal contingencies, and the other factors described in this MD&A and the 2023 AIF.
Northland has attempted to identify important factors that could cause actual results to materially differ from current
expectations, however, there may be other factors that cause actual results to differ materially from such expectations.
Northland’s actual results could differ materially from those expressed in, or implied by, these forward-looking statements
and, accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will
transpire or occur, and Northland cautions you not to place undue reliance upon any such forward-looking statements. The
forward-looking statements contained in this MD&A are, unless otherwise indicated, stated as of the date hereof and are
based on assumptions that were considered reasonable as of the date hereof. Other than as specifically required by law,
Northland undertakes no obligation to update any forward-looking statements to reflect events or circumstances after such
date or to reflect the occurrence of unanticipated events, whether as a result of new information, future events or results, or
otherwise.
Certain forward-looking information in this MD&A, including, but not limited to the information in Section 10: Outlook and
our projected Adjusted EBITDA and Free Cash Flow expected to be generated from Northland’s interest in Hai Long, Baltic
Power and Oneida may also constitute a “financial outlook” within the meaning of applicable securities laws. Financial
outlook involves statements about Northland’s prospective financial performance, financial position or cash flows and is
based on and subject to the assumptions about future economic conditions and courses of action and the risk factors
described above in respect of forward-looking information generally, as well as any other specific assumptions and risk
factors in relation to such financial outlook noted in this MD&A. Such assumptions are based on management’s assessment
of the relevant information currently available and any financial outlook included in this MD&A is provided for the purpose
of helping readers understand Northland’s current expectations and plans for the future. Readers are cautioned that reliance
on any financial outlook may not be appropriate for other purposes or in other circumstances and that the risk factors
described above or other factors may cause actual results to differ materially from any financial outlook. The actual results
of Northland’s operations will likely vary from the amounts set forth in any financial outlook and such variances may be
material.
Non-IFRS Financial Measures
This MD&A includes references to the Company’s adjusted earnings before interest, income taxes, depreciation and
amortization (“Adjusted EBITDA”), Adjusted Free Cash Flow, Free Cash Flow and applicable payout ratios and per share
amounts, which are measures not prescribed by International Financial Reporting Standards (“IFRS”), and therefore do not
have any standardized meaning under IFRS and may not be comparable to similar measures presented by other companies.
Non-IFRS financial measures are presented at Northland’s share of underlying operations. These measures should not be
considered alternatives to net income (loss), cash flow from operating activities or other measures of financial performance
calculated in accordance with IFRS. Rather, these measures are provided to complement IFRS measures in the analysis of
Northland’s results of operations from management’s perspective. Management believes that Northland’s non-IFRS
financial measures and applicable payout ratio and per share amounts are widely accepted and understood financial
indicators used by investors and securities analysts to assess the performance of a company, including its ability to generate
cash through operations.
In the second quarter of 2023, in order to accommodate the transactions that occurred during the period, the Company
aligned its definitions of non-IFRS measures to reflect the economic reality of its operation more accurately. Management
implemented specific changes to the compositions of Adjusted EBITDA, Adjusted Free Cash Flow and Free Cash Flow. The
revised definitions provide for the inclusion of partial sell-down gains (losses) in Adjusted EBITDA. All other changes had a
minor impact on the calculation of the aforementioned non-IFRS measures and are fully detailed in Section 5.7:
Reconciliation to 'Non-IFRS Measures Before Definition Change'.
Adjusted EBITDA was revised to remove the impairment of capitalized growth projects from the measure, as this
impairment (related to prior period costs) does not reflect Northland’s current or ongoing core business performance.
Furthermore, amendments were made to include the gains (losses) from partial sell-downs of development facilities
(whether directly owned or through equity accounted investments) in Adjusted EBITDA as this approach better aligns with
the ongoing performance of the business. Under the previously reported definition of Adjusted EBITDA, when a value
12
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
accretive transaction occurred with respect to a partial sell-down of a development project, any associated gain (loss)
would have been altogether excluded from Adjusted EBITDA, which management believes is not an appropriate method for
measuring the current and ongoing financial performance of the business. For clarity, gains (losses) that arise from full
divestitures of development projects continue to be excluded from Adjusted EBITDA as these do not form part of
Northland’s ongoing business performance.
For Adjusted Free Cash Flow and Free Cash Flow, management believes the adjustments described below are appropriate
as they provide for a consistent economic treatment of interest costs during construction, regardless of whether a project is
accounted for in the financial statements as a subsidiary (i.e. Oneida) or an equity accounted investee (i.e. Hai Long and
Baltic Power).
Adjusted Free Cash Flow and Free Cash Flow were revised to exclude the interest costs incurred on corporate-level debt
raised to invest directly in capitalized development projects that are recorded as equity accounted investments. This
clarification was made to ensure consistent treatment of interest costs during construction regardless of whether the
project is accounted for in the financial statements as a subsidiary or an equity accounted investee. Post-construction, the
interest will be expensed as incurred.
Adjusted EBITDA
Adjusted EBITDA represents the core operating performance of the business excluding leverage, income tax and non-core
accounting items. Adjusted EBITDA is calculated as Northland’s share of net income (loss) adjusted for the provision for
(recovery of) income taxes; depreciation of property, plant and equipment; amortization of contracts and other intangible
assets; impairment/write-off of capitalized growth projects; net finance costs; interest income from Gemini; fair value (gain)
loss on derivative contracts; foreign exchange (gain) loss; (gain) loss on sale of operating or full divestiture of development
facilities; exclusion of Northland’s share of (profit) loss from equity accounted investees, net of sell-downs; including
Northland’s share of Adjusted EBITDA from equity accounted investees; including gain (loss) on dilution of controlled
development assets; costs attributable to an asset or business acquisition and other adjustments as appropriate, such as
management and incentive fees earned by Northland from non-wholly owned assets. For clarity, Northland’s Adjusted
EBITDA reflects a reduction of its share of general and administrative costs during development and construction that do
not qualify for capitalization.
Management believes Adjusted EBITDA is a meaningful measure of Northland’s operating performance because it excludes
certain items included in the calculation of net income (loss) that may not be appropriate determinants of long-term
operating performance.
Adjusted Free Cash Flow
Adjusted Free Cash Flow represents the cash generated from the business, before investment-related decisions (refer to
Section 5.3: Growth Expenditures), and available to pay dividends. Adjusted Free Cash Flow is calculated as Northland’s
share of cash provided by operating activities adjusted for short-term changes in operating working capital; non-
expansionary capital expenditures; growth expenditures; interest incurred on outstanding debt (except for the interest on
corporate-level debt raised to finance the capitalized growth project); scheduled principal repayments and net up financing
proceeds; major maintenance and debt reserves; Northland’s share of Adjusted Free Cash Flow from equity accounted
investees; interest income from Northland’s subordinated loan to Gemini (“Gemini sub-debt”); repayment of Gemini sub-
debt; proceeds from government grants; preferred share dividends; gain (loss) from the sale of operating and development
facilities and where net proceeds are received in respect of certain transactions entered in to generate cash flow as part of
an active asset management strategy of the overall portfolio; and other adjustments as appropriate. Adjusted Free Cash
Flow excludes pre-completion sales required to service debt and related operating costs for projects under construction and
excludes costs attributable to an asset or business acquisition.
Where Northland controls the distribution policy of its investments, the Adjusted Free Cash Flow reflects Northland’s
portion of the investment’s underlying Adjusted Free Cash Flow; otherwise, Northland includes the cash distributions
received from the investment. Adjusted Free Cash Flow from foreign operations is translated to Canadian dollars at the
exchange rate Northland realizes on cash distributions.
Management believes Adjusted Free Cash Flow is a meaningful measure of Northland’s ability to generate cash flow after
ongoing obligations to reinvest in growth and fund dividend payments.
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
13
Free Cash Flow
Free Cash Flow is calculated by deducting growth-related expenditures and adjusting for historically incurred growth
expenditures’ recovery due to sell-down, from Adjusted Free Cash Flow. Management believes Free Cash Flow is a
meaningful measure of Northland’s ability to generate cash flow after growth-related costs to fund dividend payments.
For clarity, Northland’s Free Cash Flow includes a reduction for expenditures on development activities until an advanced
project qualifies for capitalization under IFRS. The Adjusted Free Cash Flow and Free Cash Flow payout ratios, calculated
using the respective financial measure, demonstrate the proportion of the respective measure paid as dividends, whether
in cash, or in shares under Northland’s dividend reinvestment plan (“DRIP”). The net payout ratios indicate the proportion
of Free Cash Flow paid as cash dividends. The payout ratios generally reflect Northland’s ability to fund growth-related
expenditures and sustain dividends.
For reconciliations of these non-IFRS financial measures to their nearest IFRS measure, refer to Section 5.5: Adjusted EBITDA
for a reconciliation of consolidated net income (loss) under IFRS to reported Adjusted EBITDA and Section 5.6: Adjusted Free
Cash Flow and Free Cash Flow for a reconciliation of cash provided by operating activities under IFRS to reported Adjusted
Free Cash Flow and Free Cash Flow. For a reconciliation of these non-IFRS financial measures to the same measures before
the definition changes refer to Section 5.7: Reconciliation to 'Non-IFRS Measures Before Definition Change'.
SECTION 2: STRATEGY AND KEY FACTORS SUPPORTING SUSTAINABLE
PERFORMANCE AND GROWTH
Business Objective
Northland’s objective is to provide its shareholders with a total return comprising dividends and share value growth from
the successful management of its assets, businesses and investments related to the production, delivery and sale of energy-
related products.
Vision
At Northland, we are building a sustainable and carbon-neutral world together: Our work is grounded in our vision to
become a global leader in developing sustainable infrastructure assets. We are pushing the energy sector forward by
creating innovative solutions that build a net-positive business. This translates to driving socio-economic value in the
communities where we operate, bringing local markets closer to a carbon-neutral future, and preserving our natural
resources through power generation. As developers, owners and operators of energy facilities across the globe, we are
poised to transform how the world is powered to produce long-term impact for our people and our planet.
Business Strategy
Northland’s business strategy is centered on establishing a significant global presence in key strategic markets as a
sustainable power provider with a primary focus on offshore wind, onshore renewable solar, wind, and battery storage.
Northland aims to increase shareholder value by leveraging its expertise and early mover advantage to create and operate
high-quality, sustainable projects in key target markets supported by long-term sales contracts that deliver predictable cash
flows. Northland utilizes its operational knowledge and the application of appropriate technology to optimize the
performance of its operating facilities to ensure delivery of essential power to its offtake counterparties.
To successfully execute on its strategy, Northland has developed a comprehensive set of strategic pillars to guide the
organization towards successful delivery of its objectives:
(i) Resiliency
Northland’s objectives are to maintain an investment grade credit rating, continue to pay dividends to its shareholders,
deliver on its financial guidance and ensure successful construction and development of renewable energy projects to
increase shareholder value. As Northland continues to progress its $16 billion construction program for the Hai Long, Baltic
Power, and Oneida projects, maintaining financial strength remains its key priority. Northland will continue to maintain
sufficient financial buffers to ensure delivery of its strategic priorities while maintaining its strong balance sheet. From time
to time, this may include Northland’s decision to reduce exposure to or exit certain markets and repurpose capital towards
more accretive opportunities within its core markets or use the funds to strengthen its financial position, especially during
intensive construction periods where it may be prudent to maintain such financial flexibility.
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(ii) Execution
Following successful financial close and securing of funding for the Hai Long, Baltic Power and Oneida projects, Northland
has advanced towards the construction phase for each facility. During the next three years, successful execution and
delivery of these projects to their full completion between 2025-2027 will be one of Northland’s strategic pillars. Northland
has a strong track record in successful project construction and has established a Project Management Office and Business
Unit structure that will focus on aligning the tools and reporting methods and processes in order to provide timely and
accurate reporting. Management will continue to manage and oversee construction of these projects against their targeted
milestones to ensure successful delivery and execution.
During the fourth quarter of 2023, the Board of Directors formed a new subcommittee: the Project Delivery Committee.
The purpose of the Project Delivery Committee is to assist the Board of Directors with monitoring and overseeing projects
in which the Company has an interest during construction.
(iii) Prudent Growth
Northland aims to increase shareholder value by developing high-quality projects that earn recurring income from long-
term sales contracts with creditworthy counterparties (i.e. government or corporate offtakers). Northland exercises
judgment, discipline and acumen in its development activities to continually assess opportunities against its investment
criteria and capital allocation framework. Northland’s successful record of project sourcing and execution results from these
core strengths and contributes to consistent investor returns. Northland’s pace of new development will be moderated in
the near term to allow management to prioritize pillar two - Execution. This may result in full or partial exits from certain
existing or prospective opportunities or assets and directing the focus, resources and capital towards more strategic
markets within Canada, the United States of America, Europe and Asia. Northland is focused on pursuing renewable growth
opportunities in jurisdictions that meet its risk management criteria such as Canada, the United States of America, Europe
and Asia. Northland seeks to manage its development processes prudently by regularly balancing the probability of success
against associated costs and risks and ensuring that only those projects that meet its investment criteria are actively
pursued.
(iv) Optimization
Northland’s management aims to maximize returns through a focus on efficient and effective facility operations; longer-
term asset management; and structuring sales supply and maintenance agreements to maximize sales, while carefully
managing risk. In addition, Northland applies an active approach to overall portfolio management, which may result in
optimizations from asset sales and financing/re-financing opportunities as part of its return objectives and funding strategy.
With a commitment to continuous improvement, Northland’s operations group shares its experiences with the
development, engineering and construction groups on an ongoing basis, to ensure all knowledge gained is factored into the
development and construction of any new project Northland undertakes.
Effective January 2023, Northland formally commenced operating under a business unit (“BU”) structure focused by
technology. The BUs encompass Offshore Wind, Onshore Renewables, and Efficient Natural Gas and Utilities. The Offshore
Wind BU accounts for 1.2GW of operating assets, 2.1GW of assets under construction and 6.5GW of development assets in
Europe and Asia. The Onshore Renewables BU accounts for 1.4GW of operating assets, 0.3GW of assets under construction
and 3.3GW of development assets in Canada, the United States of America and Europe, while the Efficient Natural Gas and
Utility BU accounts for 0.7GW of operating assets.
This operating structure has resulted in a more streamlined business that is better oriented towards the expected growth
by technology. Each BU is led by an experienced executive, with dedicated finance, operations, and human resource leads.
As Northland continues to develop and grow its asset base and shareholder value, management will continue to develop
plans to further optimize its operations. This may include asset optimization strategies such as gas contract restructuring
and, operating and maintenance (“O&M”) contract consolidations, opportunities to add incremental growth or investments
to existing assets or grow in adjacent markets through synergies, opportunities to re-contract asset bases near the end of
power purchase agreement (“PPA”) arrangements, and the improvement of internal processes to gain efficiencies.
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SECTION 3: NORTHLAND’S BUSINESS
As of December 31, 2023, Northland owns or has a net economic interest in 2,947 megawatts (“MW”) of power-producing
facilities with a total gross operating capacity of approximately 3,355MW and a regulated utility. Northland’s facilities
produce electricity from clean energy sources for sale, primarily under long-term PPAs or other revenue arrangements with
creditworthy counterparties. Northland’s utility is a distributor and retailer of electricity, compensated under a regulated
framework. These operating assets provide stable cash flow and are primarily located in Canada, Germany, the
Netherlands, Spain, the United States of America, Mexico and Colombia. Northland’s significant assets under construction
and development are located in Canada, Taiwan, South Korea, Poland, Scotland and the United States of America. Refer to
the 2023 AIF for additional information on Northland’s key operating facilities as of December 31, 2023, and refer to
SECTION 9: CONSTRUCTION, DEVELOPMENT AND ACQUISITION ACTIVITIES for additional information on Northland’s key
development projects.
Northland’s MD&A and audited consolidated financial statements include the results of its operating facilities, as
summarized in the following table:
Offshore Wind
Onshore Renewable (2)
Wind
Solar
Efficient Natural Gas
Utility
Total
(1) Presented at Northland’s economic interest.
Gross Production
Capacity (MW)
1,184
Net Production
Capacity (MW) (1)
894
1,057
392
722
n/a
3,355
968
377
708
n/a
2,947
(2) As at December 31, 2023, Northland’s economic interest was changed from December 31, 2022 due to the La Lucha solar project and New York
onshore wind projects, which achieved commercial operations in June 2023 and October 2023, respectively (refer to Section 4.1: Significant Events of this
MD&A for more information).
In addition to operational assets, summarized below are Northland’s most significant projects under construction and
development, as well as other identified projects. Management continuously assesses the development projects pipeline to
determine their feasibility, alignment with the Company’s investment criteria, and development stage. For this reason, the
development pipeline below and the respective gross production capacities will change as projects move through various
stages of their development cycles and are added or removed from the list.
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Project
Geographic
Region
Technology
Gross
Capacity
(MW)
Current
ownership
Development
Stage
Contract type
Estimated
COD
Construction Projects
Hai Long (1) (7)
Taiwan
Offshore wind
1,022
Baltic Power (7)
Poland
Offshore wind
1,140
Canada
Energy Storage
250
Identified Growth Projects
Oneida (2)
Total
Alberta
Renewables
ScotWind
Round 3 (5)
South Korea
Renewables
Total
Additional Pipeline
Various (3)
Canada
Solar
Scotland
Offshore wind
Taiwan
Offshore wind
South Korea
Offshore wind
2,412
1,150
2,340
500
3,450
7,440
31%
49%
72%
Under
construction
Under
construction
Under
construction
30-year PPA (6)
2026/2027
25-year CfD (4)
20-year capacity
contract
2026
2025
100%
Mid-stage
76%
51%
Early-stage
Early-stage
100%
Early-stage
2026 - 2030+
Various
2,177
Early-stage
TBD
Total Pipeline
(1) On December 28, 2023, Northland’s indirect equity interest in Hai Long offshore wind project reduced to 30.6% after the sell-down transaction close.
12,029
(2) In May 2023, the Oneida energy storage project reached financial close and moved to construction stage.
(3) Various include 2,177MW of other early-stage pipeline projects.
(4) CfD means Contract for Difference, a subsidy mechanism in which the difference between a fixed reference price and the market revenue is paid to
the project.
(5) Gross capacity represents a portion of Round 3 development pipeline. In July 2023 and September 2023, Northland completed its investment
partnership agreements with Gentari (as defined herein) through a sell-down of 49% stakes in each of NorthWind and CanWind offshore wind
projects, respectively.
(6) Hai Long 2A (294MW) has a FIT for 20 years. Hai Long 2B (224MW) and Hai Long 3 (504MW) have CPPA for 30 years.
(7) In September 2023, Hai Long and Baltic Power offshore wind projects reached financial close and moved to construction stage.
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SECTION 4: CONSOLIDATED HIGHLIGHTS
4.1: Significant Events
Significant events during 2023 and through the date of this MD&A are described below. Refer to SECTION 9:
CONSTRUCTION, DEVELOPMENT AND ACQUISITION ACTIVITIES of this MD&A for additional relevant information.
Balance Sheet:
Optimization of Spanish Portfolio’s Debt Facility
On December 21, 2023, Northland amended its Spanish portfolio’s debt agreement to optimize debt repayments and
address recent regulatory changes and market pool price volatility. As a result of this optimization, the debt repayment of
€21 million ($33 million) scheduled in the fourth quarter of 2023 was deferred to future periods.
Green Subordinated Notes
On June 21, 2023, Northland closed its inaugural offering of $500 million of Fixed-to-Fixed Rate Green Subordinated Notes,
Series 2023-A, due June 30, 2083 (the “Green Notes”). The Green Notes have a fixed coupon of 9.25% per annum until the
first reset date on June 30, 2028, and have an estimated after-tax cash cost in Euros to the Company of approximately 6.2%,
taking into consideration the benefit of a Canadian dollar to Euro hedge and applicable corporate tax deductions. The Green
Notes are rated BB+ by both S&P Global Ratings (“S&P”) and Fitch Ratings Inc. (“Fitch”) and benefit from 50% equity
treatment by both credit agencies.
Refinancing of EBSA’s Credit Facility
On March 30, 2023, as part of its long-term financing strategy for EBSA, Northland extended the maturity date of the EBSA
related non-recourse credit facility (the “EBSA Facility”) from December 15, 2024, to March 30, 2026. The EBSA Facility is
denominated in Canadian dollars, and Northland has hedged 100% of the principal amount against changes in the
Colombian peso. As part of the extension, the Company realized a hedge settlement gain of $22 million associated with the
financing, which offset a weaker Colombian peso since the loan was originally restructured in December 2021. The gain was
equally recognized in Northland’s Adjusted Free Cash Flow and Free Cash Flow over the four quarters of 2023.
On December 18, 2023, the EBSA facility was upfinanced by $190 million, to an aggregate amount of $711 million and the
maturity date was extended to December 18, 2026. The all-in average annual cost increased from 6.3% to 8.6%, due to a
combination of a higher estimated cost for Northland to maintain currency hedges to protect 100% of the Canadian dollar-
denominated debt balance against changes in Colombian peso, increased underlying interest rates, and slightly higher loan
margin. The increase in costs is expected to be more than offset by higher cash flows due to growth in and indexation of
EBSA’s regulatory asset base. EBSA’s operational currency (Colombian peso) is different than the currency denomination of
EBSA’s credit facility (Canadian Dollar), resulting in EBSA’s debt capacity being impacted by both the foreign exchange rate
and the growth in EBSA’s Colombian-peso denominated EBITDA. It creates an exposure to the foreign exchange rate which
Northland stabilizes through these maturity hedges. The Colombian peso has strengthened in 2023, leading to an increase
in EBSA's upfinancing capability that was offset by a hedge settlement outflow of $144 million while a $44 million excess
was distributed to Northland. There was no impact on Adjusted Free Cash Flow or Free Cash Flow as the upfinancing
proceeds are offset by expansionary capital investments scheduled at EBSA.
At-The-Market Equity Program
The Company’s “at-the-market” equity program (“ATM program”) was terminated in accordance with its terms upon the
expiry of the Company’s short form base shelf prospectus on July 16, 2023.
Prior to its termination, Northland issued 1,210,537 common shares under the ATM program in 2023 at an average price of
$34.43 per common share for gross proceeds of $42 million (net proceeds of $41 million).
Redemption of Series 3 Preferred Shares
On January 3, 2023, Northland completed the previously announced redemption of all 4,800,000 of its issued and
outstanding Cumulative Rate Reset Preferred Shares, Series 3 (the “Series 3 Preferred Shares”) at a price of $25.00 per
Series 3 Preferred Share together with all accrued and unpaid dividends of $0.3175 per Series 3 Preferred Share for an
aggregate total of $122 million.
Corporate Credit Rating Re-affirmed
In May 2023, Northland’s corporate credit ratings were reaffirmed at BBB (stable) by Fitch and BBB (stable) by S&P.
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Renewables Growth updates:
Northland remains disciplined in prioritizing projects within its development pipeline that are strategically and financially
consistent with its investment approach. The successful achievement of commercial operations of selected projects within
the Company’s pipeline is expected to deliver long-term, sustainable growth in the Company’s Adjusted EBITDA, Adjusted
Free Cash Flow and Free Cash Flow. The following provides updates on the progress of Northland’s active development
portfolio.
Hai Long Offshore Wind Project
On December 28, 2023, Northland closed its previously announced transaction with Gentari International Renewables Pte.
Ltd., a subsidiary of clean energy solutions company Gentari Sdn Bhd (“Gentari”), pursuant to which Gentari acquired 49%
of Northland’s 60% ownership in the Hai Long offshore wind project. Northland now holds a 30.6% ownership interest in
the overall project and will continue to take the lead role in Hai Long’s construction and operation. This transaction resulted
in Gentari contributing a final equity consideration of approximately NTD23 billion (equivalent to $1.0 billion) and assuming
its pro rata share of credit support for the project.
The accounting gain from the sell-down of Hai Long was recorded at $192 million, which includes $118 million of fair value
gain in respect of Northland’s retained interest in Hai Long in accordance with IFRS. Adjusted EBITDA and Free Cash Flow
sell-down gain of $74 million excludes this fair value gain in accordance with Northland’s non-IFRS financial measures
policy.
Hai Long’s total cost is projected to be approximately $9 billion, out of which NTD117 billion (equivalent to $5 billion) is
covered by non-recourse green financing provided by both international and local lenders with support from multiple
Export Credit Agencies (“ECAs”). The project is expected to generate approximately $1 billion in pre-completion revenues
during the construction phase and the balance of the equity investment has come from the project’s partners. Northland
has fully secured its equity investment through funds raised under its ATM program in 2022 and through the successful
completion of its 2023 sell-down transaction with Gentari.
Northland’s interest in Hai Long is expected to generate a five-year average of approximately $230 to $250 million of
Adjusted EBITDA and $75 to $85 million of Free Cash Flow per year once operational, delivering significant long-term value
for Northland’s shareholders. The weighted average all-in interest cost for the term of the financing is approximately 5% per
annum.
The Hai Long project continues to advance its construction activities with progress being made on the fabrication of
foundations, cables and onshore and offshore substations and preparatory works for further in-water construction during
the spring of 2024. Completion of construction activities and full commercial operations are expected in 2026/2027.
During the first quarter of 2023, the project signed an amendment to the Corporate Power Purchase Agreement (the
“CPPA”) that resulted in the extension of the CPPA tenor by two years from 20 to 22 years. During the third quarter of
2023, the project signed another amendment to the CPPA that extended its tenor by a further eight years from 22 to 30
years.
Baltic Power Offshore Wind Project
During the third quarter, Northland closed an equivalent of $5.2 billion, 20-year non-recourse green financing, supported by
a consortium of international and local commercial banks, multiple ECAs and multi-lateral agencies. The Baltic Power
project’s total cost is projected to be approximately $6.5 billion, with funding from its $5.2 billion non-recourse debt by the
project lenders and the remaining capital to be contributed by the project partners. Northland’s share of equity for the
project was fully funded through the Green Notes issuance in June 2023 and existing corporate liquidity. Northland’s
interest in Baltic Power is expected to generate a high-quality, inflation-protected five-year average Adjusted EBITDA of
approximately $300 to $320 million and $95 to $105 million of Free Cash Flow per year once operational, delivering
significant long-term cash flow for Northland’s shareholders.
The weighted average all-in interest cost for the term of the financing is approximately 5% per annum. In addition,
Northland has entered into currency hedges to stabilize the Canadian dollar equivalent for most of its projected
distributions through 2038 and will enter into additional hedges on an ongoing basis, in line with Northland’s risk
management policies.
Northland holds a 49% ownership interest in Baltic Power, with its partner Orlen S.A. holding the remaining 51%. Early
construction activities have commenced, with the fabrication of certain key components (onshore substation, foundations
and export cables) underway. Full commercial operations are expected in the latter half of 2026. The project’s 25-year
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Contract for Difference (“CfD”) offtake agreement, is denominated in Euros and includes an inflation indexation feature
commencing with the base year 2021.
NorthWind and CanWind Offshore Wind Projects
During the third quarter of 2023, Northland executed an investment partnership agreement with Gentari, completing a 49%
stake sell-down in early-stage offshore wind development projects in Taiwan: NorthWind and CanWind. The partnership
with Gentari is an extension of the agreement formed in December 2022, as related to Hai Long. The transaction resulted in
Gentari holding a 49% indirect equity interest in these projects, and Northland holding a 51% interest.
Nordsee Cluster Offshore Wind Project
On May 25, 2023, Northland announced the sale of its 49% ownership stake in the Nordsee Cluster offshore wind portfolio
(“NSC”) to its partner on the portfolio, RWE Offshore Wind GmbH (“RWE”). The sale provided RWE with 100% ownership of
the projects for a cash consideration of approximately €35 million (equivalent to $50 million), which included a premium to
Northland’s costs incurred to date. The transaction transferred all assets, liabilities and committed contractual obligations
relating to NSC, to RWE. The sale of NSC is consistent with Northland’s strategy to prioritize projects within its development
pipeline that are strategically and financially consistent with its disciplined investment approach.
ScotWind Partnership
On May 9, 2023, Northland signed a partnership agreement with ESB, a leading Irish energy company, for a 24.5% interest
in Northland’s two offshore wind leases in Scotland with a total combined capacity of 2,340MW. The partnership with ESB
demonstrates a strong interest in ScotWind and in developing offshore wind in Scotland and provides an opportunity to
bring in a strong, long-term partner to share in the costs and help advance the development process.
Oneida Energy Storage Project
On December 21, 2022, the project successfully executed a 20-year Energy Storage Facility Agreement (“ESFA”) with the
Independent Electricity System Operator (“IESO”) that offers monthly capacity payments. The remainder of the revenue will
come from operating on the wholesale market. The project also finalized a battery supply agreement, and a long-term
service agreement with Tesla Inc., to supply key components and services, and an EPC agreement with Aecon Group Inc. for
designing, engineering and constructing the facility. On March 30, 2023, Northland and its partners signed a credit
agreement with an external lender, that will allow the project to access approximately $700 million in senior and
subordinated debt financing. On May 15, 2023, the Oneida energy storage project reached financial close, as the project
successfully completed all necessary financing conditions. Construction activities have commenced, including fabrication of
battery packs and transformers and pouring of foundation pads, and are progressing as per the construction plan.
Northland currently owns 72% of the project, which is being developed in partnership with NRStor Inc., Six Nations of the
Grand River Development Corporation and Aecon Group Inc. Full commercial operations for the project are expected to
commence in 2025. Northland’s interest in the project is expected to contribute a five-year average Adjusted EBITDA of
approximately $40 to $45 million and $15 to $20 million of Free Cash Flow per year once operational, towards Northland’s
financial results.
New York Onshore Wind Projects
In October 2023, the 112MW Bluestone and 108MW Ball Hill onshore wind projects commenced commercial operations
under the 20-year PPA with the New York State Energy Research and Development Authority (“NYSERDA”).
On December 19, 2023, Northland successfully secured final tax equity funding of US$219 million ($298 million) with a
conversion of term loan on both the Bluestone and Ball Hill projects. Upon achieving the commercial operations of these
projects, Northland is deemed to have earned the investment tax credits of US$178 million ($242 million), 99% of which
were allocated to the tax equity partner, reducing the tax equity loan in the same amount as at December 31, 2023.
Following the conclusion of this tax equity investment, the financing structure of the projects comprises tax equity, back-
levered non-recourse debt and equity to fund the capital costs.
South Korean Offshore Wind Projects
Electricity Business Licenses (“EBLs”) for up to 1,270MW capacity at Dado have been secured, providing exclusivity over the
development areas. In addition, Northland’s second project, the 690MW Bobae project, has also been awarded the
requisite EBLs. Other development activities for the projects are continuing to advance.
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La Lucha Mexican Solar Project
Northland has completed all connection and energization activities relating to its 130MW La Lucha solar power project in
Mexico, with the project having achieved full commercial operations in June 2023. The project has been generating
revenues since being connected to the Mexican energy grid.
Other:
Update on the Hydrogen Business Unit
In the third quarter of 2023, Northland wound down its nascent Hydrogen BU to concentrate its resources and capital to its
core BUs (Onshore Renewables, Offshore Wind, and Efficient Natural Gas & Utilities). Northland will continue to evaluate
hydrogen and renewable fuels opportunities in the future that have the potential to optimize the Company’s existing
operating facilities and development projects, and as such will no longer show standalone hydrogen related opportunities in
its development projects pipeline.
Board of Directors
On November 29, 2023, Northland announced the expansion of its Board of Directors from nine to ten members and the
immediate appointment of Ellen Smith as a Director. Ms. Smith brings over 35 years of leadership experience within the
power and utilities sector.
Project Delivery Committee
During the fourth quarter of 2023, the Board of Directors formed a new subcommittee: the Project Delivery Committee.
The purpose of the Project Delivery Committee is to assist the Board of Directors with monitoring and overseeing projects
in which the Company has an interest during construction.
Executive Changes
On January 15, 2024, Northland announced several changes to its executive team. Pauline Alimchandani, CFO will be
departing the Company effective February 22, 2024, to pursue another opportunity. Until a new CFO is appointed, Adam
Beaumont, Vice President Finance & Head of Capital Markets, will oversee the finance function on an interim basis. David
Povall, Executive Vice President of Offshore Wind departed the company as well. Toby Edmonds will join Northland as
Executive Vice President of Offshore Wind, bringing essential offshore project execution and operational experience. In
addition, Yonni Fushman, who joined Northland in January 2023 as Chief Legal Officer and Executive Vice President of
Sustainability, has been promoted to Chief Administrative and Legal Officer and will continue to serve as Corporate
Secretary.
Facility Optimizations:
Thorold upgrade
In the second quarter of 2023, as part of the Ontario government’s energy transition and security policies, and consistent
with Northland’s strategy to optimize existing operating facilities to enhance value and performance, Northland continued
to advance the upgrade of its 265MW Thorold Co-Generation facility in Ontario, Canada. The optimization will result in an
increase to the electricity generating capacity of the facility by 23MW and an expected improvement in the facility’s heat
rate, which is expected to decrease overall emissions intensity at the facility without impacting Northland’s 2040 net zero
targets and will provide an additional fixed contract revenue stream for Northland from 2030 to 2035. The upgrade is
expected to be in service by the end of 2024. Concurrently, Northland completed the restructuring of Thorold’s project
debt, with (i) additional debt of $26 million to finance the upgrade; (ii) a decrease in all-in interest rate to 6.4% (previously
6.7%); and (iii) reduction of certain letter of credit requirements. Thorold will continue to operate under a dispatch model.
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4.2: Operating Highlights
The following table presents key IFRS and non-IFRS financial measures and operational results:
Summary of Consolidated Results
Year ended December 31,
FINANCIALS
Sales
Gross profit
Operating income
Net income (loss)
Net income (loss) attributable to common shareholders
Adjusted EBITDA (a non-IFRS measure) (2)
Cash provided by operating activities
Adjusted Free Cash Flow (a non-IFRS measure) (2)
Free Cash Flow (a non-IFRS measure) (2)
Cash dividends paid
Total dividends declared (1)
Total assets (3)
Total non-current liabilities (3)
Per Share
2023
2022
2021
$
$
2,232,779 $
2,021,041
741,157
(96,132)
(175,194)
1,239,871
785,214
497,978
423,744
205,072
303,469 $
2,448,815 $
2,178,389
1,050,784
955,457
827,733
1,398,176
1,832,983
460,892
380,472
196,845
284,582 $
2,093,255
1,879,762
782,148
269,879
189,559
1,137,004
1,609,295
386,366
307,401
172,755
264,200
13,626,298
14,222,609
$
7,867,559 $
7,589,484 $
12,871,816
8,501,560
Weighted average number of shares — basic and diluted (000s)
252,710
236,157
218,861
Net income (loss) attributable to common shareholders — basic and
diluted
Adjusted Free Cash Flow — basic (a non-IFRS measure) (2)
Free Cash Flow — basic (a non-IFRS measure) (2)
Total dividends declared
$
$
$
$
(0.72) $
1.97 $
1.68 $
1.20 $
3.46 $
1.95 $
1.61 $
1.20 $
0.82
1.77
1.40
1.20
ENERGY VOLUMES
Electricity production in gigawatt hours (GWh)
10,380
10,139
8,757
(1) Represents total dividends paid to common shareholders, including dividends in cash or in shares under Northland’s dividend reinvestment plan.
(2) See Forward-Looking Statements and Non-IFRS Financial Measures above. Further, note that non-IFRS measures during the three months and the
year ended December 31, 2023, include the effect of changes in the definition of non-IFRS measures. For a reconciliation of these non-IFRS financial
measures to the same measures before the definition changes refer to Section 5.7: Reconciliation to ‘Non-IFRS Measures Before Definition Change’.
(3) As at December 31.
22
| NORTHLAND POWER INC. |
| 2023 ANNUAL REPORT |
SECTION 5: RESULTS OF OPERATIONS
The following table summarizes operating results by technology and geography:
Three months ended December 31,
2023
2022
2023
2022
2023
2022
2023
2022
2023
2022
2023
2022
Electricity
production (GWh)
Sales
Operating
costs
Operating
income
Adjusted
EBITDA (2)
Adjusted
Free Cash Flow (1) (2)
Offshore Wind Facilities
1,444
1,482 $ 341,104 $ 339,248 $ 47,111 $ 45,079 $ 190,723 $ 193,116 $ 218,203 $ 220,960 $ 64,599 $ 71,436
Onshore Renewable Facilities
North America (3)
Spain
Efficient Natural Gas Facilities
Canada
Utilities
Colombia
451
287
738
375 $ 55,275 $ 49,043 $
8,649 $ 15,891 $ 19,666 $ 34,891 $ 29,743 $ 12,750 $ 11,308
(66,645)
258
33,858
633 $ 104,085 $ 132,251 $ 24,348 $ 21,810 $ 27,075 $ 67,942 $ 68,749 $ 96,706 $ 43,684 $ (55,337)
9,867 $
48,810
14,481
11,184
30,934
13,161
83,208
48,276
66,963
961
895 $ 88,455 $ 110,645 $ 20,646 $ 14,212 $ 30,405 $ 40,689 $ 44,265 $ 48,742 $ 22,152 $ 11,585
n/a
n/a $ 85,352 $ 64,018 $ 19,533 $ 14,628 $ 25,157 $ 19,683 $ 32,451 $ 27,272 $ 20,243 $ 31,716
Year ended December 31,
2023
2022
2023
2022
2023
2022
2023
2022
2023
2022
2023
2022
Electricity
production (GWh)
Sales
Operating
costs
Operating
income
Adjusted
EBITDA (2)
Adjusted
Free Cash Flow (1) (2)
Offshore Wind Facilities
4,438
4,486 $ 1,140,015 $ 1,259,247 $ 201,187 $ 169,756 $ 540,737 $ 703,479 $ 691,675 $ 800,404 $ 168,109 $ 228,813
Onshore Renewable Facilities
North America (3)
Spain
Efficient Natural Gas Facilities
Canada
Utilities
Colombia
1,311
991
2,302
1,364 $ 217,938 $ 216,495 $ 33,331 $ 31,013 $ 91,550 $ 100,742 $ 143,525 $ 145,235 $ 50,467 $ 53,933
(4,825)
79,761
2,345 $ 434,901 $ 485,746 $ 84,161 $ 73,845 $ 171,311 $ 244,450 $ 306,302 $ 365,165 $ 89,449 $ 49,108
143,708
219,930
269,251
216,963
162,777
50,830
38,982
42,832
981
3,430
3,308 $ 339,848 $ 425,572 $ 49,943 $ 43,215 $ 148,474 $ 169,279 $ 195,764 $ 245,652 $ 100,813 $ 118,923
n/a
n/a $ 302,241 $ 269,692 $ 70,013 $ 64,785 $ 88,007 $ 85,153 $ 117,196 $ 114,006 $ 75,441 $ 100,018
(1) Adjusted Free Cash Flow and Free Cash Flow are the same for operating facilities.
(2) See Forward-Looking Statements and Non-IFRS Financial Measures above. Further, note that non-IFRS measures during the three months and the year ended December 31, 2023, include the effect of
changes in the definition of non-IFRS measures. For a reconciliation of these non-IFRS financial measures to the same measures before the definition changes refer to Section 5.7: Reconciliation to ‘Non-IFRS
Measures Before Definition Change’.
(3) Onshore Renewables Facilities – North American geographical segment excludes Mexican La Lucha solar project because Northland monitors the financial performance of La Lucha separately for its
financial and operational decision-making.
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
23
5.1: Operating Results
Offshore Wind Facilities
Northland’s three operating offshore wind facilities, Gemini, Nordsee One and Deutsche Bucht, are located off the coasts of
the Netherlands and Germany, respectively. Wind power generation harnesses renewable wind energy by converting the
kinetic energy of wind into electrical energy. Wind facilities are subject to seasonality, and accordingly, tend to produce
more electricity during the first and fourth quarters due to denser air and higher winds compared to the second and third
quarters, the effect of which is reflected in the respective fiscal quarter’s results. In addition, variability in offshore wind
facilities results in similar fluctuations in quarter-to-quarter financial results. Factors such as exposure to market prices, and
turbine or grid availability can also have a significant effect on financial results. For the year ended December 31, 2023,
Gemini, Nordsee One and Deutsche Bucht contributed approximately 20%, 17% and 15%, respectively, to Northland’s
reported Adjusted EBITDA from facilities.
Results for Northland’s offshore wind facilities are also affected by foreign exchange rate fluctuations between the Euro and
Canadian dollar, which primarily affect sales, net income and Adjusted EBITDA. Northland has entered into long-term
foreign exchange rate hedges, at an average rate of $1.61/€ for 2023 compared to $1.59/€ for 2022 for a substantial
portion of anticipated Euro-denominated Adjusted Free Cash Flow, mitigating the effects of foreign exchange rate
fluctuations with respect to this metric.
Variability within Operating Results
Each of the offshore wind facilities participates in the power market and receives pool prices for their generation, which are
then topped-up through a subsidy mechanism to the target subsidy price, if the market revenue is below the subsidy target
price:
•
•
Gemini has revenue agreements with the Government of the Netherlands which expire in 2031. Under these
agreements, the subsidy mechanism (“SDE”) effectively tops up the revenue to €169/MWh for 2,385GWh of
generation.
Nordsee One and Deutsche Bucht have revenue contracts with the German government under the German
Renewable Energy Sources Act (the “EEG”), whereby the top-up mechanism ensures a minimum fixed unit price of
€194 and €184, respectively, per MWh generated.
The subsidy mechanisms comprise other provisions that can impact the facilities’ results:
•
•
•
•
The SDE is subject to an annual contractual floor price (the “SDE floor”), thereby exposing Gemini to market price
risk if the Dutch wholesale market price (“APX”) falls below the effective annual SDE floor of €51/MWh. As of
December 31, 2023, the APX price for the year was €96/MWh.
The SDE fixes the revenue at €169/MWh for 2,385GWh of generation, but due to the settlement’s formula, it is paid
on the first 1,908GWh. As a result, typically the revenue per MWh reported is higher in the first three quarters and
lower in the last quarter of the year. However, it is only a matter of timing and the revenue averages to €169/MWh
on an annual basis.
◦
◦
If the facility produces more than 2,385GWh in the year, the additional volume produced earns the yearly
average captured price (“CP”).
If the facility produces less than 2,385GWh in the year, the asset effectively receives the subsidy for a
volume higher than the actual volume produced.
The subsidy received on 1,908GWh is equal to [(€169 * 1.25) — (CP * 1.25)]. This calculation is applicable for every
MWh up to 1,908GWh. The yearly average CP is effectively calculated by reducing the APX with the Profile and
Imbalance (“P&I”) factor, that accounts for the profile of the generation and the costs associated with grid
balancing. The annual P&I factor is adjusted quarterly based on Gemini’s own data. The final P&I factor number is
officially published by the Netherlands Enterprise Agency in the subsequent year.
Under the EEG mechanism, the tariff compensates for most of the production curtailments the system operator
requires. However, the facilities do not receive revenue for periods where the market power price remains negative
for longer than six consecutive hours (“negative prices”).
Under the EEG, the facilities are also subject to unpaid curtailments by the German system operator for scheduled
and unscheduled grid repairs (“grid outages”) of up to 28 days annually at each facility, which can significantly
24
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
affect earnings depending on the season in which the outages occur. In the fourth quarter of 2023, a TenneT grid
outage at Deutsche Bucht for 21 days resulted in a net loss of revenue of €10 million ($15 million).
Regulatory Market Price Cap Changes Effective from December 1, 2022, to June 30, 2023
In response to the unprecedented surge in energy prices across Europe for most of 2022, in September 2022, the EU
Council established a cap on market revenues on renewable energy producers effective from December 1, 2022, to June 30,
2023 (the “EU price cap”). Following the implementation of the EU price cap, any revenue above the contracted power
purchase price for each facility is capped. The EU price cap has not been extended by the Netherlands or Germany and the
revenues for 2023 were not impacted by this cap.
Operating Performance
An important indicator for performance of offshore wind facilities is the current and historical average power production of
the facility. The following tables summarize actual electricity production and the historical average, high and low, for the
applicable operating periods of each offshore facility:
Electricity production (GWh)
Gemini
Nordsee One
Deutsche Bucht
Total
Electricity production (GWh)
Gemini
Nordsee One
Deutsche Bucht
Total
Three months ended December 31,
2023 (1)
2022 (1)
Historical
Average (2)
Historical
High (2)
Historical
Low (2)
832
379
233
1,444
794
362
326
1,482
783
340
300
832
379
326
739
298
233
Year ended December 31,
2023 (1)
2022 (1)
Historical
Average (2)
Historical
High (2)
Historical
Low (2)
2,476
1,090
872
4,438
2,396
1,087
1,003
4,486
2,381
1,063
945
2,496
1,090
1,003
2,193
968
872
(1) Includes GWh produced and attributed to paid curtailments.
(2) Represents the historical power production since the commencement of commercial operation of the respective facility (2017 for Gemini and
Nordsee One and 2020 for Deutsche Bucht) and excludes unpaid curtailments.
Electricity production for the three months ended December 31, 2023, decreased 3% or 39GWh compared to the same
quarter of 2022, primarily due to an expected 21-day grid outage required by the TenneT for maintenance at Deutsche
Bucht, as well as higher unpaid curtailments due to negative prices and grid outages at German offshore wind facilities.
These declines were partially offset by higher production from Nordsee One and Gemini. Electricity production for the year
ended December 31, 2023, was largely in line with 2022.
Sales of $341 million for the three months ended December 31, 2023, increased 1% or $2 million, compared to the same
quarter of 2022, primarily due to foreign exchange gains due to the strengthening of the Euro, partially offset by the non-
recurrence of the unprecedented spike in market prices realized in 2022 and an expected 21-day grid outage required by
the TenneT for maintenance at Deutsche Bucht. Sales of $1,140 million for the year ended December 31, 2023, decreased
9% or $119 million compared to 2022, primarily due to the non-recurrence of the unprecedented spike in market prices
realized in 2022 by $165 million, P&I factor adjustment of $24 million and an expected 21-day grid outage required by the
TenneT for maintenance at Deutsche Bucht by $15 million. This decline was partially offset by the higher turbine availability
at Nordsee One following the completion of the rotor shaft assembly (“RSA”) replacement campaign in 2022, foreign
exchange gains due to the strengthening of the Euro and other items by $85 million. Further details are set forth in the
table below.
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
25
The following table summarizes certain factors other than wind resource that affected sales:
Three months ended December 31,
Year ended December 31,
2023
2,367
2022
6,513
$
Effect of Gemini APX hedge losses (1)
Lower turbine availability at Nordsee One (due to
RSA campaign)
Unpaid curtailment due to negative prices in
Germany
Unpaid curtailment due to grid outages in
Germany
P&I adjustment and other
(1) Realized APX hedge losses are not reported in Sales but do reduce Adjusted EBITDA and Adjusted Free Cash Flow.
27,889
10,177
3,125
1,966
630
—
—
—
$
$
$
$
$
$
2023
9,354
—
23,986
34,273
18,370
$
2022
21,647
8,112
4,270
9,258
—
(2) Above amounts represent Northland’s share only.
Operating costs of $47 million for the three months ended December 31, 2023, increased 5% or $2 million, compared to the
same quarter of 2022, primarily due to higher maintenance costs at offshore wind facilities. Operating costs of $201 million
for the year ended December 31, 2023, increased 19% or $31 million, compared to 2022, primarily due to the same factor
as above.
Operating income and Adjusted EBITDA of $191 million and $218 million, respectively, for the three months ended
December 31, 2023, decreased 1% or $2 million and 1% or $3 million compared to the same quarter of 2022, due to the
same factors as noted above. Operating income and Adjusted EBITDA of $541 million and $692 million, respectively, for the
year ended December 31, 2023, decreased 23% or $163 million and 14% or $109 million compared to 2022, due to the
same factors as noted above.
Operating results of each facility
The following table summarizes operating results by facility:
Three months ended December 31, 2023
Production
Non-curtailed production
Revenue per MWh (1) (2)
From market
From subsidy
Year ended December 31, 2023
Production
Non-curtailed production
Revenue per MWh (1) (2)
From market
From subsidy
Subsidy price
(1) Revenue from non-curtailed production only.
GWh
GWh
€/MWh
€/MWh
€/MWh
GWh
GWh
€/MWh
€/MWh
€/MWh
€/MWh
Total
Gemini
1,444
1,368
146
86
60
832
829
120
69
51
Total
Gemini
4,438
4,062
175
91
84
2,476
2,450
165
80
85
169
Nordsee One Deutsche Bucht
233
208
379
331
193
118
75
182
108
74
Nordsee One Deutsche Bucht
872
721
1,090
891
193
111
82
194
182
101
81
184
(2) Revenue from curtailed production amounted to €20 million ($29 million) and €74 million ($109 million) for the three months and the year ended
December 31, 2023, respectively, which factors in the effect of unpaid curtailment due to negative prices and grid outages in Germany.
For the three months and the year ended December 31, 2023, the revenue from the offshore wind facilities was in line with
the expectations:
•
•
The revenue per MWh on Nordsee One and Deutsche Bucht was stable for the non-curtailed production.
The revenue for Gemini averaged to approximately €169/MWh annually, outside of marketing fees. However, as
described above, the revenue was lower in the fourth quarter due to the fact that the subsidy is paid on the first
1,908GWh, which were mostly produced during the first ten months of the year.
26
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
Onshore Renewable Facilities
Northland’s onshore renewables comprise 1,345MW (at Northland’s share) of onshore wind and solar facilities located in
Canada, the United States of America, Mexico and Spain. Onshore wind facilities are similar in nature operationally to
offshore wind; however, with lower operating costs and generally lower wind resource. Solar power facilities have lower
fixed operating costs per unit of capacity than other renewable power technologies. Electricity production from solar
facilities tends to be less variable than wind but is limited to available sunlight, which is generally higher in the second and
third quarters than in the first and fourth quarters. For the year ended December 31, 2023, Northland’s onshore renewable
facilities in Canada and Spain contributed approximately 11% and 12%, respectively, to Northland’s reported Adjusted
EBITDA from facilities.
Spain revenue structure and regulatory changes
Northland’s Spanish portfolio is comprised of onshore wind (435MW), solar photovoltaic (66MW), and concentrated solar
(50MW) assets located throughout Spain. The Spanish portfolio operates under a regulated asset base framework that
guarantees a specified pre-tax rate of return of 7.4% for 20 sites and 7.1% for 13 sites, over the full regulatory life of the
facilities, regardless of settled wholesale power price (“pool price”).
The revenue for each facility has four components:
•
•
•
•
The return on investment (“Ri”), sized to complete the target return based on the market revenue assumed ex-ante
(the “posted price”);
The return on operations (“Ro”), sized to compensate a facility when its operating costs are higher than its market
revenues. To note, Ro is not being received in the current environment;
The market revenue, at pool prices; and
The “band adjustments”, which are an ex-post positive or negative settlement to compensate for the difference
between the market revenue, at pool prices and the revenue at the regulatory posted price. If the pool price is
lower than the regulatory posted price, the band adjustment mechanism adds the additional revenue to achieve a
reasonable return. Conversely, if the pool price is higher than the posted pool price, the band adjustment
mechanism reduces revenues in the period.
For a given year, both market revenue and the corresponding band adjustment are recognized in Adjusted EBITDA,
Adjusted Free Cash Flow and Free Cash Flow. However, the band adjustments are paid in the following years. Accordingly,
the current year’s cash distributions therefore depend only on the pool prices, capture rate, Ri and Ro components of
revenue.
The table below outlines revenue components from the Spanish asset portfolio included in the consolidated results.
Ri revenue
Market revenue
Band adjustment
Total revenue
Regulated Posted price per MWh
Market Revenue per MWh
Production (GWh)
Ri revenue
Market revenue
Band adjustment
Total revenue
Three months ended December 31,
Year ended December 31,
€
€
€
€
2023
9,920 €
16,431
6,967
33,318 €
109 €
57 €
287
2022
16,399
25,725
17,885
60,009
122
100
258
Three months ended December 31,
$
$
2023
14,532 $
24,070
10,208
48,810 $
2022
22,739
35,670
24,799
83,208
€
€
€
€
$
$
2023
40,655 €
68,649
39,382
148,686 €
109 €
69 €
991
2022
65,596
155,062
(24,082)
196,576
122
158
981
Year ended December 31,
2023
59,324 $
100,172
57,467
216,963 $
2022
89,847
212,389
(32,985)
269,251
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
27
Northland entered into long-term Euro denominated foreign exchange hedges, at an average rate of $1.58/€1 for 2023
compared to $1.42/€1 for 2022, which hedges the majority of projected distributions from the Spanish portfolio to mitigate
foreign exchange rate volatility, consistent with its corporate risk mitigation strategy.
Electricity production at the onshore renewable facilities for the three months ended December 31, 2023, was 17% or
107GWh higher than the same quarter of 2022, primarily due to the contribution from the recently completed New York
onshore wind projects which achieved commercial operation in October 2023 and higher wind resource across Spanish
onshore wind facilities, partially offset by lower wind resource at Canadian onshore renewable facilities. Electricity
production at the onshore renewable facilities for the year ended December 31, 2023, was 2% or 43GWh lower than 2022,
primarily due to lower wind resource at Canadian facilities, partially offset by the contribution from New York onshore wind
projects.
Sales of $104 million for the three months ended December 31, 2023, decreased 21% or $28 million compared to the same
quarter of 2022, primarily due to the lower pool prices and lower Ri revenue from the Spanish portfolio, partially offset by
the contribution from the recently completed New York onshore wind projects. Sales of $435 million for the year ended
December 31, 2023, decreased 10% or $51 million compared to 2022, primarily due to lower pool prices decreasing market
revenue and Ri by $112 million and $31 million, respectively, partially offset by the increase in band adjustments by $90
million from the Spanish portfolio, as well as the contribution of $9 million from New York onshore wind projects.
Operating income and Adjusted EBITDA of $27 million and $69 million, respectively, for the three months ended December
31, 2023, decreased 60% or $41 million and 29% or $28 million, respectively, compared to the same quarter of 2022,
primarily due to the same factors as above. Operating income and Adjusted EBITDA of $171 million and $306 million,
respectively, for the year ended December 31, 2023, decreased 30% or $73 million and 16% or $59 million, respectively,
compared to 2022 primarily due to the same factors as above.
Adjusted EBITDA from the Spanish portfolio of $34 million for the three months ended December 31, 2023, decreased 49%
or $33 million compared to the same quarter of 2022, primarily due to lower pool prices decreasing market revenue and Ri,
and lower band adjustments by $12 million, $8 million and $15 million respectively. Adjusted EBITDA from the Spanish
portfolio of $163 million for the year ended December 31, 2023, decreased 26% or $57 million compared to 2022, primarily
due to lower pool prices decreasing market revenue and Ri by $112 million and $31 million, respectively, partially offset by
the increase in band adjustments by $90 million. Free Cash Flow from the Spanish portfolio of $31 million for the three
months ended December 31, 2023, increased by $98 million compared to the same quarter of 2022, primarily due to higher
debt repayments in the fourth quarter of 2022, as well as the impact from a debt optimization completed in the fourth
quarter of 2023. Free Cash Flow from the Spanish portfolio of $39 million for the year ended December 31, 2023, increased
by $44 million compared to 2022, due to the same factors as above.
Efficient Natural Gas Facilities
The contractual structures of Northland’s efficient natural gas facilities ensure each facility’s gross profit is generally stable,
within a seasonal profile, regardless of production or sales levels, so long as the plant is available. Under certain revenue
agreements, the facility is reimbursed for certain costs of sales by the counterparty. For the year ended December 31, 2023,
Northland’s efficient natural gas facilities contributed approximately 15% of reported Adjusted EBITDA from facilities, with
the two largest facilities, North Battleford and Thorold accounting for approximately 13%.
Electricity production for the three months ended December 31, 2023, increased 7% or 66GWh, compared to the same
quarter of 2022, mainly due to higher market demand for dispatchable power. Electricity production for the year ended
December 31, 2023, increased 4% or 121GWh, compared to 2022, primarily due to the same factor as above.
Sales of $88 million for the three months ended December 31, 2023, decreased 20% or $22 million compared to the same
quarter of 2022, primarily due to lower natural gas prices resulting in lower energy rates. Sales of $340 million for the year
ended December 31, 2023, decreased 20% or $86 million compared to 2022, primarily due to lower margins triggered by
planned outages, in addition to the same factor as above.
Adjusted EBITDA of $44 million for the three months ended December 31, 2023, decreased 9% or $4 million, compared to
the same quarter of 2022, due to the same factors as above. Adjusted EBITDA of $196 million for the year ended December
31, 2023, decreased 20% or $50 million compared to 2022, primarily due to Kirkland Lake’s one-time management fee
received in 2022, in addition to the same factors as above.
Utility
Empresa de Energía de Boyacá S.A E.S.P (“EBSA”) holds the sole franchise rights for electricity distribution in the Boyacá
region of Colombia and is an electricity retailer for the regulated residential sector in the region. EBSA owns and operates
28
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
an extensive distribution network, serving about half a million customers. EBSA’s net sales are almost entirely regulated, of
which the vast majority is earned from its distribution business and the remainder primarily from its electricity retail
business. EBSA’s results are affected by exchange rate fluctuations between the Canadian dollar and the Colombian peso.
For 2023, Northland has hedged the foreign exchange rate at COP$3,347:CAD$1 (2022: COP$3,097:CAD$1) for nearly all of
the anticipated Colombian peso-denominated cash flow, mitigating the effects of fluctuations in the foreign exchange rate
on Adjusted Free Cash Flow. For the year ended December 31, 2023, EBSA contributed approximately 9% of reported
Adjusted EBITDA from facilities.
EBSA earns revenue by charging customers a rate approved under the regulatory framework administered by the local
regulator, the CREG. The rate charged is set for an expected five-year period and includes amounts retained by EBSA, as
retailer and distributor, and amounts passed through to other electricity system participants, such as the transmission
operator. EBSA’s portion of the rate is determined based on its asset base (i.e. the “rate base”), inflation indexation per the
established Colombian producer price index and a regulated weighted average cost of capital of approximately 12.09% for
an expected five-year period. The rate base takes into account the depreciated cost of existing equipment and anticipated
future investments for maintenance and growth. EBSA’s portion of the rate also includes standardized allowances set by the
regulator intended to cover fixed and variable operating costs. The rate is designed to ensure EBSA earns a predictable and
stable return.
Sales of $85 million for the three months ended December 31, 2023, increased 33% or $21 million compared to the same
quarter of 2022, primarily due to the higher market demand, rate escalations and foreign exchange gains as a result of the
strengthening of the Colombian peso. Gross profit of $54 million for the three months ended December 31, 2023, increased
25% or $11 million compared to the same quarter of 2022, primarily due to the same factors as above. Sales of $302 million
for the year ended December 31, 2023, increased 12% or $33 million compared to 2022, primarily due to the same factors
as above. Gross profit of $196 million for the year ended December 31, 2023, increased 5% or $10 million compared to
2022, primarily due to the same factors as above.
Operating income and Adjusted EBITDA of $25 million and $32 million, increased 28% or $5 million and 19% or $5 million
respectively, compared to the same quarter of 2022, primarily due to the same factors as above. Operating income and
Adjusted EBITDA of $88 million and $117 million, respectively, for the year ended December 31, 2023, increased 3% or $3
million and 3% or $3 million, respectively, compared to 2022, primarily due to the same factors as above.
For EBSA, non-expansionary capital expenditures are required to maintain its regulated asset base under the requirements
of the local regulator. Such expenditures are largely driven by the requirements of the regulatory framework, though the
timing of the capital expenditures can vary from year to year and can be seasonal, therefore, affecting Adjusted Free Cash
Flow as reported.
5.2: General and Administrative Costs
The following table summarizes Northland’s general and administrative (“G&A”) costs:
Corporate G&A
Operations G&A (1)
Total G&A costs
(1) Operations G&A is included in the respective segment’s Adjusted EBITDA and Adjusted Free Cash Flow presented in Section 5.1: Operating Results.
77,921
37,245
115,166
24,178
14,257
38,435
$
$
$
$
$
2023
Three months ended December 31,
2022
16,848
8,464
25,312
$
$
2023
Year ended December 31,
2022
54,820
29,143
83,963
$
Corporate G&A costs of $24 million and $78 million for the three months and the year ended December 31, 2023, were 44%
or $7 million and 42% or $23 million higher than the same periods of 2022, respectively, primarily due to increased
personnel costs and other costs supporting Northland’s projects and investments in the global platform.
Operations G&A costs of $14 million for the three months ended December 31, 2023, increased 68% or $6 million compared
to the same quarter of 2022, primarily due to projects entering commercial operations, including La Lucha solar project and
New York onshore wind projects. Operations G&A costs of $37 million for the year ended December 31, 2023, increased
28% or $8 million compared to the same period of 2022, primarily due to the same factors as above.
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
29
5.3: Growth Expenditures
The following table summarizes development costs (charged to expense under IFRS) and growth expenditures for non-IFRS
financial measures:
Three months ended December 31,
Year ended December 31,
Business development
Project development
Development overhead
Acquisition costs (1)
Development costs
Joint venture project development costs (2)
$
$
2023
6,674
7,523
12,680
138
27,015
958
Growth expenditures (3)
Growth expenditures on a per share basis
(1) Relates to successful acquisition costs only. Excluded from growth expenditures.
$
26,635
$
$
$
2022
11,365 $
6,789
6,219
138
24,511 $
273
24,646 $
$
2023
35,698
28,429
49,504
549
114,180
3,355
112,786
0.45
$
$
$
$
2022
26,859
15,824
34,639
895
78,217
3,098
80,420
0.34
(2) Includes Northland’s share of development costs incurred at Baltic Power, Chiba and other joint venture projects.
(3) Excludes acquisition costs but includes share of project development costs incurred by joint ventures. Excludes non-controlling portion of the
development costs for the three months and the year ended December 31, 2023 of $1.2 million and $4.2 million, respectively.
To achieve its long-term growth objectives, Northland deploys early-stage investment capital (growth expenditures) to
advance projects in its pipeline.
Growth expenditures are excluded from Adjusted Free Cash Flow. However, these growth expenditures reduce near-term
Free Cash Flow until projects achieve capitalization under IFRS but are expected to deliver sustainable growth in Free Cash
Flow over the long-run.
Business development costs are incurred to identify and explore prospective business and development opportunities,
which are expected to result in identifiable development projects intended to be pursued to completion. These may include
costs incurred for projects that ultimately may not be pursued to acquisition or to completion. Business development costs
for the year ended December 31, 2023, were higher compared to 2022, due to higher activities in the onshore renewables
business related to Alberta solar pipeline and Ontario energy storage. Such opportunities represent the majority of the
business development costs to date.
Project development costs are attributable to identified early- to mid-stage development projects that are likely to generate
cash flow over the long-run, though do not yet meet capitalization criteria under IFRS. For the year ended December 31,
2023, project development costs were higher than 2022, primarily due to spend towards projects such as ScotWind and
South Korea offshore. Refer to SECTION 9: CONSTRUCTION, DEVELOPMENT AND ACQUISITION ACTIVITIES for additional
information on identified development projects.
Development overhead primarily relates to personnel, rent and other office costs not directly attributable to specific
development projects. Development overhead reflects Northland’s resources and development offices in key target
jurisdictions focused on securing long-term growth opportunities in those jurisdictions. Development overhead costs for the
year ended December 31, 2023, were higher than 2022, primarily due to higher personnel and other costs in support of
Northland’s business development and project advancement. These costs also include the expansion of certain enabling
functions for the development teams, including the global Project Management Offices and Energy Origination teams as
examples.
Acquisition and transaction costs are generally third-party transaction-related costs directly attributable to an executed
business acquisition.
Northland’s primary focus will be to deliver the successful execution of the three key projects that achieved financial close
this year, the Hai Long and Baltic Power offshore wind projects and Oneida energy storage project.
5.4: Consolidated Results
The following discussion of the significant factors contributing to the consolidated financial results should be read in
conjunction with Northland’s audited consolidated financial statements for the year ended December 31, 2023.
30
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
Electricity production (GWh)
Sales
Less: Cost of sales
Gross profit
Expenses
Operating costs
General and administrative costs
Development costs
Depreciation of property, plant and equipment
Amortization of contracts and intangible assets
Finance lease income
Operating income
Finance costs, net
Impairment
Foreign exchange (gain) loss
Fair value (gain) loss on derivative contracts
Share of (profit) loss from equity accounted
investees
Other expense (income)
Income (loss) before income taxes
Provision for (recovery of) income taxes
Current
Deferred
Provision for (recovery of) income taxes
Net income (loss)
Net income (loss) attributable to common
shareholders per share - basic and diluted
Fourth Quarter
$
$
$
$
$
$
$
$
Three months ended December 31,
Year ended December 31,
2023
3,353
2022
3,009
2023
10,380
2022
10,139
626,221
$
641,115
$
2,232,779
$
2,448,815
59,867
67,544
211,738
270,426
566,354
$
573,571
$
2,021,041
$
2,178,389
112,643
38,435
27,015
156,619
14,510
96,123
25,312
24,511
146,645
13,966
408,822
115,166
114,180
595,600
57,015
351,995
83,963
78,217
571,090
53,611
349,222
$
306,557
$
1,290,783
$
1,138,876
2,780
$
269,794
$
10,899
741,157
11,271
$
1,050,784
2,670
219,802
111,113
163,169
(3,570)
190,198
265,599
(183,212)
(323,495) $
87,177
—
(69,073)
(140,901)
(2,703)
382
321,812
163,169
(39,732)
303,898
279,849
(230,836)
323,109
—
(41,792)
(460,704)
2,857
(32,805)
394,912
$
(57,003) $
1,260,119
49,112
(104,689)
(55,577) $
(267,918) $
77,785
(6,795)
70,990
323,922
(1.13) $
1.12
143,554
(104,425)
$
39,129
(96,132) $
203,376
101,286
304,662
955,457
(0.72) $
3.46
$
$
$
Sales of $626 million decreased 2% or $15 million compared to the same quarter of 2022, primarily due to lower revenue
from Spanish portfolio and efficient natural gas facilities, partially offset by the contribution from the recently completed
New York onshore wind projects and higher revenue from EBSA due to higher market demand and rate escalations.
Gross profit of $566 million decreased 1% or $7 million compared to the same quarter of 2022, due to the same factors
impacting sales.
Operating costs of $113 million increased 17% or $17 million compared to the same quarter of 2022, primarily due to higher
maintenance cost across offshore and onshore operating facilities.
Corporate and Operational G&A costs of $38 million increased 52% or $13 million primarily due to increased costs and
resources to support Northland’s projects and global platform and additional projects entering operation during the period,
including La Lucha solar project and New York onshore wind projects.
Development costs of $27 million increased 10% or $3 million compared to the same quarter of 2022, primarily due to
timing of spending to advance development projects.
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
31
Finance costs, net (primarily interest expense) of $111 million increased 27% or $24 million compared to the same quarter
of 2022, primarily due to the issuance of the Green Notes, partially offset by scheduled repayments on facility-level loans
and higher loan repayments related to loan restructurings that occurred in 2022.
Fair value loss on derivative contracts was $190 million compared to a $141 million gain in the same quarter of 2022,
primarily due to net movement in the fair value of derivatives related to interest rate and foreign exchange contracts.
Foreign exchange gain of $4 million was primarily due to unrealized gain from fluctuations in the closing foreign exchange
rates.
Other income of $183 million increased by $184 million compared to the same quarter of 2022, was primarily due to the
accounting gains recorded as a result of the sell-down of Hai Long offshore wind projects to Gentari in the fourth quarter of
2023. The sell-down transaction was treated as a disposition of a business interest under IFRS. Please refer to Section 4.1:
Significant Events for further information.
Impairment expense of $163 million represents goodwill write-off related to the Spanish portfolio. As communicated
previously, the recent regulatory framework changes are not expected to impact the overall regulatory return over the life
of the Spanish portfolio. However, because of the fixed return construct of the regulatory regime in Spain, the benefits of
much higher-than-expected pool prices and cash flows received by Northland since its acquisition are being offset by lower
regulated cash flows over the remaining contractual life of the portfolio. The goodwill write-off reflects the diminished
value of lower future cash flows resulting from the fixed return regulatory framework.
Net loss of $268 million in the fourth quarter of 2023 compared to net income of $324 million in the same quarter of 2022,
was primarily as a result of the factors described above.
2023
Sales of $2,233 million decreased 9% or $216 million compared to 2022, primarily due to the non-recurrence of the
unprecedented spike in market prices realized in 2022 at Gemini, higher 2022 P&I factor adjustment in 2023, an expected
21-day grid outage required by the TenneT for maintenance at Deutsche Bucht and lower revenue generated from the
Spanish portfolio, partially offset by the contribution from the recently completed New York onshore wind projects.
Gross profit of $2,021 million decreased 7% or $157 million compared to 2022, due to the same factors impacting sales.
Operating costs of $409 million increased 16% or $57 million compared to 2022, primarily due to higher maintenance cost
across offshore and onshore operating facilities.
Corporate and Operational G&A costs of $115 million increased 37% or $31 million primarily due to increased costs and
resources to support Northland’s projects and global platform and additional projects entering operation during the period,
including La Lucha solar project and New York onshore wind projects.
Development costs of $114 million increased 46% or $36 million compared to 2022, primarily due to timing of spending to
advance development projects.
Finance costs, net (primarily interest expense) of $322 million is largely in line with 2022.
Fair value loss on derivative contracts was $304 million compared to a $461 million gain in 2022, primarily due to net
movement in the fair value of derivatives related to interest rate and foreign exchange contracts.
Foreign exchange gain of $40 million was primarily due to unrealized gain from fluctuations in the closing foreign exchange
rates.
Other income of $231 million increased 604% or $198 million, compared to 2022, primarily due to the gains associated with
offshore wind assets in Europe and Asia in 2023, partially offset by the gain on the sale of two efficient natural gas facilities
in 2022.
Impairment expense of $163 million represents goodwill write-off related to the Spanish portfolio. As communicated
previously, the recent regulatory framework changes are not expected to impact the overall regulatory return over the life
of the Spanish portfolio. However, because of the fixed return construct of the regulatory regime in Spain, the benefits of
much higher-than-expected pool prices and cash flows received by Northland since its acquisition are being offset by lower
regulated cash flows over the remaining contractual life of the portfolio. The goodwill write-off reflects the diminished
value of lower future cash flows resulting from the fixed return regulatory framework.
Net loss of $96 million in the year ended December 31, 2023 compared to net income of $955 million in 2022, was primarily
as a result of the factors described above.
32
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
5.5: Adjusted EBITDA
The following table reconciles net income (loss) to Adjusted EBITDA:
Net income (loss)
Adjustments:
Finance costs, net
Gemini interest income
Provision for (recovery of) income taxes
Depreciation of property, plant and equipment
Amortization of contracts and intangible assets
Fair value (gain) loss on derivative contracts
Foreign exchange (gain) loss
Impairment loss
Elimination of non-controlling interests
Finance lease (lessor)
Others (1)
Three months ended December 31,
2022
323,922
2023
(267,918) $
$
Year ended December 31,
2022
955,457
2023
(96,132) $
$
111,113
1,991
(55,577)
156,619
14,510
187,830
(3,570)
163,169
(71,813)
(1,291)
153,595
388,658
86,578
2,265
70,990
146,645
13,966
(147,414)
(69,073)
—
(73,692)
(1,511)
394
353,070
321,812
8,103
39,129
595,600
57,015
294,544
(39,732)
163,169
(258,202)
(5,609)
160,174
1,239,871
323,632
13,065
304,662
571,090
53,611
(482,351)
(41,792)
—
(272,407)
(6,352)
(20,439)
1,398,176
Adjusted EBITDA (2)
(1) Others primarily include Northland’s share of profit (loss) from equity accounted investees, Northland’s share of Adjusted EBITDA from equity
$
$
$
$
accounted investees, gains from partial asset sell-downs, acquisition costs and other expenses (income).
(2) See Forward-Looking Statements and Non-IFRS Financial Measures above. Further, note that non-IFRS measures during the three months and the
year ended December 31, 2023, include the effect of changes in the definition of non-IFRS measures. For a reconciliation of these non-IFRS financial
measures to the same measures before the definition changes refer to Section 5.7: Reconciliation to ‘Non-IFRS Measures Before Definition Change’.
Gemini interest income reflects 5% interest earned on Northland’s €108 million subordinated debt to Gemini. Under the
terms of the Gemini debt amendment completed in the fourth quarter of 2022, semi-annual principal payments to
Northland commenced in December 2022 until maturity in 2031. Northland consolidates the financial results of Gemini and,
as a result, Northland’s loan balances, investment income, and interest expense are eliminated upon consolidation. Gemini
interest income is included in Northland’s consolidated Adjusted EBITDA because it reflects returns generated from an
investment in core assets.
Fourth Quarter
Adjusted EBITDA of $389 million for the three months ended December 31, 2023, increased 10% or $36 million compared
to the same quarter of 2022. The significant factors increasing Adjusted EBITDA include:
•
•
$74 million in gains (calculated for non-IFRS financial measures) from the partial sell-down of Hai Long offshore wind
project to Gentari, including the historically incurred growth expenditures’ recovery due to sell-down; and
$7 million increase due to the contribution of New York Wind onshore wind facilities, which achieved commercial
operations in the fourth quarter of 2023.
The factors partially offsetting the increase in the Adjusted EBITDA were:
•
•
$33 million decrease in the contribution from the Spanish renewables portfolio, primarily due to the lower revenue, as
described in Section 5.1: Operating Results; and
$15 million increase in G&A costs and development expenditures, as described above in Sections 5.2: General and
Administrative Costs, and 5.3: Growth Expenditures.
Full Year
Adjusted EBITDA of $1,240 million for the year ended December 31, 2023, decreased 11% or $158 million compared to the
same period of 2022. The significant factors decreasing Adjusted EBITDA include:
•
$109 million decrease in operating results at the offshore wind facilities compared to 2022, primarily due to the non-
recurrence of the unprecedented spike in market prices realized in 2022, P&I factor adjustment and an expected 21-
day grid outage required by the TenneT for maintenance at Deutsche Bucht, partially offset by foreign exchange
fluctuations due to the strengthening of the Euro and other items;
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
33
•
•
•
$64 million increase in G&A costs and development expenditures, as described above in Sections 5.2: General and
Administrative Costs, and 5.3: Growth Expenditures;
$57 million decrease in the contribution from the Spanish renewables portfolio, primarily due to lower pool prices
decreasing market revenue and Ri by $112 million and $31 million, respectively, partially offset by the increase in band
adjustments by $90 million, as described in Section 5.1: Operating Results, and lower wind resource; and
$43 million decrease in contribution from Kirkland Lake primarily due to a one-time management fee received in
2022.
The factor partially offsetting the decrease in the Adjusted EBITDA was:
•
$115 million in gains from partial sell-down of development assets.
5.6: Adjusted Free Cash Flow and Free Cash Flow
The following table reconciles cash flow from operations to Adjusted Free Cash Flow and Free Cash Flow:
Cash provided by operating activities
$
135,869
$
550,689
$
785,214
$
1,832,983
Three months ended December 31,
Year ended December 31,
2023
2022
2023
2022
Adjustments:
Net change in non-cash working capital balances
related to operations
Non-expansionary capital expenditures
Restricted funding for major maintenance, debt
and decommissioning reserves
Interest
Scheduled principal repayments on facility debt
Funds set aside (utilized) for scheduled principal
repayments
Preferred share dividends
Consolidation of non-controlling interests
Investment income (1)
Proceeds under NER300 and warranty
settlement at Nordsee One
Others (2)
Free Cash Flow (3)
Add Back: Growth expenditures
Less: Historical growth expenditures’ recovery
due to sell-down
231,350
(141,244)
466,313
(289,875)
(1,947)
(8,200)
(142,890)
(323,800)
(10,675)
(6,531)
(112,927)
(439,185)
158,020
170,661
(1,573)
(22,194)
7,374
—
159,439
(2,954)
(31,707)
12,214
14,530
13,012
(3,215)
(11,435)
(325,841)
(705,119)
—
(6,103)
(87,380)
29,685
—
281,625
(56,248)
(17,857)
(336,356)
(839,614)
—
(11,206)
(75,217)
24,880
70,317
78,665
$
191,448
$
15,883
$
423,744
$
380,472
26,635
(26,794)
24,646
112,786
—
(38,552)
80,420
—
Adjusted Free Cash Flow (3)
(1) Investment income includes Gemini interest income and repayment of Gemini subordinated debt.
191,289
$
$
40,529
$
497,978
$
460,892
(2) Others mainly include the effect of foreign exchange rates and hedges, interest rate hedge, Nordsee One interest on shareholder loans, share of joint
venture project development costs, acquisition costs, lease payments, interest income, Northland’s share of Adjusted Free Cash Flow from equity
accounted investees, gains and losses from sell-downs of development assets, interest on corporate-level debt raised to finance capitalized growth
projects and other non-cash expenses adjusted in working capital excluded from Free Cash Flow in the period.
(3) See Forward-Looking Statements and Non-IFRS Financial Measures above. Further, note that non-IFRS measures during the three months and the
year ended December 31, 2023, include the effect of changes in the definition of non-IFRS measures. For a reconciliation of these non-IFRS financial
measures to the same measures before the definition changes refer to Section 5.7: Reconciliation to ‘Non-IFRS Measures Before Definition Change’.
Adjusted Free Cash Flow, is a supplementary non-IFRS cash flow measure including associated per share amounts and
payout ratios. Adjusted Free Cash Flow is calculated by excluding growth-related expenditures and adjusting for historically
incurred growth expenditures’ recovery due to sell-down, from Free Cash Flow. Management believes this measure
provides a relevant presentation of cash flow generated from the business before investment-related decisions (refer to
Section 5.3: Growth Expenditures for additional information). Management believes Adjusted Free Cash Flow is a
34
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
meaningful measure of Northland’s ability to generate cash flow, after on-going obligations, to reinvest in growth and fund
dividend payments. Reinvesting in growth is a key part of Northland’s long-term strategy.
Scheduled principal repayments on facility debt reflect repayments as paid. Funds set aside (utilized) for scheduled principal
repayments allocate repayments across the quarters in order to more clearly reflect the Company’s performance. Gemini’s
principal repayment schedule is weighted towards the first payment of the year to align with Gemini’s expected annual cash
flow profile, while Nordsee One, Deutsche Bucht and the Spanish portfolio’s principal repayments are equally weighted.
Northland’s share of scheduled principal repayments for Gemini, Nordsee One, Deutsche Bucht and the Spanish portfolio
are presented in the table below.
Select Scheduled Principal Repayments (at Northland’s share)
Gemini
Nordsee One
Deutsche Bucht
Spanish portfolio (1)
Total
(1) On December 21, 2023, Northland amended its Spanish portfolio’s debt agreement to optimize debt repayments and address recent regulatory
2024
96,383
88,119
78,853
47,524
310,879
2023
88,497
86,767
78,071
63,854
317,189
2022
127,103
88,411
76,507
124,603
416,624
€
€
€
€
€
€
changes and market pool prices volatility.
Interest expense is reflected each quarter as accrued in net income and working capital or paid.
Others mainly include gains and losses on sell-downs of development assets amounting to $120 million, interest income of
$62 million, foreign exchange hedge settlement of $50 million, interest rate hedge settlement of $36 million, and the
foreign exchange rates and hedges of $6 million.
The following table reconciles Adjusted EBITDA to Adjusted Free Cash Flow.
Adjusted EBITDA (2)
Adjustments:
Three months ended December 31,
2022
353,070
2023
388,658
$
$
Year ended December 31,
2022
1,398,176
2023
1,239,871
$
$
Scheduled debt repayments
Interest expense
Current taxes
Non-expansionary capital expenditure
Utilization (funding) of maintenance and
decommissioning reserves
Lease payments, including principal and interest
Preferred dividends
Foreign exchange hedge gain (loss)
Proceeds under NER300 and warranty settlement
at Nordsee One
EBSA Refinancing proceeds, net of growth capital
expenditures
Others (1)
Free Cash Flow (2)
$
Add back: Growth expenditures
Less: Historical growth expenditures’ recovery due
to sell-down
(129,002)
(52,309)
(46,558)
(1,938)
(6,816)
(2,365)
(1,574)
5,873
—
—
$
37,479
191,448
26,635
(26,794)
(225,131)
(37,235)
(70,309)
(9,266)
(6,092)
(2,996)
(2,954)
(18,730)
12,349
20,078
3,099
15,883
24,646
$
(579,445)
(195,328)
(137,460)
(3,016)
(10,044)
(8,677)
(6,103)
36,908
—
—
87,038
423,744
112,786
$
—
(38,552)
(684,630)
(220,347)
(192,953)
(48,094)
(16,550)
(10,353)
(11,206)
37,486
59,769
46,974
22,200
380,472
80,420
—
Adjusted Free Cash Flow (2)
(1) Others mainly include Gemini interest income, repayment of Gemini subordinated debt, interest rate hedge settlement, gains and losses from sell-
191,289
497,978
40,529
$
$
$
$
460,892
downs of development assets, and interest received on third-party loans to partners.
(2) See Forward-Looking Statements and Non-IFRS Financial Measures above. Further, note that non-IFRS measures during the three months and the
year ended December 31, 2023, include the effect of changes in the definition of non-IFRS measures. For a reconciliation of these non-IFRS financial
measures to the same measures before the definition changes refer to Section 5.7: Reconciliation to ‘Non-IFRS Measures Before Definition Change’.
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
35
Fourth Quarter
Adjusted Free Cash Flow of $191 million for the three months ended December 31, 2023, was 372% or $151 million higher
than the same quarter of 2022.
The significant factors increasing Adjusted Free Cash Flow were:
•
•
•
•
$96 million decrease in scheduled debt repayments primarily due to the Spanish portfolio, as discussed above;
$49 million gain from foreign exchange hedge settlements as a result of unwinding over hedged Euro positions;
$24 million decrease in current taxes primarily at offshore wind facilities and the Spanish portfolio as a result of lower
operating results; and
$36 million increase in Adjusted EBITDA primarily due to the factors described above.
The factors partially offsetting the increase in Adjusted Free Cash Flow were:
•
•
$20 million decrease primarily as a result of lower net upfinancing proceeds from EBSA due to settlement of realized
maturity hedge losses; and
$15 million increase in net finance cost primarily due to the higher short-term financing activity at Corporate, partially
offset by scheduled repayments on facility-level loans and higher loan repayments related to loan restructurings that
occurred in 2022.
Free Cash Flow, which is reduced by growth expenditures, totaled $191 million for the three months ended December 31,
2023, and was $176 million higher than the same quarter of 2022, due to the same factors as Adjusted Free Cash Flow.
Full Year
Adjusted Free Cash Flow of $498 million for the year ended December 31, 2023, was 8% or $37 million higher than 2022.
The significant factors increasing Adjusted Free Cash Flow were:
•
•
•
•
•
$105 million decrease due to scheduled debt repayments on facility level loans and higher loan repayments related to
loan restructurings in 2022;
$55 million decrease in current taxes primarily at offshore wind facilities and the Spanish portfolio as a result of lower
operating results;
$49 million gains from sales of offshore wind development assets in Europe and foreign exchange hedge settlements as
a result of unwinding over hedged Euro positions;
$25 million decrease in net finance costs primarily due to scheduled repayments on facility-level loans and higher loan
repayments related to loan restructurings in 2022; and
$22 million decrease primarily as a result of lower net upfinancing proceeds from EBSA due to settlement of realized
maturity hedge losses.
The factors partially offsetting the increase in Adjusted Free Cash Flow were:
•
•
•
$158 million decrease in contribution from operating facilities leading to lower Adjusted EBITDA primarily due to the
factors described above;
$47 million decrease primarily as a result of higher net proceeds from the EBSA refinancing recognized in 2022; and
$30 million net proceeds from the sale of two efficient natural gas facilities in April 2022.
Free Cash Flow, which is reduced by growth expenditures, totaled $424 million for the year ended December 31, 2023, and
was 11% or $43 million higher than the same period of 2022, due to the same factors as Adjusted Free Cash Flow.
36
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
The following table summarizes dividends paid, payout ratios as well as per share amounts:
Cash dividends paid to shareholders
Adjusted Free Cash Flow payout ratio — cash
dividends (1) (3)
Free Cash Flow payout ratio — cash dividends (1) (3)
Total dividends paid to shareholders (2)
Adjusted Free Cash Flow payout ratio — total
dividends (1) (2) (3)
Free Cash Flow payout ratio — total dividends (1) (2) (3)
Weighted avg. number of shares — basic and diluted
(000s)
Per share ($/share)
Dividends paid
Adjusted Free Cash Flow — basic and diluted (3)
Free Cash Flow — basic and diluted (3)
(1) On a rolling four-quarter basis.
Three months ended December 31,
Year ended December 31,
2023
51,740 $
2022
51,337 $
2023
205,072
$
2022
196,845
$
$
76,253
$
73,584 $
41 %
43 %
48 %
302,976
$
52 %
282,269
61 %
71 %
61 %
74 %
254,368
246,378
252,710
236,157
$
$
$
0.30 $
0.75 $
0.75 $
0.30 $
0.16 $
0.06 $
1.20
1.97
1.68
$
$
$
1.20
1.95
1.61
(2) Represents dividends paid in cash and in shares under the DRIP.
(3) See Forward-Looking Statements and Non-IFRS Financial Measures above. Further, note that non-IFRS measures during the three months and the
year ended December 31, 2023, include the effect of changes in the definition of non-IFRS measures. For a reconciliation of these non-IFRS financial
measures to the same measures before the definition changes refer to Section 5.7: Reconciliation to ‘Non-IFRS Measures Before Definition Change’.
At December 31, 2023, the rolling four quarter Adjusted Free Cash Flow and the Free Cash Flow net payout ratio was 41%
and 48%, respectively, calculated on the basis of cash dividends paid, compared to 43% and 52% for the same period ending
December 31, 2022, was largely in line with 2022. At December 31, 2023, the rolling four quarter Adjusted Free Cash Flow
and the Free Cash Flow net payout ratio was 61% and 71%, respectively, calculated on the basis of total dividends paid,
compared to 61% and 74% for the same period ending December 31, 2022, was largely in line with 2022.
5.7: Reconciliation to 'Non-IFRS Measures Before Definition Change'
The following table reconciles the revised non-IFRS financial measures to the same measures before the definition change
adopted in the second quarter of 2023:
Non-IFRS measures before definition
change
Effect of changes in non-IFRS measures:
Impairment of capitalized growth
projects
Gains from partial assets sell-down
Interest on corporate-level debt raised
to finance capitalized growth project
Three months ended December 31, 2023
Year ended December 31, 2023
Adjusted
EBITDA
Adjusted Free
Cash Flow
Free Cash
Flow
Adjusted
EBITDA
Adjusted Free
Cash Flow
Free Cash
Flow
$
314,928 $
176,428 $
176,587
$ 1,116,352 $
464,496 $
390,262
—
73,730
—
—
—
—
8,211
8,211
8,211
115,308
—
—
—
14,861
14,861
—
25,271
25,271
Revised non-IFRS measures
$
388,658 $
191,289 $
191,448
$ 1,239,871 $
497,978 $
423,744
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
37
SECTION 6: CHANGES IN FINANCIAL POSITION
The following table provides a summary of account balances derived from the audited consolidated statements of financial
position as at December 31, 2023 and December 31, 2022.
As at
Assets
Cash and cash equivalents
Restricted cash
Trade and other receivables
Other current assets
Property, plant and equipment, net
Contracts and other intangible assets, net
Derivative assets
Deferred tax asset
Investment in joint ventures
Other assets (1)
Liabilities
Trade and other payables
Loans and borrowings
Derivative liabilities
Deferred tax liability
Other liabilities (2)
Total Equity
December 31, 2023
December 31, 2022
$
$
$
$
$
642,478
171,023
396,014
97,468
9,179,933
446,870
388,997
44,726
899,885
1,358,904
13,626,298
449,461
7,065,534
127,895
590,259
910,425
9,143,574
4,482,724
13,626,298
$
$
$
$
$
1,299,833
160,142
549,637
90,515
9,377,584
515,775
751,975
27,240
441,565
1,008,343
14,222,609
959,213
6,971,722
105,975
697,577
763,849
9,498,336
4,724,273
14,222,609
(1) Includes goodwill, finance lease receivable, long-term deposits and other assets.
(2) Includes dividends payable, corporate credit facilities, provisions and other liabilities.
Significant changes in Northland’s audited consolidated statements of financial position were as follows:
•
•
•
•
•
Cash and Cash Equivalents decreased by $657 million primarily due to investments in Hai Long and Baltic Power
offshore wind projects, and the Oneida energy storage project, partially offset by proceeds from the Green Notes
offering and Hai Long sell-down.
Trade and other receivables decreased by $154 million primarily due to deposit settlement for the redemption of Series
3 Preferred Shares.
Property, plant and equipment decreased by $198 million primarily due to depreciation expense, partially offset by
construction-related activities and foreign exchange fluctuations.
Net derivative assets decreased $385 million from a net derivative asset at December 31, 2022, primarily due to the
effects of interest rates in Canada, the US and Europe, and strengthening of the Euro against the Canadian dollar.
Investment in joint ventures increased by $458 million primarily due to the investment in Hai Long and Baltic offshore
wind projects, partially offset by Hai Long sell-down to Gentari.
• Other assets increased by $351 million, primarily due to long-term shareholder loans provided to Hai Long and Baltic
Power offshore wind projects.
•
Loans and borrowings increased by $94 million, mainly due to the issuance of the Green Notes, refinancing of EBSA’s
credit facility, construction related drawdowns and foreign exchange fluctuations, partially offset by the scheduled
principal repayments on facility-level loans.
38
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
SECTION 7: EQUITY, LIQUIDITY AND CAPITAL RESOURCES
Northland maintains sufficient liquidity to meet short- and medium-term cash needs and ensures that it has access to
sufficient resources to capitalize on investment opportunities and to meet growth expenditure commitments, monthly cash
dividend requirements and other needs in the normal course of operations. Northland finances these commitments
through cash flow from operations, non-recourse project financing, securing partnerships and partner contributions,
corporate credit facilities, and debt and equity issuances from time to time.
Dividends
Northland’s Board of Directors and management are committed to maintaining the current monthly dividend of $0.10 per
share ($1.20 per share on an annual basis) and are confident that Northland has adequate access to funds to meet its
dividend commitment, including operating cash flows and corporate funds. The Board of Directors reviews the dividend
policy at least annually as part of Northland’s overall capital allocation strategy to balance growth requirements and
investor preferences.
Dividend Reinvestment Plan (“DRIP”)
The DRIP provides shareholders the right to reinvest their dividends in shares at a 3% discount to the market price as
defined in the DRIP. Shares issued under the DRIP can be sourced from treasury or purchased on the secondary market at
the election of Northland’s Board of Directors. Northland’s Board of Directors has the discretion to alter the discount or
source of shares issued under the DRIP.
Equity
The change in shares during 2023 and 2022 was as follows:
As at
Common shares
Shares outstanding, beginning of year
Equity offering
Shares issued under the LTIP
Shares issued under the DRIP
Total common shares outstanding, end of period
December 31, 2023
December 31, 2022
250,017,357
1,210,537
10,286
3,701,642
254,939,822
226,882,751
20,894,982
14,974
2,224,650
250,017,357
Preferred shares outstanding as at December 31, 2023, and December 31, 2022 were as follows:
As at
Preferred shares outstanding
Series 1
Series 2
Series 3
Total
December 31, 2023
December 31, 2022
4,762,246
1,237,754
—
6,000,000
4,762,246
1,237,754
4,800,000
10,800,000
In May 2023, Northland’s corporate credit ratings were reaffirmed at BBB (stable) by Fitch and BBB (stable) by S&P.
On January 3, 2023, Northland completed the previously announced redemption of all 4,800,000 issued and outstanding
Series 3 Preferred Shares at a price of $25.00 per Series 3 Preferred Share together with all accrued and unpaid dividends of
$0.3175 per Series 3 Preferred Share for an aggregate total of $122 million.
At December 31, 2023, Northland had 254,939,822 common shares outstanding (as at December 31, 2022 - 250,017,357)
with no change in preferred shares Series 1 and Series 2 outstanding from December 31, 2022.
As of February 21, 2024, Northland has 255,660,668 common shares outstanding with no change in preferred shares Series
1 and Series 2 outstanding from December 31, 2023.
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
39
Liquidity and Capital Resources
The following table reconciles Northland’s opening cash and cash equivalents to closing cash and cash equivalents:
Three months ended December 31,
Year ended December 31,
2023
2022
2023
2022
Cash and cash equivalents, beginning of period
$
720,907
$
1,533,904
$
1,299,833
$
673,692
Cash provided by operating activities
Cash provided by (used in) investing activities
Cash provided by (used in) financing activities
Effect of exchange rate differences
135,869
431,260
(684,708)
39,150
550,689
(311,826)
(526,310)
53,376
785,214
1,832,983
(1,170,053)
(262,044)
(10,472)
(629,683)
(604,837)
27,678
Cash and cash equivalents, end of period
$
642,478
$
1,299,833
$
642,478
$
1,299,833
Fourth Quarter
Cash and cash equivalents for the fourth quarter of 2023 decreased $78 million from September 30, 2023, due to cash used
in financing activities of $685 million, partially offset by cash provided by operating and investing activities of $136 million
and $431 million, respectively, in addition to the effect of foreign exchange translation of $39 million.
The decrease in cash and cash equivalents during the quarter was largely due to net repayment of borrowings, partially
offset by cash provided by operations, proceeds from sell-downs of development assets and foreign exchange rate
differences.
2023
Cash and cash equivalents for the year ended December 31, 2023, decreased $657 million due to $1,170 million of cash
used in investing activities, $262 million by financing activities and $10 million effect of foreign exchange translation,
partially offset by cash provided by operations of $785 million.
Cash provided by operating activities for the year ended December 31, 2023, was $785 million comprising:
•
•
$1,305 million in non-cash and non-operating items such as depreciation and amortization, finance costs, impairment,
changes in fair value of derivative contracts and deferred taxes; and
$280 million share of loss from equity accounted investees.
Factors partially offsetting cash provided by operating activities include:
•
•
•
$466 million in changes in working capital due to the timing of payables, receivables and deposits;
$237 million gain on change of ownership interest in subsidiaries / joint ventures and unrealized foreign exchange
(gain) loss; and
$96 million of net loss.
Cash used in investing activities for the year ended December 31, 2023, was $1,170 million, primarily comprising:
•
•
$1,404 million used mainly for the investment in the Hai Long and Baltic Power offshore wind projects; and
$441 million used for the purchase of property, plant and equipment, mainly for construction at New York onshore
wind projects, Oneida energy storage project and other projects.
Factors partially offsetting cash used in investing activities include:
•
•
$510 million mainly due to the proceeds from sell-downs of development assets; and
$129 million mainly from interest income and other investing activities.
Cash used in financing activities for the year ended December 31, 2023, was $262 million, primarily comprising:
•
•
•
$879 million in scheduled principal repayments on the facility-level debt;
$326 million in interest payments; and
$331 million of common and preferred share dividends as well as dividends to non-controlling interest.
40
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
Factors partially offsetting cash used in financing activities include:
•
•
•
•
•
$116 million of net draws on syndicated revolving facility for investment in Hai Long and Baltic Power offshore wind
projects and general corporate funding purposes;
$490 million received from the issuance of the Green Notes;
$618 million of draws on project level debt primarily for construction of the projects;
$41 million received from common shares issued under the ATM program; and
$62 million proceeds from issuance of shares in subsidiaries that do not involve loss of control.
Movement of foreign currencies, including primarily the Euro, U.S. dollar and Colombian peso, against the Canadian dollar
decreased cash and cash equivalents by $10 million for the year ended December 31, 2023. Northland aims to mitigate the
effects of exchange rate fluctuations through a variety of mechanisms, including foreign exchange hedges and natural
hedges by corporate debt denominated in USD or Euro for operating expenditures.
Property, Plant and Equipment
The following table provides a continuity of the cost of property, plant and equipment for the year ended December 31,
2023:
Operations:
Offshore wind
Onshore renewable
Efficient natural gas(2)
Utility
Construction:
Onshore renewable
Corporate
Total
Balance as at
Jan 1, 2023
Additions
Provisions,
disposals,
transfers and
other (1)
Exchange rate
differences
Balance as at
Dec 31, 2023
$
$
6,752,871 $
3,314,585
1,318,950
507,462
30,347 $
43,596
12,741
55,654
(27,675) $
786,424
(4,163)
12,092
65,745 $
15,075
—
117,098
6,821,288
4,159,680
1,327,528
692,306
870,008
100,247
12,864,123 $
77,761
270,363
490,462 $
(816,325)
(243,575)
(293,222) $
12,009
112
210,039 $
143,453
127,147
13,271,402
(1) Includes disposal of assets and amounts accrued under the long-term incentive plan (“LTIP”).
(2) Excludes Spy Hill lease receivable accounting treatment.
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
41
Long-term Debt
Northland’s operating facilities and projects under construction are financed primarily with non-recourse project debt with
fixed or hedged interest rates and repayment schedules tied to the terms of the project offtake agreement. Following the
commercial operations date, each project is structured as a special-purpose entity so that an adverse event at one facility
would not affect Northland’s other facilities. By owning and operating high-quality assets and applying its deep, long-term
experience, Northland expects to continue to enjoy a competitive cost of capital, which maximizes returns from growth
opportunities.
The following table provides a continuity of Northland’s debt for the year ended December 31, 2023:
Operations:
Offshore wind
Onshore renewable
Efficient natural gas
Utility
Construction:
Onshore renewable
Corporate:
Green Notes (2)
Corporate Credit Facilities (1)
Tax Equity
Total
Balance as at
Jan 1, 2023
Financings,
net of costs Repayments
Amort. of
costs/fair
value
Exchange
rate
differences
Balance as at
Dec 31, 2023
$
3,483,259 $
1,757,472
875,317
518,847
— $
154
10,842
195,638
(460,521) $
(162,078)
(46,013)
(317)
23,468 $
29,496
1,383
2,226
34,574 $
3,192
—
224
3,080,780
1,877,601
841,529
716,618
336,827
124,692
(210,356)
2,568
4,348
15,000
—
490,016
(2,817) 1,106,632
287,003
6,968,905 $ 2,214,977 $ (1,875,332) $
—
(996,047)
—
—
1,033
1,918
2,251
64,343 $
—
1,302
(546)
43,094 $
491,049
110,988
42,959
7,176,524
$
(1) Deferred financing cost associated with the syndicated revolving facility is included within the other assets in the consolidated statement of
financial position.
(2) On June 21, 2023, Northland closed its offering of $500 million ($490 million, net of transaction costs) Green Notes.
Additionally, as at December 31, 2023, $115 million of letters of credit were outstanding under non-recourse project-level
credit facilities for operational use.
During the year ended December 31, 2023, Northland entered into multiple financing arrangements. Refer to Section 4.1:
Significant Events for additional information.
Debt Covenants
Northland generally conducts its business activities indirectly through separate subsidiary legal entities and is dependent on
the distribution of cash from those subsidiary entities to fund development expenses, defray its corporate expenses, repay
corporate debt and pay cash dividends to its shareholders. Most operating subsidiaries hold non-recourse debt, which
typically prohibits distributions if the loan is in default (notably for non-payment of principal or interest) or if the entity fails
to achieve a benchmark debt service coverage ratio, which is the ratio of EBITDA to scheduled principal and interest
payments over a specified time period. As of December 31, 2023, Northland’s subsidiaries were in compliance with all
financial covenants under the applicable credit agreements. As of December 31, 2023, Northland was in compliance with all
financial covenants under the applicable credit agreements at the corporate level.
42
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
Corporate Credit Facilities and Letters of Credit
Northland’s corporate credit facilities are available for general corporate purposes, to support operational, construction
and development opportunities and to provide letters of credit issued on behalf of Northland. The corporate credit facilities
are summarized in the following table:
As at December 31, 2023
Sustainability linked loan syndicated revolving facility (1)
Bilateral letter of credit facility
Export credit agency backed letter of credit facility (2)
Export credit agency backed letter of credit facility (3)
Hai Long related LC facility (credit A) (6)
Total
Facility
size
$ 1,000,000 $
150,000
200,000
200,000
500,000
Amount
drawn (4)
115,656 $
Outstanding
letters of
credit (5)
361,057 $
133,746
89,291
42,168
475,936
—
—
—
—
$ 2,050,000 $
115,656 $ 1,102,198 $
Available
capacity
523,287
16,254
110,709
157,832
24,064
832,146
Maturity
date
Sep. 2028
Sep. 2024
Mar. 2025
n/a
Sep. 2027
(1) During the year ended December 31, 2023, the maturity date was extended to September 2028.
(2) During the year ended December 31, 2023, the Export credit agency backed letter of credit facility size was increased by $100 million and the
maturity date was extended to March 2025.
(3) With effect from December 29, 2023, the facility limit increased by $100 million. This facility does not have a specified maturity date.
(4) Deferred financing cost, as at December 31, 2023, associated with the syndicated revolving facility amounting to $5 million (December 31, 2022 - $3
million) is included within the other assets in the Consolidated Statements of Financial Position.
(5) As at December 31, 2023, outstanding letters of credit include LCs issued in favor of joint ventures amounting to $833 million.
(6) During the year ended December 31, 2023, Northland secured a $1.0 billion letter of credit facility to support construction-related obligations of the
Hai Long offshore wind project. The facility size was reduced to $500 million after close of the Hai Long sell-down to Gentari in December 2023.
Of the $1,102 million of corporate letters of credit issued as at December 31, 2023, $914 million relates to projects under
advanced development or construction.
Northland’s corporate credit facilities include provisions that allow for renewals at Northland’s option, subject to approval
by the lenders.
Northland had access to $584 million of available liquidity at December 31, 2023, including $61 million of cash on hand and
approximately $523 million of capacity on its corporate revolving credit facilities.
Exposure to LIBOR and EURIBOR
LIBOR and EURIBOR were the two key global benchmark rates used to determine interest rates and value government and
corporate bonds, loans, currency and interest rate swaps and many other financial products. Over the past several years,
global regulators have worked with industry groups and policymakers to identify and transition to more robust reference
rates. In Europe, regulators transitioned to a hybrid calculation methodology for EURIBOR. In the United States of America,
the secured overnight financing rate (“SOFR”) has replaced USD LIBOR and in Canada, the Canadian Overnight Repo Rate
Average (“CORRA”) is replacing the Canadian Dollar Offered Rate (“CDOR”). Effective June 30, 2023, CORRA was used for
new interest rate derivatives, and all loans referencing CDOR will transition to CORRA by June 28, 2024.
During 2023, Northland transitioned its USD-denominated loans and derivatives to SOFR and transitioned its corporate
loans and the EBSA-related financing agreement and derivatives to CORRA. Management is completing a CORRA transition
plan for its remaining derivatives and project-level financing agreements, which includes a comprehensive review of
financial exposures, proactive discussion with lenders and amendments to its financing agreements and derivatives to
preserve the intended economics. The transitions have not had and are not expected to have a material financial impact to
Northland.
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
43
Financial Commitments and Contractual Obligations
In the ordinary course of business, Northland enters into financial and derivative contracts. The contractual maturities of
Northland’s material financial liabilities as at December 31, 2023, are summarized in the following table:
2024
2025
2026
2027
2028
>2028
Derivative liabilities (1)
Euro foreign exchange contracts
$ 480,969 $
88,706 $ 189,719 $ 263,954 $ 311,570 $ 1,161,213
Colombian peso foreign exchange contracts
634,290
—
—
—
—
—
US dollar foreign exchange contracts
652,901
56,084
58,317
4,511
4,601
7,111
Taiwan dollar foreign exchange contracts
—
—
—
81,831
133,066
296,689
Facility-level debt at Northland’s share
Gemini
Nordsee One
Deutsche Bucht
Spain
Total in Euro
New York Wind
Total in Canadian dollar (2)
EBSA (3)
All other facilities (4)
€
88,583 €
93,040 € 101,896 € 109,242 € 111,698 € 238,663
88,119
78,853
84,093
91,091
60,463
92,824
—
93,875
—
71,174
—
228,697
47,429
39,641
41,004
42,728
41,762
318,234
€ 302,984 € 307,865 € 296,187 € 245,845 € 224,633 € 785,594
— US$ — US$ — US$ 32,434
US$ 5,868 US$ 176,506 US$
463,220
695,795
445,257
369,577
337,690 1,223,793
—
—
706,323
—
—
—
146,858
131,137
143,222
148,613
158,274
743,362
Total facility-level debt at Northland’s share
$ 610,078 $ 826,932 $ 1,294,802 $ 518,190 $ 495,964 $ 1,967,155
Interest payments including swap derivative
contracts
Corporate liabilities
233,448
204,004
162,174
110,390
91,584
239,953
Corporate credit facilities, including interest
5,583
4,099
3,975
4,096
119,893
—
Green Notes, including interest
—
—
—
—
208,125
500,000
Total
(1) Derivative liabilities are reported at 100% ownership.
(2) Using long-term foreign exchange rates.
(3) EBSA Facility is expected to be renewed annually.
$ 2,617,269 $ 1,179,825 $ 1,708,987 $ 982,972 $ 1,364,803 $ 4,172,121
(4) Other includes debt service costs of the efficient natural gas and onshore renewable facilities.
44
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
Non-Financial Commitments and Contractual Obligations
The following table summarizes all material fixed contractual commitments and obligations as at December 31, 2023, for
non-financial contracts. The amounts are based on long term inflation rate, where applicable, of 2.2% to 4.1%, a Canadian
dollar/Euro exchange rate of $1.50 and Canadian dollar/US dollar exchange rate of $1.32. The table includes maintenance
and services agreements and natural gas transportation demand charges for which Northland is liable whether or not
natural gas is shipped. The construction commitment primarily relates to the construction of Oneida energy storage project.
The cash obligations related to the leases for land and buildings, dismantlement and management fees to non-controlling
interest partners are also included.
Maintenance agreements
$ 217,130 $ 199,997 $ 191,520 $ 201,132 $ 673,422 $ 1,238,169
Construction and others; excluding debt, interest
and fees
454,670
52,620
—
—
—
—
Natural gas supply and transportation, fixed portion
26,360
26,475
26,730
27,195
27,669
169,136
2024
2025
2026
2027
2028
>2028
Leases
Decommissioning liabilities
Management fees
Total
18,562
32,920
18,507
33,181
17,012
33,481
16,964
31,856
16,908
32,053
193,485
434,177
4,749
77,227
$ 754,391 $ 335,182 $ 273,245 $ 281,741 $ 754,740 $ 2,112,194
4,688
4,594
4,502
4,402
Except in circumstances where the cancellation of the agreements would result in material penalties, the above table does
not include variable contractual obligations of Northland (which typically relate directly to production or meeting
performance criteria). Such obligations include natural gas purchase costs, variable natural gas transportation costs and
variable payments to maintenance providers. Except for certain onshore renewable and efficient natural gas facilities’ PPAs,
the electricity supply contracts contain no penalties for failure to supply.
As at December 31, 2023, Northland issued letters of credits and parental guarantees in an amount of $865 million in favor
of the joint ventures.
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
45
SECTION 8: SUMMARY OF QUARTERLY CONSOLIDATED RESULTS
Northland’s consolidated financial results are affected by seasonal factors, contract provisions and extraordinary items,
which result in quarterly variations. Northland’s quarterly net income (loss) also varies due to any non-cash impairments/
recoveries and foreign exchange adjustments required to translate Euro, US dollar and Colombian peso denominated
balances to the appropriate quarter-end Canadian dollar equivalent and due to fair value movements of financial derivative
contracts.
Accounting policies and principles have been applied consistently for all periods presented in the following table.
In millions of dollars, except per share
information
Q4
2023
Q3
2023
Q2
2023
Q1
2023
Q4
2022
Q3
2022
Q2
2022
Q1
2022
Total sales
Operating income (1)
Net income (loss)
Adjusted EBITDA
Cash provided by operating activities
Adjusted Free Cash Flow
Free Cash Flow
$
626 $
513 $
472 $
622 $
641 $
556 $
557 $
220
(268)
389
136
191
146
43
267
148
64
103
22
232
204
63
273
107
352
297
180
270
324
353
551
41
202
76
290
523
66
216
268
335
312
162
$
191 $
36 $
41 $
155 $
16 $
45 $
146 $
695
363
288
420
447
192
174
Per share statistics
Net income (loss) attributable to common
shareholders — basic
Net income (loss) attributable to common
shareholders — diluted
Adjusted Free Cash Flow — basic
Free Cash Flow — basic
Total dividends declared
$ (1.13) $ 0.14 $ 0.01 $ 0.27 $ 1.12 $ 0.33 $ 1.01 $ 0.99
(1.13)
0.14
0.75
0.75
0.25
0.14
0.01
0.25
0.16
0.27
0.72
0.62
1.12
0.16
0.06
0.33
0.28
0.19
1.01
0.70
0.63
0.99
0.84
0.77
$ 0.30 $ 0.30 $ 0.30 $ 0.30 $ 0.30 $ 0.30 $ 0.30 $ 0.30
(1) Included amortization of contracts and other intangible assets in the operating income.
46
I NORTHLAND POWER INC.I
I 2023 ANNUAL REPORT I
SECTION 9: CONSTRUCTION, DEVELOPMENT AND ACQUISITION ACTIVITIES
In addition to completed acquisitions and investments made this year, summarized below are Northland’s most significant
projects under construction and under development:
Hai Long Offshore Wind Project
In July 2022, Northland announced the signing of a CPPA that covers 100 percent of the power generated from Hai Long 2B
and 3, which have a combined capacity of up to 744MW. The agreement is with an investment grade counterparty (S&P:
AA-) and is for a 20-year period at a fixed-price, commencing once Hai Long reaches full commercial operations in late 2026.
The contracted price under the CPPA is more favourable than the fixed auction rate originally awarded in 2018 and is a key
accomplishment. In addition, the PPAs with Taipower are not affected by the signing of the CPPA and provide a backstop to
the CPPA. During the first quarter of 2023, the project signed an amendment to the CPPA that resulted in the extension of
the CPPA tenor by two years from 20 to 22 years. During the third quarter of 2023, the project signed another amendment
to the CPPA that extended its tenor by a further eight years from 22 to 30 years.
Northland’s interest in Hai Long is expected to generate a five-year average of approximately $230 to $250 million of
Adjusted EBITDA and $75 to $85 million of Free Cash Flow per year once operational, delivering significant long-term value
for Northland’s shareholders. The weighted average all-in interest cost for the term of the financing is approximately 5% per
annum., which is discussed above.
Hai Long is owned 60% by Northland and Gentari International Renewables Pte. Ltd., and 40% by Mitsui & Co. Ltd., and
Enterprize Energy Group. The project was allocated a total of 1,022MW (313MW net to Northland) by the Bureau of Energy
of Taiwan under a FIT program and an auction process in 2019. Key aspects of the Hai Long project are presented in the
following table:
Sub-project
Hai Long 2A
Hai Long 2B
Hai Long 3
Total
Gross Capacity (MW)
294
Net Capacity (MW) (1)
90
Type of Procurement
FIT
224
504
1,022
69
154
313
Auction
Auction
Estimated COD
2026/2027
2026/2027
2026/2027
(1) Represents Northland’s current 31% economic interest after the sell-down to Gentari.
Please refer to Section 4.1: Significant Events for further information.
Baltic Power Polish Offshore Wind Project
In March 2021, Northland completed its acquisition of a 49% interest in the Baltic Power offshore wind project in the Polish
Baltic Sea with a total capacity of 1,140MW of offshore wind generation.
In June 2021, Baltic Power secured a 25-year CfD from Poland’s Energy Regulatory Office under the Polish Offshore Wind
Act at a guaranteed price of PLN 319.60 per MWh, which is adjusted to annual indexation by Poland’s annual average
consumer price index. The project’s 25-year Contract for Difference (“CfD”) offtake agreement, is denominated in Euros and
includes an inflation indexation feature commencing with the base year 2021. Northland’s equity funding expectations and
returns remain in line with previously disclosed expectations as a result of the inflation indexation, which has offset the
impact of previously disclosed cost increases experienced. Please refer to Section 4.1: Significant Events for further
information.
Oneida Energy Storage Project
The Oneida Energy Storage Project is a 250MW/1GWh energy storage facility. Northland will be the majority owner and
take the lead role in its construction, financing and operation. Please refer to Section 4.1: Significant Events for further
information.
Thorold upgrade
In the second quarter of 2023, as part of the Ontario government’s energy transition and security policies, and consistent
with Northland’s strategy to optimize existing operating facilities to enhance value and performance, Northland continued
to advance the upgrade of its 265MW Thorold Co-Generation facility in Ontario, Canada. Please refer to Section 4.1:
Significant Events for further information.
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New York Onshore Wind Projects
Please refer to Section 4.1: Significant Events for further information.
La Lucha Mexican Solar Project
Please refer to Section 4.1: Significant Events for further information.
South Korean Offshore Wind Projects
The next step for each project is to progress engineering surveys and secure grid capacity as part of progressing to mid-
stage development. Other development activities for the projects are continuing to advance. Northland is pursuing
additional early-stage development opportunities located in South Korea’s Wando County for multiple projects with the
potential for up to 1.8GW of operating capacity. Please refer to Section 4.1: Significant Events for further information.
ScotWind Offshore Wind Project
In January 2022, Northland announced that it was awarded two offshore wind leases in the Crown Estate Scotland auction
with a total combined capacity of 2,340MW. The two leases, one fixed foundation (840MW) and one floating foundation
(1,500MW), will extend Northland’s development runway into the next decade, with commercial operations expected at
the end of 2029/2030 for the fixed and early 2030s for the floating. In April 2022, Northland entered into an Option Lease
Agreement with the Scottish government which provides the Company with development exclusivity over the two awarded
sites for a period of up to 10 years. Northland secured its right to the offshore region through the payment of £20 million
(equivalent to $32 million). Please refer to Section 4.1: Significant Events for further information.
Alberta Portfolio
In December 2022, Northland acquired a development platform and a portfolio of solar development projects in Alberta,
Canada, continuing its growth and leadership in renewable energy in Canada, which established Northland as a leading
developer in the province. Alberta is an attractive market for renewable development, being Canada’s only deregulated
electricity market, offering clear pricing to generators and strong consumer and industrial demand for offtake. The
acquisition adds a solar and energy storage pipeline encompassing approximately 1.2GW and 0.7GW, respectively.
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SECTION 10: OUTLOOK
Adjusted EBITDA
For 2024, management expects Adjusted EBITDA to be in the range of $1.20 billion to $1.30 billion, comparable to 2023
Adjusted EBITDA of $1.24 billion. The major factors expected to increase Adjusted EBITDA include (all amounts are
approximate):
•
•
•
•
Higher contribution from New York Onshore Wind Projects that commenced operations in the fourth quarter of
2023 and contribution from other onshore renewable assets as a result of normalized production ($30 million);
Higher contribution from offshore wind assets as a result of normalized production or outages ($20 million);
Lower development expenditures ($50 million) primarily as a result of focus on construction execution in 2024; and
Higher cash flows from EBSA results expected due to favourable foreign exchange rate ($20 million).
These factors will be offset by the non-recurrence of sell-down gains and development expenditure recovery recognized in
2023 related to offshore wind projects ($110 million).
Adjusted Free Cash Flow and Free Cash Flow
In 2024, management expects Adjusted Free Cash Flow to be in the range of $1.30 to $1.50 per share, down from $1.97 per
share in 2023. The major factors contributing to the year-over-year expected decline in Adjusted Free Cash flow include (all
amounts are approximate):
•
•
•
Lower gains from Hai Long sell-down and other transactional and hedging gains ($120 million);
Lower contribution from EBSA as a result of higher upfinancing proceeds in 2023 ($15 million); and
Lower interest income earned on temporary cash balances on hand ($15 million).
Factors expected to offset the aforementioned decreases include:
•
Higher contribution from New York Onshore Wind Projects that commenced operations in the fourth quarter of
2023 and contribution from other assets as a result of normalized production ($10 million - $15 million).
Management expects Free Cash Flow, which includes growth expenditures, to be in a range of $1.10 to $1.30 per share,
down from $1.68 per share in 2023. The reduction is due to the same factors noted above, partially offset by lower growth
expenditures. Development expenditures are expected to be approximately $60 million in 2024. This represents a lower
level of spend than in prior years as Northland focuses on the successful construction execution of its three key projects,
ceases all development activities in Mexico, Colombia and Japan, and focuses development expenditures on secured
projects in its pipeline including: ScotWind, the Korean offshore wind projects, the Alberta, New York and Ontario onshore
renewable energy opportunities. These development expenditures will reduce near-term free cash flow until the projects
achieve commercial operations but are expected to deliver accretive long-term growth in earnings and free cash flow.
Corporate G&A costs are expected to be $3 million lower than 2023, at approximately $75 million in 2024.
In addition, any gains from the future sell-down of ownership interests in development assets would be included in
Adjusted EBITDA, Adjusted Free Cash Flow and Free Cash Flow as they relate to capturing development profits at key
milestones. Currently, the 2024 guidance for Adjusted EBITDA, Adjusted Free Cash Flow and Free Cash Flow does not
incorporate any sell-down proceeds and as such, net proceeds from any sell-down would increase reported Adjusted
EBITDA, Adjusted Free Cash Flow, and Free Cash Flow in the event they occur in 2024.
Northland continues to implement a selective partnership strategy to sell interests in certain development projects on or
before financial close. In certain situations, Northland may decide to exit certain markets or reduce development activities
within certain jurisdictions. Northland will assess each opportunity individually and intends to remain a long-term owner of
the renewable power assets it develops.
Over the longer term, Northland remains positioned to achieve substantial growth in Adjusted EBITDA by 2027, upon
achieving targeted commercial operations of Oneida, Baltic Power and Hai Long, each with long-term contracted revenues
of between 20 to 30 years.
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The expected 2024 payout ratio, which may be closer to or above 100%, largely reflects the level of spending on growth
initiatives and the equity capital raised for our projects currently under construction, for which corresponding cash flows
will not be received until 2026 and 2027. Northland management expects that the Company will continue to pay dividends
annually at the rate of $1.20 per share.
Once the projects under construction, including Hai Long, Baltic Power, and Oneida battery storage, are fully completed,
they are collectively expected to deliver, on a five-year annual average basis, approximately $570 million to $615 million of
Adjusted EBITDA and $185 million to $210 million of Free Cash Flow by 2027.
With over 3 gigawatts (GW) of current gross operating capacity and a development pipeline of approximately 12GW,
including 2.4GW under construction and expected to be operational by 2026/2027, the Company is well positioned for an
accelerating global energy transition. Northland intends to be selective and pursue only projects within its pipeline that
meet its strategic objectives and targeted returns and closely monitor macroeconomic conditions surrounding renewables
development globally.
This Outlook is subject to the Forward-Looking Statements proviso in this document as well as the Risk Factors in the 2023
AIF.
SECTION 11: LITIGATION, CLAIMS AND CONTINGENCIES
Litigation, claims and other contingencies arise from time to time in the ordinary course of business for Northland. None of
these contingencies, individually or in aggregate, are expected to result in a liability that would have a material adverse
effect on Northland. Refer to Note 26 of the audited consolidated financial statements for additional information including
any contingencies arising as a result of completed acquisitions.
SECTION 12: ESG AND CLIMATE CHANGE
ESG at Northland
The focuses of Northland’s ESG framework are on continued decarbonization efforts through increasing our renewable
energy portfolio, continuously improving as an equitable employer where a talented, diverse and committed group of
people want to build their careers, creating meaningful and collaborative relationships and partnerships with local and
Indigenous communities, ensuring human rights are respected in our supply chain and upholding the highest standards of
good and responsible governance.
Northland continues to identify climate-related opportunities for access to capital, growth opportunities in new
technologies (such as energy storage), markets and human capital growth. Northland is committed to achieving a 65%
reduction of its greenhouse gas (“GHG”) emissions intensity by 2030 (from 2019 baseline) and to achieve net zero emissions
across its scope 1, 2 and 3 by 2040.
Climate-related risks and opportunities
As a growth company with a significant pipeline of development projects, Northland is focused on growing its renewable
energy portfolio to support ongoing global de-carbonization efforts. Building on its history of providing clean energy
solutions, Northland’s strategy reflects the demands and complexities of this transition in the short-, medium- and long-
term. Over the next 1 to 5 years Northland will leverage its existing portfolio and expertise to build out its pipeline of
offshore and onshore development projects in key markets across North America, Europe and Asia. Refer to the 2023 AIF
for a summary of regulatory developments in the markets where Northland operates.
Longer-term, the Company’s efforts are centered on expanding its offshore wind presence through continued development
of early-stage projects in Europe and Asia. In addition, Northland is also focused on establishing and expanding a position in
new emerging technologies such as energy storage. The goal is to create sustainable renewable and green infrastructure
assets that meet the energy demands for accessible and reliable energy, while supporting global emissions reduction
targets. Northland has also committed to reducing its own carbon intensity through the growth of its renewable energy
portfolio and its commitment towards making no further investment in efficient natural gas assets.
Northland recognizes the risks associated with climate (both from the transition to a lower carbon economy and from
changes in weather). Climate-related risks are assessed throughout the project lifecycle. Refer to the 2023 AIF for a
summary of certain climate-related risks, which include financial risks, ESG reporting risk, market and reputation risk, and
physical risks from climate change.
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Northland prioritizes risks as part of its decision-making process and incorporates them into its planning assumptions,
investment decision process, project development and operational processes. Northland employs a strategy that focuses on
identifying opportunities in key markets through project management, operations, market analysis, regulatory assessments,
and monitoring.
Northland continues to identify opportunities for access to capital, growth opportunities in new areas (such as energy
storage), markets and human capital growth. Northland continues to view climate-related risks as being associated with the
variability of results, risks from acute, chronic weather changes on its physical assets and the potential for increasing costs
due to more stringent regulatory and policy requirements.
Risk Management
Identification and assessment of climate-related risks are done throughout the project life cycle as well as considered as
part of the Enterprise Risk Management process and as part of the ESG Steering Committee. Northland’s risk identification,
assessment, response planning, reporting and monitoring are integrated into routine business activities, with ownership of
key risks delegated to the functional leads throughout the organization. Any identified risks are escalated to the Executive
Team and Board of Directors, and are monitored to ensure appropriate responses.
SECTION 13: FINANCIAL RISKS AND UNCERTAINTIES
Northland’s activities expose it to a variety of risks. Refer to the 2023 AIF for a summary of factors in addition to those
discussed below that could significantly affect the operations and financial results of Northland.
Northland’s risk management objective, as it relates to financial risks and uncertainties, is to mitigate fluctuations in cash
flows and ensure stable cash levels available to pay dividends to shareholders and fund growth. Northland does not seek to
mitigate fair value risk. Northland classifies financial risks into market risk, counterparty risk and liquidity risk, noting that
these risks can be impacted by geopolitical or regulatory uncertainties. Northland manages financial risks by identifying,
evaluating and mitigating in compliance with internal policies and external requirements under non-recourse project
financing arrangements. Northland uses derivative financial instruments to manage certain financial risks but does not
engage in speculative activity. Material financial risks are monitored and reported regularly to the Audit Committee of the
Board of Directors. The risks associated with Northland’s financial instruments and Northland’s policies for mitigating these
risks are described below. Refer to Note 18 of the 2023 Annual Report for additional information on Northland’s risk
management approach.
For information on Northland’s key risks, uncertainties, financial instruments and contractual commitments refer to
Northland’s 2023 Annual Report and the 2023 AIF filed electronically at www.sedarplus.ca under Northland’s profile.
Management does not believe there have been material changes in the business environment or risks faced by Northland
during the period that have not been disclosed in the 2023 Annual Report or the 2023 AIF.
Market Risk
Market risk is the risk that the fair value of Northland’s future cash flows will fluctuate because of changes in market prices.
Financial instruments affected by market risk include loans and borrowings and derivative financial instruments as well as
Northland’s preferred shares and the Green Notes. Revenue and supply contracts can also be affected by market risk. Types
of market risk to which Northland is exposed are discussed below.
(i) Interest Rate Risk
Interest rate risk refers to the risk that the value of a financial instrument or cash flows associated with the instrument will
fluctuate due to changes in market interest rates. Northland manages this risk by securing fixed-rate debt or entering into
interest rate swap agreements prior to or around the time of financial close that effectively convert floating rate interest
exposures to a fixed rate. In certain jurisdictions, such as Taiwan, Northland is unable to secure interest rate swaps for the
full tenor of underlying debt; in those cases Northland intends to manage this risk with rolling hedge strategies.
Changes in the fair value of interest rate swap contracts designated for hedge accounting are recorded in Northland’s
consolidated statements of comprehensive income (loss) to the extent that the hedge arrangements are effective. The fair
values for these interest rate swap contracts are based on calculations and valuation models using observable market rates.
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(ii) Credit Spread Risk
Credit spread risk as it affects Northland refers to the risk that the loan margin charged by current or future lenders (a
borrower-specific margin added to the underlying interest rate) will increase, making the cost of debt capital more
expensive. Credit spread risk cannot be hedged. Northland manages this risk by: (i) entering into long-term financings with
defined credit spreads over the amortization period whenever possible; (ii) ensuring loans are fully amortized (repaid) by
maturity; and (iii) monitoring credit markets and making prudent decisions about the timing and method of original
financings, refinancing and repricing opportunities.
(iii) Currency Risk
Currency risk arises because the Canadian dollar equivalent of transactions, assets or liabilities denominated in foreign
currencies may vary due to changes in foreign exchange rates. Northland is exposed to changes in the Euro, US dollar,
Colombian peso, Taiwan dollar, Polish Zloty, and to a lesser degree, other currencies on construction projects with expenses
in currencies different than the funding currency, or development expenses on early-stage projects in other jurisdictions.
Primary exposure to Northland arises from the Euro-denominated financial statements and cash distributions at Gemini,
Nordsee One, Deutsche Bucht, and the Spanish Portfolio, and Colombian peso-denominated financial statements and cash
distributions from EBSA, and development spending at the pipeline projects. Management manages this risk by hedging
material net foreign currency cash flows to the extent practical and economical to minimize material cash flow fluctuations.
Northland has entered into long-term foreign exchange contracts to fix foreign exchange conversion rates on the majority
of forecasted Euro-denominated cash inflows from Gemini, Nordsee One, Deutsche Bucht, the Spanish Portfolio, and Baltic
Power. Northland has entered into a short-term rolling hedge program to fix foreign exchange conversion rates on a portion
of distributions from EBSA and Hai Long.
(iv) Commodity Price Risk
Commodity price risk arises where: (i) PPA revenues or components of PPA revenues depend upon certain electricity
market indices; (ii) government subsidiary or feed-in-tariff programs define a floor price but electricity market prices may
exceed those floors; (iii) a portion of revenue is not contracted and subject to changes in electricity prices; (iv) PPA revenues
for efficient natural gas facilities are fixed, not linked to natural gas prices or the cost of natural gas is not substantively
passed through to the off-taker; (v) the value of a financial instrument or cash flows associated with the instrument
fluctuates due to changes in commodity prices; or (vi) the price of a component in a supply agreement is linked to the price
of one or several commodities.
Northland manages this risk by: (i) entering into PPAs that provide a fixed price for all, or substantially all, electricity
production, provide a price linked to commodity prices or include pass-through of commodity costs to the offtaker; (ii)
entering into financial power and natural gas hedges to stabilize contractual economics or protect against a specific risk,
including natural gas costs and electricity prices.
Northland has exposure to Dutch electricity market prices under Gemini’s PPA when the market price falls below the
contractual floor price. For the year ended December 31, 2023, the average wholesale market price was above the
contractual floor price, so the revenue was not impacted by this floor.
Northland has indirect exposure to German electricity market prices under the Nordsee One and Deutsche Bucht PPAs
whereby the facilities do not receive revenue for periods where the market power price remains negative for longer than
six consecutive hours.
Financial Counterparty Risk
Counterparty risk is the risk that a counterparty fails to perform its contractual obligations which could result in losses in
financial assets. Northland is exposed to counterparty risk in several areas including: (i) cash and cash equivalents held with
banks and financial institutions; (ii) counterparty exposures arising from: (a) contractual obligations, which include but are
not limited to sales contracts, equipment supply, delivery, installation and maintenance contracts, fuel supply and fuel
transportation agreements, energy marketing contracts and construction contracts, (b) derivative financial instruments, (c)
trade receivables due from customers, (d) loan receivables due from partners and other entities, and (e) claims payable by
an insurer; and (iii) unfunded loan commitments from financial institutions for the construction of projects. The maximum
exposure to counterparty risk, other than for the loan commitments, is equal to the carrying value of the financial assets.
Northland manages counterparty risk by contracting with highly creditworthy counterparties wherever possible, such as
government-related entities and large financial institutions. Northland’s cash, derivative financial instruments, unfunded
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loan commitments and insurance policies are contracted with creditworthy financial institutions. Northland’s gas,
transportation, equipment supply/ installation, maintenance and construction contracts are with highly rated and/or large,
well-capitalized counterparties wherever possible. Northland also manages counterparty risk by conducting comprehensive
initial credit analyses on potential counterparties to material and/or long-term contracts and monitoring counterparties
over time.
The nature of Northland’s business and contractual arrangements, and the quality of its counterparties generally serve to
minimize counterparty risk.
Liquidity Risk
Liquidity risk is the risk that Northland: (i) may not have sufficient funds to settle a transaction on the due date; (ii) may be
forced to sell financial assets or terminate financial liabilities at a value that is not the fair market value; or (iii) may be
unable to settle or recover a financial asset at all. Liquidity risk arises through an excess of financial obligations over
available financial assets at any point in time.
Northland manages liquidity risk to maintain sufficient cash or readily available funding in order to meet expected liquidity
requirements. Northland achieves this by: (i) maintaining prudent cash balances, availability under committed credit
facilities and access to capital markets; (ii) implementing financing structures and derivatives or hedging strategies that
minimize the risk of material cash flow impacts; and (iii) actively monitoring open positions to assess and proactively adapt
to possible market liquidity concerns.
Northland is also subject to internal liquidity risk because it conducts its business activities through separate legal entities
(subsidiaries and affiliates) and is dependent on cash distributions from those entities to defray corporate expenses and pay
dividends. Most operating subsidiaries hold non-recourse debt. Such non-recourse financing agreements typically prohibit
distributions if the loan is in default (notably for non-payment of principal or interest) or if the entity fails to achieve a
benchmark debt service coverage ratio, which is the ratio of Adjusted EBITDA to scheduled loan principal and interest
payments over a specified time period. For the year ended December 31, 2023, Northland and its subsidiaries were in
compliance with all debt covenants.
Northland will be required to refinance, renew or extend debt instruments as they become due. The ability to refinance,
renew or extend debt instruments is dependent on the capital markets up to the time of maturity and any credit ratings for
Northland at the relevant time, which may affect the availability, pricing or terms and conditions of replacement financing.
Refer to Note 26 in the audited consolidated financial statements for the year ended December 31, 2023, for additional
information related to Northland’s commitments and obligations.
Taxation
Income, withholding and sales tax laws in the jurisdictions in which Northland and its subsidiaries do business could change
in a manner that adversely affects Northland and its shareholders. Northland and its subsidiaries are also subject to various
uncertainties concerning the interpretation and application of domestic and international tax laws that could affect its
profitability and cash flows.
Recent tax developments that could have an adverse effect on Northland and its subsidiaries include, but are not limited to:
•
•
•
The tabling in Canada’s Parliament of legislation to implement interest limitation rules. The revised draft legislation
deferred Northland’s effective date of the Canadian interest limitation rules to January 1, 2024, at which point
Canadian interest deductions will be limited to 30% of tax EBITDA. Disallowed interest can be carried forward
indefinitely. This pending legislation was not substantively enacted as of December 31, 2023;
The tabling in Canada’s Parliament of legislation to address hybrid mismatch arrangements that would be effective
for Northland January 1, 2023. This pending legislation was not substantively enacted as of December 31, 2023;
and
The European Union member states announcing in December 2022 that they had reached an agreement in
principle on the introduction of Pillar Two, a 15% global minimum tax effective January 1, 2024. The Canadian
Department of Finance released its own Pillar II draft legislation in 2023, but it was not substantively enacted as of
December 31, 2023.
Northland undertakes all transactions for commercial reasons and strives to structure them in a tax-efficient manner. These
transactions and financing structures could be challenged by the Canadian and/or local tax authority. Before entering into
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these transactions and structures, legal and tax experts are engaged to ensure these transactions and structures are in
compliance with all tax laws, rules and regulations. A successful challenge by the Canadian or local tax authority to
transactions and structures entered into by Northland and its subsidiaries may have an adverse effect on Northland and its
Adjusted Free Cash Flow.
SECTION 14: CRITICAL ACCOUNTING ESTIMATES
Preparing the consolidated financial statements in conformity with IFRS requires management to make estimates and
assumptions that affect the reported amounts of assets, liabilities, income and expenses. Northland’s operating facilities
and investments primarily operate under long-term contracts with creditworthy counterparties. As a result, management
believes it is not exposed to critical accounting estimates to the same degree as merchant businesses of comparable size.
For Northland, the amounts recorded for depreciation of property, plant and equipment and contracts, fair value of
financial assets and financial liabilities, decommissioning liabilities, deferred development costs, leases, LTIP, impairment of
non-financial assets, income taxes and accounting for non-wholly owned subsidiaries are based on estimates and
management’s judgment. By their nature, these estimates are subject to measurement uncertainty, and changes in these
estimates may affect the audited consolidated financial statements of future periods. Estimates and accounting judgments
are based on historical experience, current trends and other assumptions that are believed to be reasonable under the
circumstances.
In making these estimates and judgments, management relies on external information and observable conditions where
possible, supplemented by internal analysis as appropriate. These estimates and judgments have been applied in a manner
consistent with that in the past two years and there are no known trends, commitments, events or uncertainties that
management believes will materially affect the methodology or assumptions utilized in this annual report.
Additional information on the significant estimates, judgments and assumptions that have the most significant effect on the
recognition and measurement of assets, liabilities, income and expenses are discussed in Note 3 in the audited consolidated
financial statements for the year ended December 31, 2023.
SECTION 15: FUTURE ACCOUNTING POLICIES
Management assesses each new IFRS or amendment to determine whether it may have a material impact on Northland’s
consolidated financial statements. As at December 31, 2023, there have been no accounting pronouncements by the
International Accounting Standards Board expected to materially affect Northland’s consolidated financial statements
beyond those described in Note 2.18 of the annual audited consolidated financial statements.
SECTION 16: CONTROLS AND PROCEDURES OVER FINANCIAL REPORTING
Management, including the President and Chief Executive Officer (“CEO”) and the Chief Financial Officer (“CFO”) are
responsible for establishing and maintaining adequate disclosure controls and internal controls over financial reporting as
defined under National Instrument 52-109 Certification of Disclosure in Issuers’ Annual and Interim Filings of the Canadian
Securities Administrators (“NI 52-109”).
Disclosure Controls and Procedures
Disclosure controls and procedures are designed to provide reasonable assurance that all relevant information is gathered
and reported to senior management, including the CEO and CFO, on a timely basis so that appropriate decisions can be
made regarding public disclosure.
An evaluation of the effectiveness of the design and operation of Northland’s disclosure controls and procedures was
conducted as of December 31, 2023, by and under the supervision of management, including the CEO and CFO. Based on
this evaluation, the CEO and CFO have concluded that Northland’s disclosure controls and procedures, as defined in NI
52-109, were effective as of December 31, 2023.
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Internal Controls over Financial Reporting
Management is responsible for establishing and maintaining adequate internal controls over financial reporting to provide
reasonable assurance regarding the reliability of financial reporting and the preparation of consolidated financial
statements for external purposes in accordance with IFRS.
Northland’s internal controls over financial reporting framework includes policies and procedures that are designed to
provide reasonable assurance regarding prevention or timely detection of unauthorized transactions that could have a
material effect on Northland’s consolidated financial statements, and provide reasonable assurance that transactions are
recorded as necessary to permit preparation of consolidated financial statements for external use purposes in accordance
with policies, procedures and IFRS.
In designing such controls, it should be recognized that due to inherent limitations, any control, no matter how well
designed and operated, can provide only reasonable assurance, not absolute, and may not prevent or detect all
misstatements. Further, projections of any evaluation of effectiveness to future periods are subject to the risk that controls
may become inadequate because of changes in conditions, or that the degree of compliance with the policies and
procedures may change. Additionally, management is required to use judgment in evaluating controls and procedures.
An evaluation of the effectiveness of the design and operation of Northland’s internal controls over financial reporting was
conducted as of December 31, 2023, by and under the supervision of the management, including the CEO and CFO using
the framework established in Internal Control – Integrated Framework published by the Committee of Sponsoring
Organizations of the Treadway Commission in 2013.
Based on this evaluation, the CEO and CFO have concluded that Northland’s internal controls over financial reporting were
effective as at the end of the fiscal year ended December 31, 2023.
Changes In Internal Control over Financial Reporting
There were no changes in the internal controls over financial reporting in the year ended December 31, 2023, that have
materially affected, or are reasonably likely to materially affect, Northland’s internal controls over financial reporting.
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Consolidated Financial
Statements
Northland Power Annual Report | 2023
56
Management’s Responsibility
Management is responsible for the preparation of Northland’s Consolidated Financial Statements and annual report.
Management has prepared the accompanying Consolidated Financial Statements in accordance with International Financial
Reporting Standards, and the financial information included in the annual report is consistent with the Consolidated
Financial Statements. Where appropriate, these Consolidated Financial Statements reflect estimates based on the
judgements of management. When alternative methods exist, management has chosen those it deems most appropriate in
the circumstances in order to ensure that the Consolidated Financial Statements are presented fairly, in all material
respects.
Management is responsible for the development and maintenance of systems of internal accounting and administrative
cost controls of high quality, consistent with a suitable cost. Such systems are designed to provide reasonable assurance
that the financial information is accurate, relevant and reliable and that Northland and its subsidiaries’ assets are
appropriately accounted for and adequately safeguarded.
The Board of Directors and Audit Committee (consisting of independent directors) are responsible for reviewing the
Consolidated Financial Statements of Northland and the accompanying management’s discussion and analysis and ensuring
that management fulfills its responsibilities for financial reporting.
Ernst & Young LLP, the independent auditor, have examined the Consolidated Financial Statements of Northland. The
independent auditor’s responsibility is to express a professional opinion on the fairness of the Consolidated Financial
Statements. The auditor’s report outlines the scope of their examination and sets forth their opinion on the Consolidated
Financial Statements. Their report as auditor is set out on page 58.
The Audit Committee of Northland meets periodically with management, internal auditors and the independent auditor to
discuss internal controls, auditing matters and financial reporting issues and to satisfy itself that each party is properly
discharging its responsibilities. The Audit Committee also reviews the Consolidated Financial Statements, management’s
discussion and analysis and the external auditor’s report; examines the fees and expenses for audit services; and considers
the engagement or reappointment of the external auditor. The Audit Committee reports its findings to the Board of
Directors for consideration prior to the issuance of the Northland Consolidated Financial Statements to the shareholders.
Ernst & Young LLP have full access to the Audit Committee and meet with the committee both in the presence of
management and separately.
(signed, Mike Crawley)
Mike Crawley
President and Chief Executive Officer
(signed, Pauline Alimchandani)
Pauline Alimchandani
Chief Financial Officer
Toronto, Canada
February 21, 2024
| NORTHLAND POWER INC. | | 2023 ANNUAL REPORT |
57
Independent Auditor’s Report
To the Shareholders of Northland Power Inc.
Opinion
We have audited the consolidated financial statements of Northland Power Inc. and its subsidiaries (the “Group”), which
comprise the consolidated statements of financial position as at December 31, 2023 and 2022, and the consolidated
statements of income (loss), consolidated statements of comprehensive income (loss), consolidated statements of changes
in equity and consolidated statements of cash flows for the years then ended, and notes to the consolidated financial
statements, including material accounting policy information.
In our opinion, the accompanying consolidated financial statements present fairly, in all material respects, the consolidated
financial position of the Group as at December 31, 2023 and 2022, and its consolidated financial performance and its
consolidated cash flows for the years then ended in accordance with International Financial Reporting Standards (“IFRS”).
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 are independent of the Group in accordance with the ethical requirements that are relevant to
our audit of the consolidated financial statements in Canada, and we have fulfilled our other ethical responsibilities in
accordance with these requirements. We believe that the audit evidence we have obtained is sufficient and appropriate to
provide a basis for our opinion.
Key Audit Matters
Key audit matters are those matters that, in our professional judgment, were of most significance in the audit of the
consolidated financial statements of the current period. These matters were addressed in the context of the audit of the
consolidated financial statements as a whole, and in forming the auditor’s opinion thereon, and we do not provide a
separate opinion on these matters. For each matter below, our description of how our audit addressed the matter is
provided in that context.
We have fulfilled the responsibilities described in the Auditor’s Responsibilities for the Audit of the Consolidated Financial
Statements section of our report, including in relation to these matters. Accordingly, our audit included the performance of
procedures designed to respond to our assessment of the risks of material misstatement of the consolidated financial
statements. The results of our audit procedures, including the procedures performed to address the matter below, provide
the basis for our audit opinion on the accompanying consolidated financial statements.
58
| NORTHLAND POWER INC. | | 2023 ANNUAL REPORT |
Key audit matter
How our audit addressed the key audit matter
Impairment of Goodwill, Contracts and other intangible assets, and Property, plant and equipment
As at December 31, 2023, the Group’s goodwill, contracts and
other intangible assets, and property, plant, and equipment were
$639 million, $447 million and $9,180 million, respectively. For
the year ended December 31, 2023, an impairment of $163
million was recorded with respect to goodwill. At each reporting
date, management assessed whether indicators of impairment
exist for any cash generating units (CGUs). Further, for CGUs with
lives,
goodwill and other
management assesses at least annually, or at any time if an
indicator of impairment exists, whether there has been an
impairment loss in the carrying value of these CGUs. When
performing
the
recoverable amount for each CGU or group of CGUs using the
higher of: (i) the value-in-use method; or (ii) the fair value less
costs of disposal method. The Group discloses significant
judgements, estimates and assumptions and the results of their
analysis in respect of impairment, in Notes 3 and 22 to the
consolidated financial statements.
the Group estimates
intangible assets with
impairment
indefinite
tests,
Auditing management’s impairment tests was complex, given the
degree of judgement and subjectivity in evaluating management’s
estimates and assumptions
in determining the recoverable
amounts of CGUs or group of CGUs. The significant assumptions
and inputs noted in the models whereby the net cash flow is
determined based on current business plans and budgets
approved by management were revenues, operating costs,
terminal values, capital expenditures and discount rates.
Based on our risk assessment, with assistance from our
valuation specialists, we performed the following
procedures, among others, on a
sample of
management’s cash generating unit impairment tests:
•
•
•
•
Assessed the appropriateness of revenues,
operating costs, capital expenditures and
terminal values by comparing them to executed
or expected power generation contracts and
regulatory power distribution rates, historical
results,
industry,
third-party data, current
market or economic trends and evidence
obtained in other areas of the audit;
the discount
Evaluated
management, which
comparable market data;
rates utilized by
assessing
involved
Performed
assumptions
recoverable amount of the CGU; and
sensitivity analysis on
to evaluate changes
certain
the
in
Assessed the adequacy of the disclosures
included
in Note 22 of the accompanying
consolidated financial statements in relation to
this matter.
Other Information
Management is responsible for the other information. The other information comprises:
• Management’s Discussion and Analysis
•
The information, other than the consolidated financial statements and our auditor’s report thereon, in the Annual
Report
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,
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.
We obtained Management’s Discussion and Analysis and the Annual Report prior to the date of this auditor’s report. 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 in this auditor’s report. We have nothing to report in this regard.
| NORTHLAND POWER INC. | | 2023 ANNUAL REPORT |
59
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 Group’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 Group or to cease operations, or has no realistic alternative
but to do so.
Those charged with governance are responsible for overseeing the Group’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
Group’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 Group’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 Group 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 Group 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.,
60
| NORTHLAND POWER INC. | | 2023 ANNUAL REPORT |
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.
From the matters communicated with those charged with governance, we determine those matters that were of most
significance in the audit of the consolidated financial statements of the current period and are therefore the key audit
matters. We describe these matters in our auditor’s report unless law or regulation precludes public disclosure about the
matter or when, in extremely rare circumstances, we determine that a matter should not be communicated in our report
because the adverse consequences of doing so would reasonably be expected to outweigh the public interest benefits of
such communication.
The engagement partner on the audit resulting in this independent auditor’s report is Scott Kerr.
Toronto, Canada
February 21, 2024
| NORTHLAND POWER INC. | | 2023 ANNUAL REPORT |
61
Consolidated Financial Statements
Table of Contents
Consolidated statements of financial position . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated statements of income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated statements of comprehensive income (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated statements of changes in equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Consolidated statements of cash flows . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Notes to the Consolidated Financial Statements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Business
1. Description of Northland's business . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
2. Summary of accounting policies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
3. Significant accounting judgments, estimates and assumptions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Financial Position
4. Property, plant and equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5. Contracts and other intangible assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
6. Goodwill . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
7. Leases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
8. Investment in joint ventures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
9. Trade and other receivables . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
10. Other non-current assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
11. Trade and other payables . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
12. Management of capital . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
13. Loans and borrowings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
14. Corporate credit facilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
15. Provisions and other liabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
16. Equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
17. Non-controlling interests . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
63
64
65
66
68
69
69
69
80
82
83
84
84
86
90
90
91
91
92
95
95
97
99
18. Financial risk management . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100
19. Financial instruments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 104
Performance
20. Net income (loss) per share . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 108
21. Finance costs (income), net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 108
22. Impairment of non-financial assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 109
23. Income taxes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 109
24. Operating segment information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 112
Other
25. Related-party disclosures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 115
26. Litigation, claims, contingencies and commitments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 116
62
| NORTHLAND POWER INC. | | 2023 ANNUAL REPORT |
Consolidated statements of financial position
In thousands of Canadian dollars
As at
Assets
Cash and cash equivalents
Restricted cash
Trade and other receivables (Note 9)
Other current assets
Derivative assets (Note 19.2)
Total current assets
Property, plant and equipment (Note 4)
Contracts and other intangible assets (Note 5)
Goodwill (Note 6)
Finance lease receivable (Note 7.1)
Derivative assets (Note 19.2)
Deferred tax asset (Note 23)
Investment in joint ventures (Note 8)
Other non-current assets (Note 10)
Total assets
Liabilities and equity
Trade and other payables (Note 11)
Loans and borrowings (Note 13)
Dividends payable (Note 16.4)
Current portion of provision and other liabilities (Note 15)
Derivative liabilities (Note 19.2)
Total current liabilities
Loans and borrowings (Note 13)
Corporate credit facilities (Note 14)
Provisions and other liabilities (Note 15)
Derivative liabilities (Note 19.2)
Deferred tax liability (Note 23)
Total liabilities
Equity
Common shares (Note 16.1)
Preferred shares (Note 16.3)
Contributed surplus
Accumulated other comprehensive income (loss)
Deficit
Equity attributable to shareholders
Non-controlling interests (“NCI”) (Note 17)
Total equity
Total liabilities and equity
See accompanying notes.
December 31, 2023
December 31, 2022
$
$
$
$
$
$
$
$
$
$
642,478 $
171,023
396,014
97,468
139,711
1,446,694 $
9,179,933
446,870
639,347
120,191
249,286
44,726
899,885
599,366
13,626,298 $
449,461 $
744,812
26,150
28,236
27,356
1,276,015 $
6,320,722
115,656
740,383
100,539
590,259
9,143,574 $
5,085,387 $
144,843
5,976
107,653
(1,158,682)
4,185,177 $
297,547
4,482,724 $
13,626,298 $
1,299,833
160,142
549,637
90,515
248,829
2,348,956
9,377,584
515,775
712,618
125,938
503,146
27,240
441,565
169,787
14,222,609
959,213
793,881
25,669
32,793
97,296
1,908,852
6,177,841
—
705,387
8,679
697,577
9,498,336
4,945,983
144,843
5,536
(4,040)
(701,140)
4,391,182
333,091
4,724,273
14,222,609
(signed, John W. Brace)
John W. Brace
Director and Chair of the Board
(signed, Kevin Glass)
Kevin Glass
Director and Chair of the Audit Committee
| NORTHLAND POWER INC. | | 2023 ANNUAL REPORT |
63
Consolidated statements of income (loss)
In thousands of Canadian dollars except per Share and Share information
Sales
Electricity and related products
Regulated electricity
Other
Total sales
Cost of sales
Fuel purchases
Regulated electricity purchases
Total cost of sales
Gross profit
Expenses
Operating costs
General and administrative (“G&A”) costs
Development costs
Depreciation of property, plant and equipment (Note 4)
Amortization of contracts and other intangible assets (Note 5)
Total expenses
Finance lease income (Note 7.1)
Operating income
Finance costs (Note 21)
Finance income (Note 21)
Impairment of non-financial assets (Note 6 and 22)
Foreign exchange (gain) loss
Fair value (gain) loss on financial instruments (Note 19.1)
Share of (profit) loss from equity accounted investees (Note 8)
Other (income) expense (Note 8)
Income (loss) before income taxes
Provision for (recovery of) income taxes (Note 23)
Current
Deferred
Total income taxes
Net income (loss)
Net income (loss) attributable to:
Non-controlling interests (“NCI”) (Note 17)
Shareholders of the Company (Note 20)
Net income (loss)
Weighted average number of shares outstanding - basic and diluted (000s) (Note 20)
Net income (loss) attributable to common shareholders per share - basic and diluted
See accompanying notes.
64
| NORTHLAND POWER INC. | 2023 ANNUAL REPORT |
Year ended December 31,
2023
2022
$
$
$
$
$
$
1,693,096 $
512,458
27,225
2,232,779 $
105,292
106,446
211,738 $
2,021,041 $
408,822
115,166
114,180
595,600
57,015
1,290,783 $
10,899
741,157 $
383,328
(61,516)
163,169
(39,732)
303,898
279,849
(230,836)
$
(57,003) $
143,554
(104,425)
39,129 $
(96,132) $
79,062
(175,194)
(96,132) $
252,710
(0.72) $
$
$
$
$
1,910,995
531,489
6,331
2,448,815
186,767
83,659
270,426
2,178,389
351,995
83,963
78,217
571,090
53,611
1,138,876
11,271
1,050,784
336,630
(13,521)
—
(41,792)
(460,704)
2,857
(32,805)
1,260,119
203,376
101,286
304,662
955,457
127,724
827,733
955,457
236,157
3.46
Consolidated statements of comprehensive income (loss)
In thousands of Canadian dollars
Net income (loss)
Items that may be re-classified into net income (loss):
Exchange rate differences on transaction of foreign operations
Change in fair value of hedged derivative contracts (Note 19)
Deferred tax recovery (expense) (Note 23)
Items that will not be re-classified into net income (loss):
Re-measurement of pension obligation
Other comprehensive income (loss)
Total comprehensive income (loss)
Total comprehensive income (loss) attributable to:
Non-controlling interests (Note 17)
Shareholders of the Company
Total comprehensive income (loss)
See accompanying notes.
Year ended December 31,
2023
(96,132) $
2022
955,457
248,539
(164,204)
19,713
31,076
425,702
(98,444)
(6,076)
97,972 $
1,840 $
3,161
361,495
1,316,952
65,341
(63,501)
1,840 $
213,295
1,103,657
1,316,952
$
$
$
$
| NORTHLAND POWER INC. | 2023 ANNUAL REPORT |
65
Consolidated statements of changes in equity
In thousands of Canadian dollars
December 31, 2022
$
4,945,983 $
144,843 $
(701,140) $
5,536 $
(4,040) $
4,391,182 $
333,091 $
4,724,273
Common
shares
Preferred
shares
Deficit
Contributed
surplus
Accumulated
other
comprehensive
income (loss)
Equity
attributable
to
shareholders
Non-
controlling
interests
Total
equity
Net income (loss)
Deferred tax recovery (expense) (Note 23)
Exchange rate differences on translation of
foreign operations
Change in fair value of hedged derivative
contracts (Note 19)
Re-measurement of pension obligation
Total comprehensive income (loss)
$
Long term incentive plan (Note 16.1)
Disposal or other adjustments (Note 17)
Increase in NCI arising on additional
contribution and dilution of interest in
subsidiaries (Note 17)
Common shares issued, net of costs
(Note 16.1)
Deferred tax on share issuance cost
(Note 16.1 and 23)
Dividends to NCI (Note 17)
Common share and dividends declared
(Note 16.1 and 16.4)
Preferred share dividends (Note 16.3)
December 31, 2023
See accompanying notes.
—
—
—
—
—
— $
279
—
—
40,908
313
—
97,904
—
—
—
—
—
—
(175,194)
—
—
—
—
— $
(175,194) $
—
—
—
—
—
—
—
—
—
—
27,224
—
—
—
(303,469)
(6,103)
—
—
—
—
(175,194)
79,062
(96,132)
19,002
19,002
711
19,713
245,319
245,319
3,220
248,539
—
(146,588)
(146,588)
(17,616)
(164,204)
—
— $
440
—
—
—
—
—
—
—
(6,040)
(6,040)
(36)
111,693 $
(63,501) $
65,341 $
(6,076)
1,840
—
—
—
719
—
—
719
(10,750)
(10,750)
27,224
29,808
57,032
—
40,908
—
40,908
—
—
—
—
313
—
313
—
(119,943)
(119,943)
(205,565)
(6,103)
—
—
(205,565)
(6,103)
$
5,085,387 $
144,843 $
(1,158,682) $
5,976 $
107,653 $
4,185,177 $
297,547 $
4,482,724
66
| NORTHLAND POWER INC. | | 2023 ANNUAL REPORT |
Consolidated statements of changes in equity - continued
In thousands of Canadian dollars
December 31, 2021
$
4,005,462 $
260,880 $
(1,233,085) $
3,586 $
(279,964) $
2,756,879 $
208,832 $ 2,965,711
Common
shares
Preferred
shares
Deficit
Contributed
surplus
Accumulated
other
comprehensive
income (loss)
Equity
attributable
to
shareholders
Non-
controlling
interests
Total
equity
Net income (loss)
Deferred tax recovery (expense) (Note 23)
Exchange rate differences on translation of
foreign operations
Change in fair value of hedged derivative
contracts (Note 19)
Re-measurement of pension obligation
Total comprehensive income (loss)
$
Long term incentive plan (Note 16.1)
Non-controlling interest disposal (Note 17)
Additional contribution provided by NCI
(Note 17)
Common shares issued, net of costs
(Note 16.1)
Deferred tax on share issuance cost
(Note 16.1 and 23)
Dividends to NCI (Note 17)
Common share and dividends declared
(Note 16.1 and 16.4)
Preferred shares transfer to current-liabilities
(Note 16.3)
Preferred share dividends (Note 16.3)
December 31, 2022
See accompanying notes.
—
—
—
—
—
— $
591
—
—
851,610
2,896
—
85,424
—
—
—
—
—
—
—
— $
—
—
—
—
—
—
—
827,733
—
—
—
—
827,733 $
—
—
—
—
—
—
(284,582)
(116,037)
—
—
(11,206)
—
—
—
—
827,733
127,724
955,457
(96,521)
(96,521)
(1,923)
(98,444)
22,067
22,067
9,009
31,076
—
347,260
347,260
78,442
425,702
—
— $
1,950
—
—
—
—
—
—
—
—
3,118
3,118
43
3,161
275,924 $
1,103,657 $
213,295 $ 1,316,952
—
—
—
2,541
—
—
—
3,446
1,320
2,541
3,446
1,320
—
851,610
—
851,610
—
—
—
—
—
2,896
—
2,896
—
(93,802)
(93,802)
(199,158)
—
(199,158)
(116,037)
—
(116,037)
(11,206)
—
(11,206)
$
4,945,983 $
144,843 $
(701,140) $
5,536 $
(4,040) $
4,391,182 $
333,091 $ 4,724,273
| NORTHLAND POWER INC. |
| 2023 ANNUAL REPORT |
67
Consolidated statements of cash flows
In thousands of Canadian dollars
Operating activities
Net income (loss)
Items not involving cash or operations:
Depreciation of property, plant and equipment (Note 4)
Amortization of contracts and other intangibles (Note 5)
Impairment of non-financial assets (Note 6 and 22)
Finance costs, net (Note 21)
Fair value (gain) loss on financial instruments
Unrealized foreign exchange (gain) loss
Loss (gain) on change of ownership interest in subsidiaries and joint ventures
(Note 8)
Deferred tax expense (recovery) (Note 23)
Share of (profit) loss from equity accounted invested (Note 8)
Other
Net change in working capital related to operations
Cash provided by (used in) operating activities
Investing activities
Purchase of property, plant and equipment
Additional equity contribution to the joint ventures
Acquisitions of contract and intangible assets, net (Note 5)
Purchase of contracts and other intangible assets (Note 5)
Proceeds from sell-down and divestment
Restricted cash utilization (funding)
Loans provided to joint ventures - net
Other
Cash provided by (used in) investing activities
Financing activities
Proceeds from borrowings, net of transaction costs (Note 12)
Repayment of borrowings (Note 12)
Interest paid
Restricted cash utilization (funding)
Common share dividends
Dividends to NCI (Note 17)
Preferred share dividends (Note 16.3)
Advance payment for redemption of preference shares (Note 16.3)
Common shares issued, net of costs (Note 16.1)
Proceeds from NCI for issuance of shares in subsidiaries that does not involve loss
of control
Other
Cash provided by (used in) financing activities
Effect of exchange rate differences on cash and cash equivalents
Net change in cash and cash equivalents during the period
Cash and cash equivalents, beginning of period
Cash and cash equivalents, end of period
See accompanying notes.
68
| NORTHLAND POWER INC.
| 2023 ANNUAL REPORT |
Year ended December 31,
2022
2023
$
(96,132) $
955,457
595,600
57,015
163,169
321,812
303,898
(32,407)
(204,902)
(104,425)
279,849
(31,950)
1,251,527 $
(466,313)
785,214 $
(441,111)
(1,014,615)
—
(1,050)
510,115
36,738
(389,509)
129,379
(1,170,053) $
2,214,977
(1,875,332)
(325,841)
(47,619)
(205,072)
(119,943)
(6,103)
—
40,908
62,187
(206)
(262,044) $
(10,472)
(657,355) $
1,299,833
642,478 $
571,090
53,611
—
323,109
(460,704)
5,588
(41,651)
101,286
2,857
32,465
1,543,108
289,875
1,832,983
(452,576)
(203,479)
(37,771)
(32,780)
41,566
47,405
—
7,952
(629,683)
2,799,273
(3,496,308)
(336,356)
2,855
(196,845)
(93,802)
(11,206)
(121,524)
851,610
—
(2,534)
(604,837)
27,678
626,141
673,692
1,299,833
$
$
$
$
$
$
Notes to the Consolidated Financial Statements
1. Description of Northland's business
Northland Power Inc. (the “Company” or “NPI”) owns or holds net economic interests, through its subsidiaries and joint
ventures (together referred in here as “Northland” or the “Group”), in power producing facilities and a power distribution
utility, as well as in the projects under construction or development phases. Northland’s facilities produce electricity from
clean energy sources for sale, primarily under long-term Power Purchase Agreements (“PPAs”) or other revenue
arrangements with creditworthy counterparties. Northland’s utility is a distributor and retailer of electricity, compensated
under a regulated framework. These operating assets provide stable cash flow and are primarily located in Canada,
Germany, the Netherlands, Spain, the United States of America, Mexico and Colombia. Northland’s significant assets under
construction and development are located in Canada, Taiwan, South Korea, Poland, Scotland and the United States of
America.
Northland is incorporated under the laws of Ontario, Canada, with common shares (“Shares”), Series 1 cumulative rate
reset preferred shares (“Series 1 Preferred Shares”) and Series 2 cumulative floating rate preferred shares (“Series 2
Preferred Shares”) that are publicly traded on the Toronto Stock Exchange (“TSX”). Northland’s registered office is located
in Toronto, Ontario.
These audited consolidated financial statements (“Consolidated Financial Statements”) include the results of the Group, of
which the most significant subsidiaries, as of December 31, 2023 are listed in the following table:
Offshore Wind
Buitengaats C.V. and ZeeEnergie C.V. (“Gemini”)
Nordsee One GmbH (“Nordsee One”)
Northland Deutsche Bucht GmbH (“Deutsche Bucht”)
Onshore Renewable
Northland Power Spain Holdings, S.L.U. ("Spanish portfolio")
Efficient Natural Gas
North Battleford Power L.P. (“North Battleford”)
Thorold CoGen L.P. (“Thorold”)
Utility
Empresa de Energía de Boyacá S.A E.S.P (“EBSA”)
Geographic region
% voting ownership(1)
The Netherlands
Germany
Germany
Spain
Canada
Canada
Colombia
60.0%
85.0%
100.0%
98.5%
100.0%
100.0%
99.4%
(1) As at December 31, 2023, Northland’s economic interest remained unchanged from December 31, 2022. Northland owns 100% ownership interest in
all the facilities within the Spanish Portfolio, except for Elecdey Lezuza, S.A. (a wind facility), where Northland’s ownership interest is at 66.2%.
2. Summary of accounting policies
2.1 Basis of preparation and statement of compliance
These Consolidated Financial Statements have been prepared in accordance with International Financial Reporting
Standards (IFRS) as issued by the International Accounting Standards Board (IASB) and are presented in Canadian dollars.
All values are presented in thousands except when otherwise indicated. The comparative financial information has been
reclassified from the previously presented to conform to the 2023 Consolidated Financial Statements presentation.
The Consolidated Financial Statements for the year ended December 31, 2023, were approved by the Board of Directors on
February 21, 2024.
2.2 Basis of consolidation
The Consolidated Financial Statements include Northland’s direct and indirect subsidiaries, which are fully consolidated on
the date when Northland obtains control and continue to be consolidated until the date such control ceases. Northland
determines that it has control over an investee if facts and circumstances indicate that Northland is exposed to, or has
rights to variable returns from its involvement with the investee and has the ability to affect those returns through its
power. All intra-group balances and transactions are eliminated on consolidation.
| NORTHLAND POWER INC. | | 2023 ANNUAL REPORT |
69
2.3 Business combinations and goodwill
Business combinations are accounted for using the acquisition method. The acquired identifiable assets, liabilities and
contingent consideration that meet the conditions for recognition under IFRS 3, “Business Combinations” are recognized at
their fair values at the acquisition date, except for (i) income taxes, which are measured in accordance with IAS 12, “Income
Taxes”; (ii) share-based payments, which are measured in accordance with IFRS 2, “Share-based Payment”; and (iii) non-
current assets that are classified as held for sale, which are measured at fair value less costs to sell in accordance with IFRS
5, “Non-Current Assets Held for Sale and Discontinued Operations”. Any goodwill arising from business combinations is,
from the date of acquisition, allocated to each of Northland’s cash-generating units (CGUs) or a group of CGU that are
expected to benefit from the synergies of the combination, irrespective of whether other assets or liabilities of the acquiree
are assigned to those units and tested annually for impairment (Note 2.8). Goodwill is initially measured at cost, being the
excess of the purchase price over Northland’s share in the net fair value of the acquiree’s identifiable assets, liabilities and
contingent liabilities.
2.4 Investment in joint ventures and associates
A joint venture is a type of joint arrangement whereby, the parties that have joint control of the arrangement have rights to
the net assets of the joint venture. Joint control is the contractually agreed sharing of control of an arrangement, which
exists only when decisions about the relevant activities require unanimous consent of the parties sharing control. Judgment
is required when assessing the classification of a joint arrangement as a joint venture. When making this assessment,
Northland considers the structure of the arrangements, the legal form of any separate vehicles, the contractual terms of the
arrangements, and other facts and circumstances.
An associate is an entity over which Northland has significant influence, which is the ability to participate in the financial
and operating policy decisions, but without controlling or jointly controlling the investee.
Northland’s investments in a joint venture or an associate are accounted for under the equity method of accounting,
whereby, the carrying value of interest in a joint venture or an associate is initially recognized at cost, which includes
transaction costs and subsequently adjusted for Northland’s share of net income, other comprehensive income (OCI),
distributions by a joint venture or an associate and other adjustments to Northland’s proportionate interest in a joint
venture or an associate.
The Consolidated Financial Statements include Northland’s share of the income (loss) and OCI of the joint venture, after
adjustments to align the accounting policies of the joint venture with those of Northland, from the date that joint control
commences, until the date that joint control ceases.
In addition, when there has been a change recognized directly in the equity (other than due to OCI) of the joint venture,
Northland recognizes its share of any changes, when applicable, in the consolidated statements of changes in equity and
corresponding effect would be reflected in the net carrying value of interest in the joint venture.
When Northland’s share of losses exceeds its interest in the joint venture, the carrying amount of that interest (including
any long term investments) is reduced to nil and the recognition of further losses is discontinued except to the extent that
Northland has a constructive or legal obligation to contribute to such losses or has made payments on behalf of the Joint
venture. Currently, Northland does not have an investment in associate.
2.5 Property, plant and equipment
Property, plant and equipment (PP&E) are recorded at cost, net of accumulated depreciation and any accumulated
impairment losses. The cost of PP&E includes the cost of replacing part of the PP&E and borrowing costs for long-term
construction projects, if the recognition criteria are met. Likewise, when a major overhaul as described below is performed,
its cost is recognized in the carrying amount of the related PP&E as a replacement if the recognition criteria are met. All
other repair and maintenance costs are recognized in the consolidated statements of income (loss) as incurred. The present
value of the expected cost for decommissioning is included in the cost of the related asset if the recognition criteria for a
provision are met. Refer Note 2.9 for further information about the measurement of the decommissioning liabilities.
70
| NORTHLAND POWER INC. | | 2023 ANNUAL REPORT |
Depreciation expense is recognized on a straight-line basis over its estimated useful lives of the asset primarily as follows:
Description of Asset class
Plant and operating equipment
Buildings and foundations
Lease ROU asset
Leasehold improvements
Other equipment - vehicles and meteorological towers
Other equipment - office equipment, furniture and fixtures
Other equipment - computers and computer software
Useful Lives
10 to 35 years
20 to 40 years
1 to 50 years
Over the term of the lease
5 years
5 years
2 years
In general, Northland expects to use its PP&E to their full useful lives and considers residual values, where appropriate, in
calculating depreciation.
Assets included in construction-in-progress (CIP) are transferred to the appropriate PP&E category and amortized once the
assets are available for use, such as when the test period ends and / or the PP&E begins commercial operations.
The costs of all maintenance provided under long-term, fixed-price contracts are charged to the Consolidated statements of
income (loss) based on the terms of the contract. All major overhaul expenditures that are not incurred under long-term
maintenance contracts are capitalized and amortized over the average expected period between major overhauls.
An item of PP&E is derecognized upon disposal or when no future economic benefits are expected from its use or disposal.
Any gain or loss arising on derecognition of an asset is included in the consolidated statements of income (loss) in the
period of derecognition.
Government grants and other tax credits related to the construction of capital assets are recorded as a reduction to the cost
of the related asset and amortized over the useful life of the related asset.
2.6 Intangible assets
The cost of intangible assets acquired is initially recorded at their fair value at the date of acquisition. Intangible assets
acquired separately are measured on initial recognition at cost. Internally generated intangible assets, other than deferred
development costs, are not capitalized, and the expenditure is reflected the consolidated statements of income (loss).
Intangible assets with finite lives are amortized over their useful economic lives and assessed for impairment whenever
there is an indication that the intangible asset may be impaired.
Development costs
Development expenditures on an individual project are recorded as assets on the Consolidated statements of financial
position when Northland can demonstrate:
•
•
•
•
•
The technical feasibility of completing the project so that it will be available for use or sale;
The intention to complete, and ability to use or sell, the project;
The project will generate future economic benefits;
The availability of resources to complete the project; and
The ability to measure reliably the expenditures during development.
During the period of development, the asset is tested annually for impairment or if any indicators of impairment are
identified.
Deferred development costs include pre-construction costs directly related to new projects and are presented under PP&E
as CIP. Capitalization begins once it is determined by management that a given project has a high likelihood of being
pursued through to completion. Costs are capitalized up to the closing of project financing and/or the start of construction,
at which time they are reclassified to the appropriate PP&E category from CIP or recorded as intangible assets, as
appropriate. All indirect research and development costs not eligible for asset recognition are expensed as “development
costs” on the Consolidated statements of income (loss).
Contracts
Contracts relate primarily to the fair value of PPAs and management agreements when they were acquired by Northland
and are recorded net of accumulated amortization. Contract amortization is recorded on a straight-line basis over the term
of the agreement.
| NORTHLAND POWER INC. | | 2023 ANNUAL REPORT |
71
2.7 Leases or arrangements containing a lease
Lessee accounting
At the inception of a contract, Northland assesses whether the arrangement is or contains a lease in accordance with IFRS
16, “Leases”. If the arrangement meets the definition of a lease, a lease obligation and a related right-to-use (“ROU”) asset
will be recorded on the applicable lease commencement date. A lease liability is initially measured at the present value of
the unpaid lease payments and discounted using the interest rate implicit in the lease (if readily determinable) or otherwise
using Northland’s incremental borrowing rate. A ROU asset is initially measured based on the initial amount of the related
lease obligation, subject to certain adjustments. The lease obligation is remeasured when there are adjustments to future
lease payments arising from a change in applicable indices or rates or changes in lease terms. Upon any such
remeasurement, a corresponding adjustment is made to the carrying amount of the related ROU asset.
Northland applies the cost model to subsequently measure lease ROU assets and applies the same impairment policy as
other PP&E. ROU assets are depreciated over a period, which is shorter of the lease term and useful life of the underlying
asset. The lease term includes any renewal or termination options, which Northland is reasonably certain to exercise. In the
case of land leased for future development, Northland assumes an initial lease term of 5 years. Where leased assets are
required for the operation of the facility, Northland assumes that the lease will be renewed to match the term of the
facility’s PPA. Northland reassesses the lease term in response to significant events or changes in circumstances. If a lease
transfers ownership of the underlying asset or Northland expects to exercise a purchase option, the related ROU asset is
depreciated over the useful life of the underlying asset.
Lessor accounting
Northland enters into PPAs to provide electricity and electricity-related products at predetermined prices. At inception of
the contract, Northland assesses whether the PPA is, or contains, a lease in accordance with IFRS 16. If the PPA meets the
definition of a lease and the terms of the contract do not transfer substantially all of the benefits and risks of ownership of
PP&E, it is classified as an operating lease. Where the terms do transfer substantially all of the benefits and risks of
ownership, it is classified as a finance lease.
Finance lease receivables are initially measured at amounts equal to the present value of the net investment in the lease.
Finance lease income is recognized in a manner that produces a constant rate of return on Northland’s net investment in
the lease and is included in operating income.
At the commencement of the lease, which generally coincides with start of commercial operations of the facility, Northland
separates payments and other consideration required by such an arrangement into those for the lease and those for other
elements on the basis of their relative fair values.
2.8 Impairment of non-financial assets
Northland assesses at each reporting date whether there is an indication that an asset may be impaired or that previously
recognized impairment losses may no longer exist or have decreased. If any indication exists or when annual impairment
testing for an asset is required, Northland estimates the asset’s or CGU’s recoverable amount. The estimated recoverable
amount is the higher of (i) an asset’s or CGU’s estimated fair value less costs to sell or (ii) its value in use. Where the
carrying amount of an asset or CGU exceeds its estimated recoverable amount, the asset is considered impaired and is
written down to its estimated recoverable amount. When the recoverable amount exceeds the carrying amount for an
asset or CGU previously impaired, the reversal is limited to ensure the carrying amount of the asset does not exceed the
carrying amount that would have been determined, net of depreciation, had no impairment been previously recognized.
In assessing value in use, the estimated future cash flows are discounted to their present value using a pre-tax discount rate
that reflects current market assessment of the time value of money and risk specific to the asset. In determining fair value
less costs to sell, an appropriate valuation model is used and calculations are corroborated by valuation multiples or other
available fair value indicators.
Goodwill
Goodwill is tested for impairment annually and when circumstances indicate that the carrying value may be impaired.
Impairment is determined for goodwill by assessing the recoverable amount for each CGU or a group of CGUs to which the
goodwill relates. Where the estimated recoverable amount of the CGU or a group of CGU is less than its carrying amount,
an impairment loss is recognized. Impairment losses relating to goodwill are not reversed in future periods.
72
| NORTHLAND POWER INC. | | 2023 ANNUAL REPORT |
2.9 Provisions
General
Provisions are recognized when Northland has a present obligation (legal or constructive) as a result of a past event and
where it is probable that an outflow of resources embodying economic benefits will be required to settle the obligation.
Where Northland expects some or all of a provision to be reimbursed (for example, under an insurance policy or warranty
agreement), the reimbursement is recognized as a separate asset but only when the reimbursement is virtually certain. The
expense relating to any provision is presented in the Consolidated statements of income (loss) net of any reimbursement.
Decommissioning liabilities
Provisions for decommissioning costs are recorded at the present value of expected costs to settle the obligation using
estimated cash flows and are recognized as part of the cost of the related asset. The expected cash inflows associated with
the residual or scrap values of the the assets are not considered in arriving at decommissioning cost. The cash flows are
discounted at a current pre-tax rate. Where the estimated cash flows reflect the risks specific to the decommissioning
liability, a risk-free discount rate is used; otherwise, a discount rate reflective of the risks specific to the decommissioning
liability is used. The unwinding of the discount is expensed as incurred and recognized in the Consolidated statements of
income (loss) as a finance cost. The estimated future costs of decommissioning are reviewed annually and adjusted as
appropriate. Changes in the estimated future costs or in the discount rate applied are added to or deducted from the cost
of the asset.
2.10 Share-based compensation
As part of Northland’s share-based compensation plans, Northland provides incentives to management and certain
employees when projects achieve predetermined milestones (“Development LTIP”) or to recognize achievements, attract
and retain executives (“Deferred Rights”). For Development LTIP awards, the cost of the shares awarded is recognized over
the estimated vesting period and is capitalized for the employees providing services which are directly attributable to the
development and construction of the project. The awards vest when the associated project meets established performance
expectations. Grants of Deferred Rights vest over a maximum of a three-year period, and the expected cost is expensed
over the vesting period. In addition to the Development LTIP and Deferred Rights, share-based compensation in the form of
Performance Share Unit (PSU), Restricted Share Units (RSU) and Deferred Share Units (DSU), are also granted by Northland
to the Board of Directors, certain executives and non-executives employees.
These awards, except for DSU are settled in cash or shares, at Northland’s discretion, whereas, DSUs are settled in cash.
Accordingly, these are accounted for as a liability until settled. The fair value of the awards is based on the grant date share
price and, to the extent that services are provided in advance of the grant date, Northland’s reporting date share price. The
estimated forfeiture rate reflects the shares that will vest upon achieving project milestone and is revised if there is any
indication that the number of shares expected to vest has changed.
2.11 Cash and cash equivalents and restricted cash
Cash equivalents comprise only highly liquid investments with maturities of less than 90 days.
Restricted cash comprises amounts which are not readily available, on demand, to fund Northland’s operations, including
the amounts set aside for specific uses such as amounts funded against future maintenance, debt service and construction
costs at certain Northland subsidiaries.
As of December 31, 2023, cash and cash equivalents are comprised of cash balances and a short term deposit held with the
banks of $642 million (2022 - $1,300 million) and $58 million (2022 - $147 million), respectively.
2.12 Financial instruments
(a) Financial assets and liabilities
Northland recognizes financial assets and financial liabilities initially at fair value and subsequently remeasure these at
either fair value or amortized cost based on their classification as described below. Financial assets are derecognized when
the rights to receive cash flows from the financial assets have expired or have been transferred and Northland has
transferred substantially all the risks and rewards of ownership.
| NORTHLAND POWER INC. | | 2023 ANNUAL REPORT |
73
Fair value through profit and loss:
Financial assets with the intention of generating earnings in the near term, and derivatives other than cash flow hedges, are
classified as fair value through profit and loss (FVPL). A gain or loss on a financial asset measured at FVPL that is not part of
a hedging relationship is recognized in Consolidated statements of income (loss) and presented on a net basis in the period
in which it arises. For derivative financial assets, gains and losses are shown within “fair value (gain) loss on financial
instruments”. Northland classifies loans provided to First Nations partners at FVPL due to the fact that they do not meet the
criteria for classification as amortized cost because the contractual cash flows are not solely payments of principal and
interest. This is the only non-derivative financial asset measured at FVPL and related gains and losses are shown within
“other (income) expense” in the Consolidated statements of income (loss). Interest income from FVPL financial assets is
recognized as “Finance Income”.
Financial liabilities held for trading, such as those acquired for the purpose of selling in the near term, and derivative
financial instruments entered into by Northland that do not meet hedge accounting criteria are classified as fair value
through profit and loss. Gains or losses on these type of instruments are recognized in the Consolidated statements of
income (loss).
For financial instruments classified as fair value through OCI (FVOCI), refer Note 2.12 (d) below.
Amortized cost:
Financial assets held for collection of contractual cash flows that represent solely payments of principal and interest are
measured at amortized cost, and include Northland’s trade receivables, term deposits and other receivables. Interest
income from these financial assets is included in “Finance costs” using the effective interest rate method.
All other financial liabilities are classified as amortized cost using the effective interest rate method. Gains and losses are
recognized in Consolidated statements of income (loss) when the liabilities are derecognized as well as through the
amortization process. The calculation takes into account any premium or discount on acquisition and includes transaction
costs and fees that are an integral part of the effective interest rate. This category includes trade and other payables,
dividends payable, interest-bearing loans and borrowings, corporate credit facilities.
Tax equity financing:
Northland owns and operates certain renewable projects in the United States of America under tax-equity structures with
the project investors, commonly referred to as the “Tax-Equity Investors”, that have financed the construction of these
renewable projects. Such tax-equity structures are used to allocate renewable tax incentives, such as Investment Tax
Credits (ITCs), cash grants, and accelerated tax depreciation, as applicable, to the Tax-Equity Investors.
Generally, these Tax-Equity Investors, in return for purchasing equity stakes in these renewable projects, receive a
substantial portion of earnings, tax benefits and cash flows from the projects financed with a tax-equity structure, until the
projects have yielded an agreed-upon target rate of return to the Tax-Equity Investors (the "Flip Point"). The Flip Point is
generally dependent on the projects' respective performance. However, from time to time, the Flip Point dates may be
contractually determined. Immediately after the Flip Point, the structures flip such that the Northland will receive the
majority of earnings, tax benefits and cash flows from the projects financed with tax-equity structures.
When a tax-equity partnership is formed, Northland assesses whether the project company should be consolidated based
on Northland's right to variable returns and its ability to influence the financial and operational decisions impacting those
returns. Due to the operational and financial nature of the projects, and the protective nature of the rights given to the Tax-
Equity Investors, Northland may retain the control to consolidate the project entity.
In accordance with the terms of the tax equity structure, the contribution by the Tax-Equity Investors has the characteristics
of a liability as the contribution is repaid, including an agreed-upon return, and the Tax-Equity Investors do not share the
risks of the renewable project in the same way as Northland. Accordingly, the amounts contributed by the Tax-Equity
Investors for their equity stakes are classified as loans and borrowings in the Consolidated Financial Statements until the
respective Flip Point of the projects. Subsequent to the Flip Point, the Tax-Equity Investors’ equity investments will be
accounted for as non-controlling interests.
The loans and borrowings as disclosed in Note 13.3 of these Consolidated Financial Statements, associated with the tax-
equity structures are measured at amortized cost using the effective interest method.
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Tax Equity financing is settled over time through the following components:
Key Components
Description
ITCs
Taxable income (loss), including
tax attributes such as accelerated
tax depreciation
Allocation of ITCs to the tax-equity investor derived from the power generated by the
respective renewables facility during the period and recognized as an offset against the cost
of relate asset.
Allocation of taxable income (loss) and other tax attributes to the Tax-Equity Investor
recognized in other income as earned.
Interest Expense
Pay-go-contributions
Cash distributions
Interest expense using the effective interest rate method recognized in finance costs as
incurred and as an increase in tax-equity financing.
Upon exceeding the annual production thresholds, the Tax-Equity Investor is required to
contribute additional cash amounts. The cash amounts paid increase the value of the tax-
equity financing.
Cash distribution and projected ITCs allocated to tax-equity financing in lieu of cash discounted
at the internal rate of return to its present value.
(b) Offsetting of financial instruments
Financial assets and financial liabilities are offset and the net amount reported in the Consolidated statements of financial
position if and only if there is a currently enforceable legal right to offset the recognized amounts and an intention to settle
on a net basis or to realize the assets and settle the liabilities simultaneously.
The individual derivative financial instruments, that a subsidiary enters into, will not be realized or settled simultaneously,
and therefore derivative assets and derivative liabilities are not offset on the Consolidated statements of financial position.
(c) Fair value of financial instruments
Northland determines the fair value of its financial instruments at each Consolidated statements of financial position date
based on the following hierarchy:
•
•
Level 1 - Where financial instruments are traded in an active financial market, fair value is established by reference to
the appropriate quoted market price at the reporting date. Active markets are those in which transactions occur with
significant frequency and volume to provide pricing information on an ongoing basis.
Level 2 - If there is no active market, fair value is established using valuation techniques, including discounted cash
flow models. The inputs to these models are taken from observable market data where possible, including recent
arm’s-length market transactions, and comparisons to the current fair value of similar instruments; but where this is
not feasible, inputs such as liquidity risk, counterparty risk and volatility are used.
•
Level 3 - Valuations at this level are those with inputs that are not based on observable market data.
Assessment of the significance of a particular input to the fair value measurement requires judgment; any changes in
assumptions may affect the reported fair value of financial instruments.
The fair value of derivative financial instruments reflects the estimated amount that Northland would have been required
to pay upon the settlement all unfavourable outstanding contracts or the amount that would be received upon the
settlement of all favourable contracts at the Consolidated statements of financial position date. The fair value represents a
point-in-time estimate that may not be relevant in predicting Northland’s future earnings or cash flows.
(d) Derivatives and hedging activities
Derivatives are initially recognized at fair value on the date a derivative contract is entered into and are subsequently re-
measured to their fair value at the end of each reporting period. The accounting for subsequent changes in fair value
depends on whether the derivative is designated as a hedging instrument, and if so, the nature of the item being hedged
and the type of hedge relationship designated.
Northland designates its derivatives as hedges of:
•
•
•
•
Foreign exchange risk associated with the cash flows of highly probable forecast transactions (cash flow hedges);
Foreign exchange risk associated with net investment in foreign operations (net investment hedges);
Floating interest rate risk associated with payments of debts (cash flow hedges); and
Commodity risk associated with payments under PPAs (cash flow hedges).
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75
The fair values of various derivative financial instruments used for hedging purposes and movements in the hedge reserve
within equity are shown in Note 19.1.
When a hedging instrument expires, is sold, is terminated, or no longer meets the criteria for hedge accounting, any
cumulative deferred gain or loss and deferred costs of hedging in equity at that time remain in equity until the forecasted
transaction occurs. When the forecasted transaction is no longer expected to occur, the cumulative gain or loss and
deferred costs of hedging are immediately reclassified to Consolidated statements of income (loss).
If the hedge ratio for risk management purposes is no longer optimal but the risk management objective remains
unchanged and the hedge continues to qualify for hedge accounting, the hedge relationship will be rebalanced by adjusting
either the volume of the hedging instrument or the volume of the hedged item so that the hedge ratio aligns with the ratio
used for risk management purposes. Any hedge ineffectiveness is calculated and accounted for in Consolidated statements
of income (loss) at the time of the hedge relationship rebalancing.
Cash flow hedges that qualify for hedge accounting
The effective portion of changes in the fair value of derivatives that are designated and qualify as cash flow hedges is
recognized in OCI and accumulated in reserves in equity, limited to the cumulative change in fair value of the hedged item
on a present value basis from the inception of the hedge. The gain or loss relating to the ineffective portion is recognized
immediately in the Consolidated statements of income (loss), within “fair value (gain) loss on financial instruments”.
Gains and losses relating to the effective portion of the change in fair value of the entire forward contract are recognized in
the cash flow hedge reserve within equity. Amounts accumulated in equity are reclassified in the period when the hedged
item affects the Consolidated statements of income (loss).
Net investment hedges that qualify for hedge accounting
Hedges of net investments in foreign operations are accounted for similarly to cash flow hedges. Any gain or loss on the
hedging instrument relating to the effective portion of the hedge is recognized in OCI and accumulated in reserves in equity.
The gain or loss relating to the ineffective portion is recognized immediately in the Consolidated statements of income
(loss) within “fair value (gain) loss on financial instruments”. Gains and losses accumulated in equity will be reclassified to
the Consolidated statements of income (loss) when the foreign operation is partially disposed of or sold.
Hedge ineffectiveness
Northland’s hedging policy only allows for the use of derivative instruments that form effective hedge relationships. Hedge
effectiveness is determined at the inception of the hedge relationship and through periodic prospective effectiveness
assessments to ensure that an economic relationship exists between the hedged item and hedging instrument. Northland
enters into hedge relationships where the critical terms of the hedging instrument match exactly with the terms of the
hedged item, and so a qualitative assessment of effectiveness is performed. If changes in circumstances affect the terms of
the hedged item such that the critical terms no longer match exactly with the critical terms of the hedging instrument,
Northland uses the hypothetical derivative method to assess effectiveness.
(e) Impairment of Financial assets:
Northland accounts for impairment of financial assets based on a forward-looking expected credit loss (ECL) approach. ECL
are measured as the difference in the present value of the contractual cash flows due to Northland under the contract and
the cash flows that Northland expects to receive. Northland assesses all information available, including past due status,
credit ratings, the existence of third-party insurance and forward-looking macro-economic factors in the measurement of
the ECL associated with its assets carried at amortized cost and FVOCI. Northland measures ECL by considering the risk of
default over the contract period and incorporates forward-looking information into its measurement.
Impairment of cash and cash equivalents and restricted cash is evaluated by reference to the credit quality of the
underlying financial institution or investee.
Trade receivables are reviewed periodically on a case-by-case basis to determine if impairment exists.
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2.13 Revenue recognition
(a) Electricity generation and related products
Electricity related revenue is recognized over time as electricity and related products are delivered. Each of Northland’s
PPAs contain a distinct performance obligation for the delivery of electricity, delivery of capacity (i.e. availability of
generation), or a combination of the two. Determining what goods or services promised to the customer constitute a
distinct performance obligation requires significant management judgment. Northland considered all goods and services
promised in its PPA contracts and determined that while certain promises do have standalone value to the customer, they
are not distinct in the context of the contract. Refer to Note 24 for details on revenue streams disaggregated by technology
and geography.
Northland views each megawatt hour (MWh) of electricity and/or capacity delivered to be a series of distinct goods that are
substantially the same and have the same pattern of transfer to the customer as measured using an output method. The
amount that Northland has a right to bill the customer reflects the pattern of transfer and value of the completed
performance to the customer. As a result, Northland applies the “right to invoice” practical expedient under IFRS 15,
“Revenue from Contracts with Customers”, to measure and recognize revenue.
Renewable energy credits revenue is recognized at the time when the electricity is generated by the facility and delivered to
the grid, when all performance obligations have been delivered. Revenues are based on actual output and contractual sale
prices set forth in long-term contracts.
(b) Regulated revenue from electricity generation and utility
From electricity generation:
The revenue for each facility has four components:
•
•
•
•
The return on investment (“Ri”), sized to complete the target return based on the market revenue assumed ex-ante
(the “posted price”);
The return on operations (“Ro”), sized to compensate a facility when its operating costs are higher than its market
revenues. To note, Ro is not being received in the current environment;
The market revenue, at pool prices; and
The “band adjustments”, which are an ex-post positive or negative settlement to compensate for the difference
between the market revenue, at pool prices and the revenue at the regulatory posted price. If the pool price is
lower than the regulatory posted price, the band adjustment mechanism adds the additional revenue to achieve a
reasonable return. Conversely, if the pool price is higher than the posted pool price, the band adjustment
mechanism reduces revenues in the period.
Any pool price revenue collected significantly in excess of the assumed pool price in the current regulatory semi-period is
recognized as deferred revenue. The long-term portion of deferred revenue is presented under provisions and other
liabilities, whereas, the short-term portion of deferred revenue is presented under “Trade and other payables” or
“Provisions and other liabilities”, as the case may be, in the Consolidated statements of financial position. The deferred
revenue is recognized as revenue over the remaining regulatory periods and presented under regulated electricity in the
consolidated statement of income (loss). Any pool price revenue collected less than the assumed pool price in the current
regulatory semi-period is recognized as a receivable and presented under “Trade and other receivables” or “Other non-
current assets”, as the case may be, in the Consolidated statements of financial position. Collectively known as “Band
adjustments” mechanism.
From utility distribution:
Regulated utility revenues from generation, transmission, distribution and commercialization (i.e. retail) tariffs are
recognized as electricity is delivered to customers. Revenues include amounts billed or billable to customers for generation
and transmission tariffs, which are passed through to third parties. Northland records these revenues on a gross basis since
Northland is responsible for procuring electricity and has collection risk for these amounts.
Payments to customers are recorded as an expense when the payments relate to a separate good or service provided by
the customer and recorded as a reduction in revenue when the payments relate to Northland’s performance obligations
under the contract (e.g. liquidated damages penalties).
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77
(c) Other sources of revenue
Northland recognizes management fees and operations-related incentive fees as earned based on the terms of its
respective facility agreements as the work is performed.
(d) Interest income
Interest income is recognized as earned in accordance with the terms of the underlying financial contracts.
2.14 Borrowing costs
Borrowing costs directly attributable to the acquisition or construction of a qualifying asset that takes a substantial period
of time to prepare for its intended use or sale are capitalized as part of the cost of the asset. All other borrowing costs are
expensed as incurred. Borrowing costs consist of interest and other costs incurred in connection with the borrowing of
funds.
2.15 Taxes
(a) Current income tax
Income tax assets and liabilities are measured at the amount expected to be recovered from or paid to tax authorities,
based on the tax rates and tax laws that are enacted or substantively enacted at the Consolidated statements of financial
position date. Current income tax relating to items recognized directly in equity is recognized in equity and not in the
Consolidated statements of income (loss).
(b) Deferred income tax
Deferred income tax is determined using the asset and liability method at the Consolidated statements of financial position
date on temporary differences between the tax bases of assets and liabilities and their carrying amounts for financial
reporting purposes.
Deferred income tax liabilities are recognized for all taxable temporary differences except:
• Where the deferred income tax liability arises from the initial recognition of goodwill or of an asset or liability in a
transaction that is not a business combination and at the time of the transaction affects neither the accounting income
nor taxable income or loss and does not give rise to equal taxable and deductible temporary differences; and
• Where the deferred income tax liability relates to taxable temporary differences associated with investments in
subsidiaries, associates and interests in joint ventures, where the timing of the reversal of the temporary differences
can be controlled and it is probable that the temporary differences will not reverse in the foreseeable future.
Deferred income tax assets are recognized for all deductible temporary differences, carryforward of unused tax credits and
unused tax losses to the extent that it is probable that taxable income will be available against which the deductible
temporary differences, carry forward of unused tax credits and unused tax losses can be utilized except:
• Where the deferred income tax asset relating to the deductible temporary difference arises from the initial recognition
of goodwill or of an asset or liability in a transaction that is not a business combination and at the time of the
transaction affects neither the accounting income nor taxable income or loss and does not give rise to equal taxable
and deductible temporary differences; and
• Where the deferred income tax asset relates to deductible temporary differences associated with investments in
subsidiaries, associates and interests in joint ventures, deferred income tax assets are recognized only to the extent
that it is probable that the temporary differences will reverse in the foreseeable future and taxable income will be
available against which the temporary differences can be utilized.
Deferred income tax assets and liabilities are measured at the tax rates that are expected to apply in the year when the
asset is realized or the liability is settled, based on tax rates (and tax laws) that have been enacted or substantively enacted
at the Consolidated statements of financial position date.
Deferred income tax relating to items recognized directly in equity is recognized in equity, not the Consolidated statements
of income (loss).
Deferred income tax assets and deferred income tax liabilities are offset if a legally enforceable right exists to offset and the
deferred income taxes relate to the same taxable entity and the same taxation authority.
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(c) Sales taxes
Sales, expenses and assets are recognized net of the amount of sales tax except:
• Where the sales tax incurred on a purchase of assets or services is not recoverable from the taxation authority, in
which case the sales tax is recognized as part of the cost of acquisition of the asset or as part of the expense item, as
applicable; and
• Where receivables and payables are stated with the amount of sales tax included.
The net amount of sales tax recoverable from or payable to the taxation authority is included in the Consolidated
statements of financial position.
2.16 Foreign currency translation
Northland’s Consolidated Financial Statements are presented in Canadian dollars, which is Northland’s functional currency.
For each subsidiary or a joint venture, located outside of Canada (referred herein as “foreign operations”) Northland
determines the functional currency and measures items included in the financial statements of such foreign operations in
that functional currency. The functional currency of Northland’s significant foreign operations reflects the primary
economic environment in which each they operate and includes the United States Dollar, Pound Sterling, Euro, Mexican
Peso, New Taiwan Dollar, Polish Zloty, Korean Won, and Colombian Peso.
The assets and liabilities of foreign operations are translated into Canadian dollars at the closing rates for Consolidated
statements of financial position date and their income and expenses are translated at the average exchange rate for each
quarterly period. The exchange differences arising on the translation are recognized in accumulated other comprehensive
income (loss) in Consolidated statements of changes in equity. On disposal of a foreign operation, the cumulative amount
recognized in equity relating to the foreign operation is recognized in the Consolidated statements of income (loss).
2.17 Contingencies and commitments
Liabilities for loss contingencies arising from environmental remediation, claims, assessments, litigation, fines, penalties and
other sources are recorded when it is probable that a liability has been incurred and the amount can be reasonably
estimated. Legal costs incurred in connection with loss contingencies are expensed as incurred.
2.18 New standards or amendments and forthcoming requirements
Northland assesses each new IFRS or amendment to determine whether it may have a material impact on its Consolidated
Financial Statements. The following standards and amendments to the standards apply for the first time to financial
reporting periods commencing on or after January 1, 2023:
•
•
•
•
Amendments to IAS 1, Presentation of Financial Statements – These narrow-scope amendments to IAS 1 require
entities to disclose their material accounting policy information, instead of significant accounting policies.
Amendments to IAS 8, Accounting Policies, Changes in Accounting Estimates and Errors – Introducing a definition of
‘accounting estimates’. The amendments clarify the distinction between changes in accounting estimates and changes
in accounting policies, and the correction of errors. Also, they clarify how entities use measurement techniques and
inputs to develop accounting estimates.
Amendment to IAS 12, Income Taxes, Deferred tax related to assets and liabilities arising from a single transaction –
These amendments require companies to recognize deferred tax on transactions that, on initial recognition, give rise to
equal amounts of taxable and temporary deductible differences.
Amendment to IAS 12, Income Taxes relating to international tax reform – The amendments give entities a temporary
exemption from accounting for the deferred tax impacts resulting from the jurisdictional implementation of Pillar Two
model rules published by the Organization for Economic Co-operation and Development.
Northland adopted the above amendments as of January 1, 2023, and there has been no significant impact on the
Consolidated Financial Statements as of and for the year ended December 31, 2023.
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IASB has issued following new amendments to the standards before December 31, 2023, with an effective date for
accounting periods ending on or after January 1, 2024:
•
•
•
•
Amendments to IAS 1, Presentation of Financial Statements (effective on or after January 1, 2024) – These narrow-
scope amendments to IAS 1 clarify that liabilities are classified as either current or non-current, depending on the rights
that exist at the end of the reporting period. Classification is unaffected by the expectations of the entity or events
after the reporting date. The amendment also clarifies what IAS 1 means when it refers to the ‘settlement’ of a liability.
Amendments to IAS 7 and IFRS 7, Supplier Finance (effective on or after January 1, 2024) – These amendments require
disclosures to enhance the transparency of supplier finance arrangements and their effects on an entity’s liabilities,
cash flows and exposure to liquidity risk.
Amendment to IFRS 16, Leases on sale and leaseback (effective on or after January 1, 2024) – These amendments
include requirements for sale and leaseback transactions in IFRS 16 to explain how an entity accounts for a sale and
leaseback after the date of the transaction. Sale and leaseback transactions where some or all the lease payments are
variable lease payments that do not depend on an index or rate are most likely to be impacted.
Amendment to IAS 21, Lack of Exchangeability (effective on or after January 1, 2025) – The amendment specifies how
an entity should assess whether a currency is exchangeable and how it should determine a spot exchange rate when
exchangeability is lacking. An entity is impacted by the amendments when it has a transaction or an operation in a
foreign currency that is not exchangeable into another currency at a measurement date for a specified purpose.
The amendments are not expected to have a material impact on the Consolidated Financial Statements of Northland.
3. Significant accounting judgments, estimates and assumptions
When preparing the Consolidated Financial Statements, management undertakes a number of judgments, estimates and
assumptions about recognition and measurement of assets, liabilities, income and expenses and in applying accounting
policies. The actual results are likely to differ from the judgments, estimates and assumptions and will seldom precisely
equal the estimated results.
The judgments, estimates and assumptions that have the most significant effect on the recognition and measurement of
assets, liabilities, income and expenses are discussed below.
3.1 Judgements
In the process of applying Northland’s accounting policies, management has made the following judgements, which have
the most significant effect on the amounts recognized in the Consolidated Financial Statements:
a) Deferred development costs
Management monitors the progress of the projects in early, mid and advanced stage development phases though a
framework developed by its global Project Management Office. Costs are recognized as an asset in accordance with IFRS
once management determines a project is economically feasible and risks to project completion have been sufficiently
mitigated, which typically occurs during mid-to-advanced staged development. In contrast, early stage prospecting and
development costs are expensed as incurred.
Determining which projects will continue to be pursued and when to begin deferring costs for advanced development
phase projects requires judgment. Management regularly reviews the feasibility of each project that is being developed,
and should management determine that the development of a particular project is no longer feasible to be pursued to
completion, the deferred costs are expensed in the period the determination is made.
b) Accounting for investments in non-wholly owned subsidiaries
Management exercises judgment in determining whether non-wholly owned subsidiaries are controlled by Northland.
Management’s judgment included the determination of (i) how the relevant activities of the subsidiary are directed (either
through voting rights or contracts); (ii) whether Northland’s rights are substantive or protective in nature; and (iii)
Northland’s ability to influence the returns of the subsidiary. In addition, where subsidiaries are subject to joint control,
Management applies judgment in determining whether Northland’s rights are to the net assets or individual assets and
liabilities of the joint arrangement, which results in accounting for the subsidiary as a joint venture or joint operation,
respectively. Refer to Note 17 for details on significant non-wholly owned subsidiaries and Note 8 for investment in joint
ventures.
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3.2 Accounting estimates and assumptions
The key assumptions concerning the future and other key sources of estimation uncertainty at the reporting date that have
a significant risk of causing a material adjustment to the carrying amounts of assets and liabilities within the next financial
year are described below. Management based its assumptions and estimates on parameters available when the
Consolidated Financial Statements were prepared. However, existing circumstances and assumptions about future
developments may change due to market changes or circumstances arising beyond management's control. Accordingly,
such changes are reflected in the assumptions when they occur.
a) PP&E and intangible assets
PP&E and intangible assets are depreciated over their useful lives, taking into account estimated residual values, where
appropriate. Residual values and useful lives are reviewed annually and adjusted prospectively, if appropriate. In assessing
residual values, Northland considers the remaining life of the asset, its projected disposal value and future market
conditions. Useful lives take into account factors such as technological innovation, maintenance programs, relevant market
information and management considerations. Management judgment is also required when Northland acquires entities and
must allocate the purchase price to the fair value of the assets and liabilities acquired, which includes PP&E and intangible
assets, such as but not limited to goodwill. The carrying amounts of PP&E and intangible assets are analyzed in Notes 4 and
Note 5, respectively.
b) Decommissioning liabilities
Northland’s decommissioning liabilities relate to wind, solar and closed efficient natural gas facilities. Future remediation
costs, whether required under contract or by law, are recognized based on best estimates. These estimates are calculated
at completion of construction and reviewed annually or more often if there is reason to believe the estimate has changed.
Cost estimates depend on labour costs, efficiency of site restoration and remediation measures, inflation rates and, where
possible, risks specific to the liability. Estimates of pre-tax interest rates that reflect current market conditions, the time
value of money and, where applicable, the risks specific to the liability also affect the liability. Northland estimates the
timing of expenses, which may change depending on the viability of continuing operations. Expected future costs are
inherently uncertain and could materially change over time. Subject to plant closures, Northland expects to use assets at
the efficient natural gas facilities and regulated utility operations for an indefinite period due to continuing equipment
overhauls and rights to the underlying land. As a result, management considers that a reasonable estimate of the value of
any related decommissioning liability cannot be made until it is known that the facility will be closed. Refer to Note 15.1 for
additional details.
c) Fair value of financial assets and financial liabilities
Where the fair values of financial assets and financial liabilities cannot be derived from active markets, they are determined
using valuation techniques, including discounted cash flow models. The inputs to these models are taken from observable
markets where possible, but where this is not feasible, a degree of judgment is required in establishing fair values. The
judgments include consideration of inputs such as liquidity risk, credit risk and volatility. Changes in assumptions about
these factors could affect the reported fair value of financial instruments. Refer to Note 19.1 for additional details on fair
values of financial instruments.
d) Impairment of non-financial assets
Northland tests impairment of goodwill, other intangible assets and PP&E based on value-in-use calculations using a
discounted cash flow model. The cash flows are derived from forecasts over the remaining useful lives of the assets of the
CGUs, less an allocation of forecasted corporate costs. The estimated recoverable amount is sensitive to the discount rate
used for the discounted cash flow model as well as the expected future cash inflows. The key assumptions used to estimate
the recoverable amount for the different CGUs are further explained in Note 22.
For certain assets, Northland also uses fair value less cost to sell (FVLCS) method in which most recent market transactions
are taken into account. If no such transactions can be identified, an appropriate valuation model is used. These calculations
are corroborated by valuation multiples for similar transactions or other available fair value indicators. FVLCS approach is
most sensitive to EBITDA multiples and price per megawatts.
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81
e) Income taxes
Preparation of the Consolidated Financial Statements requires an estimate of income taxes in each of the jurisdictions in
which Northland operates. The process involves an estimate of Northland’s current tax exposure and an assessment of
temporary differences resulting from differing treatment of items such as depreciation and amortization for tax and
accounting purposes. These differences result in deferred tax assets and liabilities that are included in Northland’s
Consolidated statements of financial position. An assessment is also made to determine the likelihood that Northland’s
deferred income tax assets will be recovered from future taxable income.
Judgment is required to continually assess changing tax interpretations, regulations and legislation to ensure liabilities are
complete and to ensure assets, net of valuation allowances, are realizable. The impact of different interpretations and
applications could be material.
4. Property, plant and equipment
The following table summarizes movements in Northland’s PP&E by category:
6
Construction-
in-progress
Plant and
operating
equipment(3)
Land, buildings
and leasehold
improvements
Lease ROU
asset
Other
equipment (1)
Total
Cost
January 1, 2022
Additions
Transfer from CIP
Exchange rates changes
Other movements (2)
December 31, 2022
Additions
Transfer from CIP
Exchange rates changes
Other movements (2)
December 31, 2023
Accumulated depreciation
January 1, 2022
Exchange rates changes
Depreciation
Disposals and others
December 31, 2022
Exchange rates changes
Depreciation
Disposals and others
December 31, 2023
Net book value
December 31, 2022
December 31, 2023
$
622,189 $ 10,116,903 $
1,990,204 $
179,293 $
374,936
(83,677)
52,841
69,936
78,033
10,694
1,414
3,252
11,552
—
10,282
3,995
(124,990)
841,299 $
(365,592)
9,909,974 $
$
(130,623)
1,874,529 $
(4,316)
190,524 $
43,625 $ 12,952,214
460,421
2,583
2,392
(1,630)
827
76,182
(624,694)
47,797 $ 12,864,123
—
375,632
(1,024,683)
36,222
56,684
850,776
162,486
(10,777)
217,693 $ 10,702,808 $
(277,112)
10,960
46,521
160,136
8,438
(69)
2,053,994 $
2,796
600
(4,697)
235,744 $
665
10,975
2,293
(567)
490,462
—
210,039
(293,222)
61,163 $ 13,271,402
— $ 2,673,684 $
630,808 $
27,241 $
—
—
21,528
461,088
5,997
89,020
(357,671)
—
— $ 2,798,629 $
(118,085)
607,740 $
657
15,661
(3,022)
40,537 $
—
—
33,355
422,904
(20,372)
—
— $ 3,234,516 $
4,492
13
151,819
17,039
(4,793)
759,258 $
(420)
57,169 $
34,015 $ 3,365,748
27,545
(637)
5,321
934
571,090
(477,844)
39,633 $ 3,486,539
39,567
1,707
3,838
(4,652)
40,526 $ 4,091,469
595,600
(30,237)
$
$
$
$
841,299
7,111,345
1,266,789
149,987
$
217,693 $ 7,468,292 $
1,294,736 $
178,575 $
8,164
9,377,584
20,637 $ 9,179,933
(1) Other equipment includes vehicles, meteorological towers, office equipment, furniture and fixtures, and computer software.
(2) Includes disposal and transfers of assets, adjustments related to ARO assets, and recognition of accruals, net of amounts paid, under the LTIP.
(3) Investment Tax Credits (“ITC”) earned by the New York Wind projects, during the year, have been recorded as a reduction to the cost of plant and
operating equipments and is included in the other movements line (Note 13.3).
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(a) As at December 31, 2023, construction-in-progress primarily relates to Oneida Storage, and Thorold expansion projects
in Canada and other routine capital maintenance work on certain operational projects in Canada, USA and Colombia.
(b) In 2022, Northland entered into a Contribution Agreement (the "Grant Agreement") with Natural Resource Canada
("NRCan"), under which NRCan shall provide a contribution (the "Grant") in the form of financial assistance to support the
development and construction of lithium-ion battery energy storage project in southern Ontario, Canada (the “Oneida
Energy Storage Project”). The total value of the Grant amounts to the lower of $50 million or 30% of the total project cost,
to be disbursed in two tranches of $22 million in 2023 and $28 million in 2024. During the year ended December 31, 2023,
first tranche of the Grant, amounting to $20 million (net of 10% hold back, $2 million) was received, which has been
recognized as an offset to the carrying value of construction in progress and presented under the other movements line.
(c) For the year ended December 31, 2022, other movements includes derecognition of capitalized project cost of
$91 million, which is contributed by Northland to the Hai Long project and recognized as an Investment in Joint Venture.
Refer to (Note 8(a)).
(d) On April 7, 2022, Northland completed the sale of its two efficient natural gas facilities in Ontario, Canada, with a net
book value of $5 million as at the date of sale. The respective costs and the accumulated depreciation for these facilities
have been included in the other movements line above.
5. Contracts and other intangible assets
The following table summarizes the movements in Northland’s intangible asset contract balances:
Cost
As at January 1
Acquired
Additions
Disposals
Exchange rates changes
December 31,
Accumulated Amortization
As at January 1
Disposals
Amortization
Exchange rates changes
December 31,
Net book value
2023
2022
$
723,522 $
797,719
—
1,050
(18,224)
7,947
37,771
32,780
(148,925)
4,177
714,295 $
723,522
207,747 $
300,084
—
57,015
2,663
(148,882)
53,611
2,934
267,425 $
207,747
446,870 $
515,775
$
$
$
$
Acquired represents contracts assets capitalized, in 2022, as a part of the acquisition of a majority equity interest in the
Oneida Energy Storage Project, and the acquisition of 100% equity interest in certain early to late-stage development
projects in the Alberta, Canada (the “Alberta Portfolio”).
| NORTHLAND POWER INC. |
| 2023 ANNUAL REPORT |
83
6. Goodwill
Acquired goodwill was allocated to CGUs expected to benefit from the synergies of the acquisition. Changes in the goodwill
during the years ended December 31, 2023, and December 31, 2022 are summarized below:
Cost
As at January 1
Exchange rates changes
December 31,
Accumulated Impairment
As at January 1
Impairment (Note 22)
December 31,
Net Book Value
2023
2022
820,699 $
89,898
910,597 $
861,454
(40,755)
820,699
(108,081) $
(108,081)
(163,169)
—
(271,250) $
(108,081)
639,347 $
712,618
$
$
$
$
$
During the December 31, 2023, Northland recorded an impairment charge amounting to $163 million, representing full
amount of goodwill relating to its Spanish portfolio, upon completing the required annual impairment test. Refer to Note 22
for additional information on impairment.
7. Leases
7.1 Northland as lessor
Spy Hill’s long-term PPA is classified as a finance lease arrangement, whereby Northland is considered to have leased the
Spy Hill facility to Saskatchewan Power Corporation (“SaskPower”) for 25 years ending in 2036. For the year ended
December 31, 2023, finance lease income of $11 million (2022 - $11 million) was recognized in the Consolidated statements
of income (loss).
The amounts receivable under finance lease accounting are as follows:
As at
December 31, 2023
December 31, 2022
Minimum lease payments
Minimum lease
payments
Present value of
minimum lease
payments
Minimum lease
payments
Present value of
minimum lease
payments
Within one year
After one year but not more than five years
More than five years
Less: Unearned finance income
Total finance lease receivable
Current portion (Note 9)
Long-term
$
$
$
16,183 $
64,806
125,258
206,247 $
(80,256)
125,991 $
$
5,800 $
28,753
91,438
125,991 $
—
125,991 $
5,800
120,191
16,188 $
64,749
141,445
222,382 $
(91,101)
131,281 $
$
5,343
26,410
99,528
131,281
—
131,281
5,343
125,938
The interest rate inherent in the lease was fixed for the entire lease term at the lease inception date at approximately 8.4%
per annum.
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| 2023 ANNUAL REPORT |
7.2 Northland as lessee
Northland and several of its subsidiaries have entered into leases for land with private and public landowners, buildings,
and operating equipment. The original terms of these leases range up to 50 years.
The amount of the lease ROU asset and associated depreciation by type of underlying asset as at December 31, 2023 are as
follows:
January 1, 2022
Additions
Other movements (1)
Depreciation expense
Exchange rates changes
December 31, 2022
Additions
Other movements (1)
Depreciation expense
Exchange rates changes
December 31, 2023
Land
Vehicle
Equipment
Building
Total
$
123,871 $
912 $
13,363 $
13,906 $
152,052
4,668
(673)
(7,277)
3,265
655
(3)
(1,833)
(68)
2,034
(427)
(4,810)
127
4,195
(191)
(1,741)
14
11,552
(1,294)
(15,661)
3,338
$
123,854 $
(337) $
10,287 $
16,183 $
149,987
29,523
67
(9,912)
313
1,406
5,096
(1,727)
188
—
(5,047)
(1,807)
36
15,592
(1,597)
(3,593)
50
46,521
(1,481)
(17,039)
587
$
143,845 $
4,626 $
3,469 $
26,635 $
178,575
(1) Other movements include disposal and transfers of leased assets.
The lease ROU asset balance is included in PP&E in the Consolidated statements of financial position.
Northland expenses payments for leases that are short-term (i.e. term of 12 months or less) and low value, as well as
variable payments that are excluded from lease payments, such as usage-based fees or utility charges. For the year ended
December 31, 2023, lease expense of $7 million (2022 - $6 million) was recognized and presented within the G&A and
operating costs lines in the Consolidated statements of income (loss).
The following table summarizes the movements in Northland’s lease liabilities:
As at January 1
Additions
Accretion of interest (Note 21)
Payments
Exchange rates changes
December 31,
Current
Non-current
Total lease liabilities (Note 15)
2023
2022
$
155,212 $
150,982
46,521
4,073
(19,613)
1,033
187,226 $
16,141
171,085
187,226 $
11,552
3,382
(14,834)
4,130
155,212
16,748
138,464
155,212
$
$
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| 2023 ANNUAL REPORT |
85
8. Investment in joint ventures
Below are Northland’s significant joint ventures as at December 31, 2023 and December 31, 2022. The entities have share capital consisting solely of ordinary shares,
which are held directly or indirectly by Northland. The country of incorporation or registration is also their principal place of business, and the proportion of
ownership interest is the same as the proportion of voting rights held.
Name of Joint Venture
Baltic Power (Note 8.1)
Hai Long (Note 8.2)
Others (Note 8.3, 8.4 and 8.5)
Total
Carrying Amount as at
Share of profit (loss) for the year ended
December 31, 2023 December 31, 2022 December 31, 2023 December 31, 2022
$
$
360,747 $
128,341 $
(220,490) $
526,282
12,856
280,668
32,556
(42,877)
(16,482)
899,885 $
441,565 $
(279,849) $
(966)
—
(1,891)
(2,857)
The place of business / country of incorporation of Baltic Power and Hai long is Poland and Taiwan, respectively. As of December 31, 2023, Northland’s ownership
percentage in Baltic Power and Hai Long stands at 49% and 51% (2022: 49% and 60%), respectively.
The table below provides reconciliation of the carrying amounts of significant joint venture to the underlying net assets of the joint ventures:
a) Reconciliation to equity investments carrying amounts
Opening
net assets
Equity
contribution
Net income
(loss) for the
period
Currency
translation
gain (loss)
Fair value
adjustments*
Closing net
assets
Northland’s
share in %
Northland’s
share in net
assets
Other
adjustments
Carrying amount
at Northland’s
share
As at December 31, 2023
Baltic Power
Hai Long
$ 254,814 $
903,951 $
(451,268) $
30,830
— $ 738,327
329,858 1,117,024
(71,461)
3,142
(346,637) 1,031,926
Total
$ 584,672 $ 2,020,975 $
(522,729) $
33,972 $
(346,637) $ 1,770,253
As at December 31, 2022
Baltic Power (a)
$ 257,077 $
— $
(1,691) $
(572)
Hai Long (b)
Total
—
324,426
(28)
5,460
$ 257,077 $
324,426 $
(1,719) $
4,888 $
— $ 254,814
—
329,858
— $ 584,672
49%
51%
49%
60%
$
360,747 $
526,282
$
887,029 $
— $
—
— $
$
123,738 $
4,603 $
197,915
82,753
$
321,653 $
87,356 $
360,747
526,282
887,029
128,341
280,668
409,009
* This represents fair value adjustment, recognized during the year as a result of change in ownership interest of Northland into the Hai Long joint venture (Note 8.2).
(a) The other adjustments in the carrying amount of Baltic Power primarily represent Northland’s higher share of equity investment contributed during the year
ended December 31, 2022.
(b) The other adjustments in the carrying amount of Hai Long, include an amount of $91 million, representing capitalized development cost contributed to Hai Long
by Northland during the year ended December 31, 2022.
In addition to the above, Northland’s share in commitments and contingencies in relation to its joint ventures are summarized in Note 8(d).
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| 2023 ANNUAL REPORT |
Summarized below is the financial information for the significant joint ventures. The disclosed information reflects the amounts presented in the Consolidated
Financial Statements of the relevant joint venture, reflecting their 100% financial information and not Northland’s share of those amounts. They have been amended
to reflect adjustments made by Northland when using the equity method, including acquisition date fair value adjustments and differences in accounting policies.
b) Summarized statement of financial position, at 100%
Current assets
Cash and cash
equivalents
Other current
assets
Total current
assets
Non-current
assets
Current
liabilities
Financial
liabilities
Non-current liabilities
Other non-
current
liabilities
Total non-
current
liabilities
Net Assets
As at December 31, 2023
Baltic Power
Hai Long
Total
As at December 31, 2022
Baltic Power
Hai Long
Total
$
$
$
$
276,359 $
1,417
277,776 $
189,411 $
465,770 $ 1,805,022 $
425
1,842
1,438,150
189,836 $
467,612 $ 3,243,172 $
344,679 $ 1,187,786 $
208,274
199,792
552,953 $ 1,387,578 $
— $
—
— $
1,187,786 $
199,792
1,387,578 $
738,327
1,031,926
1,770,253
44,358 $
107,152
151,510 $
20,137 $
3,373
23,510 $
64,495 $
110,525
175,020 $
211,118 $
262,931
474,049 $
18,813 $
42,967
61,780 $
— $
—
— $
1,986 $
631
2,617 $
1,986 $
631
2,617 $
254,814
329,858
584,672
c) Summarized statement of comprehensive income, at 100%
Year ended December 31, 2023
Baltic Power
Hai Long
Total
Year ended December 31, 2022
Baltic Power
Hai Long
Total
Interest income
G&A
Depreciation and
amortization
Fair value changes Income tax expense
Net income (loss)
$
$
$
$
4,396 $
—
4,396 $
920 $
—
920 $
(3,560) $
4,659
1,099 $
— $
—
— $
(483) $
—
(483) $
(224) $
—
(224) $
(451,621) $
(75,188)
(526,809) $
(61)
—
(61) $
— $
(932)
(932) $
— $
—
— $
(451,268)
(71,461)
(522,729)
(1,691)
(28)
(1,719)
| NORTHLAND POWER INC. |
| 2023 ANNUAL REPORT |
87
d) Letters of credit and parental guarantees issued by Northland
The table below summarizes the Northland’s share of letters of credit and the parental guarantees issued in favor of the
joint ventures:
As at
Baltic Power
Hai Long (a)
Other joint ventures
Total
December 31, 2023
December 31, 2022
$
$
32,145 $
830,429
2,626
865,200 $
203,696
328,268
120,171
652,135
(a) This represents letters of credit issued by Northland, for its share, as a sponsor of the Hai Long project to support the
credit obligations associated with the construction of the Hai Long projects.
8.1 Baltic Power offshore wind project
Northland holds a 49% interest in the Baltic Power offshore wind project (the "Baltic Power”) in the Baltic Sea. Baltic Power
is structured as a standalone legal entity, and Northland has an interest in the net assets of Baltic Power. Accordingly,
Northland has classified its interest in Baltic power as a joint venture, accounted for under the equity method in accordance
with IAS 28 (Investment in Associates and Joint venture).
During the year ended December 31, 2023, upon Baltic Power securing the Contract for Differences (CfD) contract from the
Polish government and signing of credit agreement (financial close), Northland made an additional contribution of $129
million (€88 million) into the Baltic Power JV. This additional contribution has been recognized as a part of the carrying
amount of investment in the joint venture, representing Northland’s share in the fair value of identified contract asset.
Additionally, during the year ended December 31, 2023 Baltic Power signed and closed a credit agreement to secure 20-
year long-term non-recourse project financing amounting to $5.2 billion.
Northland has provided a long-term shareholder loan amounting to $193 million to the Baltic Power. The loan carries
interest at the rate of EURIBOR plus 3.8%. The loan has a contractual maturity of 26 years with repayments commencing
upon Baltic Power Projects achieving commercial operations and will be made in semi-annual installments, due in February
and August each year. The carrying value of this shareholder loan approximates its fair value. In the Consolidated
statements of financial position, this loan, including accrued interest, is classified as non-current and presented under Other
non current assets (Note 10.1).
For the year ended December 31, 2023, Northland recharged expenses, including staff costs of $11 million (2022 -
$14 million), to Baltic Power (Note 25.2).
8.2 Hai Long offshore wind project
Northland holds 31% (2022: 60%) economic interest in the Hai Long Offshore Wind Projects (the “Hai Long Project”),
through a 51% (2022: 100%) direct shareholding in NP Hai Long Holding BV (“Hai Long”).
Formation of Joint Venture:
On July 18, 2022, Northland entered into a Shareholders’ Agreement (“SHA”) with Yushan Energy Co. Ltd (YECL), a jointly
owned company by Mitsui & Co. and Yushan Energy PTE. LTD. As per the SHA terms, Northland and YECL established Special
Purpose Vehicles with ownership interests of 60% and 40%, respectively in the Hai Long Project. Per the contractual terms
of SHA, certain key activities of the Hai Long Project are jointly controlled by Northland (through a then wholly owned
subsidiary, NP Hai Long Holding BV- an intermediate holding company of the Hai Long Project) and YECL, as defined under
IFRS 11 "Joint Arrangements”. Consequently, Northland recognized its investment in the Hai Long Project as a jointly
controlled investment and, accounted for using the equity method.
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| NORTHLAND POWER INC. |
| 2023 ANNUAL REPORT |
Sell–down:
On December 14, 2022, Northland signed a share purchase agreement with Gentari International Renewables Pte. Ltd
(“Gentari”) to sell 49% of Northland’s ownership interest in NP Hai Long Holding BV, for an aggregate consideration of
$693 million, net of transaction cost of $17 million. This transaction, completed in December 2023, resulted in Gentari
becoming a 49% shareholder in NP Hai Long Holding BV, holding a 29% indirect economic interest in the downstream Hai
Long Project, previously jointly owned by Northland and Mitsui at 60% and 40%, respectively. Northland’s effective
ownership in the Hai Long Project has now been reduced to 31%, whereas Mitsui continues to retain its 40% interest in the
Hai Long Project.
Following the ownership change, a control assessment under IFRS 3 “Business Combinations” determined that Northland,
Gentari, and Mitsui jointly control the Hai Long Project. Consequently, Northland de-consolidated NP Hai Long Holding BV
and recognized its remaining 51% ownership (or 31% effective ownership in the Hai Long Project) as an investment in the
joint venture per IFRS 11. The remaining 51% ownership in NP Hai Long Holding BV (or 31% effective ownership in the Hai
Long Project) was fair valued, resulting in a gain on the sell-down of $192 million. The gain on disposal has been included
under the Other (income) expense line within the Consolidated statements of income (loss).
During year ended December 31, 2023, Hai Long project signed and closed a credit agreement to secure a $5 billion (NTD
$117 billion) 20-year long-term non-recourse project financing.
Northland has provided a long-term shareholder loan amounting to $202 million to the Hai Long Project. The loan carries
interest at the rate of 6% per annum. The loan has a contractual maturity of 20 years with repayments commencing upon
Hai Long Project achieving commercial operations and will be made in semi-annual installments, due on 30 June and 31
December each year over. The carrying value of this shareholder loan approximates its fair value. In the Consolidated
statements of financial position, this loan, including accrued interest, is classified as non-current and presented under Other
non current assets (Note 10.1).
For the year ended December 31, 2023, Northland recharged expenses, including staff costs of $26 million (2022 - $10
million), respectively to the Hai Long Project (Note 25.2).
8.3 Nordsee cluster offshore wind projects
On May 25, 2023, Northland entered into a Share Purchase Agreement (SPA) to complete the sale of its remaining 49%
ownership stake in the Nordsee Offshore Wind Cluster (the “Cluster”) to its partner on the portfolio, RWE Offshore Wind
GmbH (RWE), who already owns the remaining 51% stake in the Cluster. Pursuant to the terms of the SPA, RWE took over
all the assets, liabilities, and the committed contractual obligations relating to the Cluster for a cash consideration of $50
million which resulted in a gain on disposal amounting to $24 million. The gain on disposal has been included under the
Other (income) expense line within the Consolidated statements of income (loss).
8.4 Suba solar project
During the year ended December 31, 2023, after an in-depth evaluation, Northland and EDF Renewables have jointly
elected not to proceed with the development of the Suba solar project. As a result of this decision, an expense of $15
million, relating to the carrying value of equity accounted investment (Joint venture) in Suba solar project has been
recognized as an impairment charge in the Consolidated statements of income (loss) and has been included under the Share
of (profit) loss from equity accounted investees.
8.5 NorthWind and CanWind offshore wind projects
During the year ended December 31, 2023, Northland completed the sale of its 49% stake in CanWind and NorthWind, two
early-stage offshore wind development projects in Taiwan (collectively referred to as the “Taiwan Round 3 Projects”) to
Gentari. Pursuant to the investment agreement, Gentari acquired 49% indirect equity interest in the Taiwan Round 3
Projects whereas, Northland retained the remaining 51%.
The contractual terms of agreement, requires a joint decision making in relation to certain key activities of Taiwan Round 3
Projects, during the construction and the operation stages. Accordingly, management concluded Northland’s investment in
Taiwan Round 3 Projects as a jointly controlled investment and, therefore, accounted for using the equity method. This
transaction resulted in a recognition of investments in joint ventures with an initial carrying value of $8 million and gain on
derecognition of investments in subsidiaries, amounting to $19 million. The gain on disposal has been included under the
Other (income) expense line within the Consolidated statements of income (loss).
| NORTHLAND POWER INC. |
| 2023 ANNUAL REPORT |
89
9. Trade and other receivables
As at
Trade receivables
Indirect taxes receivable
Income taxes receivable
Finance lease receivable (current portion) (Note 7.1)
Short term deposits with bank (a)
Others
Total
December 31, 2023
December 31, 2022
$
298,221 $
58,923
16,165
5,800
—
16,905
$
396,014 $
292,152
32,639
—
5,343
146,524
72,979
549,637
(a) As at December 31, 2022, short term deposits with bank includes advance payment, amounting to $122 million, made to
Northland’s share registrar in relation to the Series 3 Preferred shares which were redeemed on January 3, 2023 (Note 16.3)
and a short term bank deposit amounting to $25 million, held with a reputable Canadian bank and carried an interest rate
of 5.01% with the maturity of November 2023).
10. Other non-current assets
As at
Loan receivable from joint ventures (Note 10.1)
Long-term deposits (a)
Trade receivables - Non current portion
Receivable related to terminated derivative contracts
Prepaid expenses - Non current portion
Tax receivable on Band adjustments
Other (1)
Total
December 31, 2023
December 31, 2022
$
405,368 $
133,620
20,490
20,031
5,336
3,899
10,622
$
599,366 $
—
114,789
76
32,608
7,765
7,125
7,424
169,787
(1) Other include deferred financing cost amounting to $5 million (2022 - $3 million), associated with the syndicated revolving facility (Note 14).
(a) Long-term deposits include decommissioning deposits relating to offshore wind facilities, amounting to $123 million
(2022: $122 million).
Additionally, in connection with the decommissioning deposits, Gemini provided a letter of credit to the Dutch government
to secure future decommissioning liability for Gemini. The letter of credit is collateralized by a long-term deposit amounting
to $59 million (2022 - $57 million), held by project lenders in a money market fund with the maturity in 2042 and earns
interest at a rate of 6-month EURIBOR plus 0.8%.
10.1 Loan receivable from joint ventures
As at
Baltic (Note 8.1)
Hai Long (Note 8.2)
Total (Note 25.2)
December 31, 2023
December 31, 2022
$
$
197,293 $
208,075
405,368 $
—
—
—
The above loan receivable balances, from Hai Long and Baltic, also include accrued interest amounting to $6 million and $4
million, respectively, as of December 31, 2023.
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| 2023 ANNUAL REPORT |
11. Trade and other payables
Northland’s trade and other payables are summarized as follows:
As at
Trade payables
Tax payable
SDE subsidy payable (a)
Short-term loan payable to joint ventures (b)
Provision for redemption of Series 3 Preferred Shares
Current portion of provision for additional equity contributions
Other payables and accrued liabilities (c)
Total
December 31, 2023
December 31, 2022
$
161,638 $
88,365
25,756
14,999
—
—
$
158,703
449,461 $
153,572
130,742
327,519
—
121,524
11,464
214,392
959,213
(a) SDE subsidy is payable to the Government of Netherlands on account revenues earned in excess of higher annual
average Dutch wholesale market (“APX”) prices in the year ended December 31, 2022.
(b) The short-term loan payable to the joint ventures, carries interest at an annual rate of 3 month EURIBOR plus 1.1% and
has a contractual maturity date of April 2024 (Note 25.2).
(c) Other payables and accrued liabilities include accruals in relation to development and other operational costs amounting
to $103 million (December 31, 2022 - $119 million), deposit received amounting to nil (December 31, 2022 - $58 million),
and accrued interest amounting to $26 million (December 31, 2022 - $18 million).
12. Management of capital
Northland’s strategy to finance general development efforts and investments in project entities utilizes internally generated
cash flows, equity issuances, corporate debt, and notably corporate credit facility borrowings. Refer to Note 13 and Note 14
for additional information.
Northland defines capital that it manages as the aggregate of its equity, including non-controlling interests, interest-bearing
loans and borrowings, corporate credit facilities and net proceeds from the sale of assets. Northland’s objectives when
managing capital are to (i) ensure the stability and long-term sustainability of dividends to shareholders and (ii) finance
assets with non-recourse debt that is fully amortized over the term of the underlying sales arrangements.
Northland exercises discretion in the amount of dividends declared to shareholders, the terms of its Dividend Reinvestment
Plan (DRIP), the level of issuances under its At-The-Market Equity Program (“ATM Program”), return of capital to
shareholders, issuance of new Shares and the issuance or redemption of preferred shares.
Northland’s strategy has been to finance its operating entities (which are subsidiaries of Northland) primarily using non-
recourse debt, either at the subsidiary level or holding company level in the case of EBSA, New York Wind and the Spanish
Portfolio. The interest rate on the debt at Northland’s power generation facilities is fixed (or effectively fixed using interest
rate swaps) and principal is fully repaid (amortized) generally over each facility’s PPA term. This ensures a power generation
facility is debt-free at the expiry of its original sales arrangement, after which its economics become less predictable. For
EBSA, the interest rate on the non-recourse debt at its holding company is effectively fixed over the lending period, but the
principal is expected to be extended and upsized regularly due to the perpetual and growing nature of its utility business.
As at December 31, 2023, total managed capital was $11.7 billion (2022 - $11.7 billion), comprising equity of $4.5 billion
(2022 - $4.7 billion), non-recourse facility-level loans and borrowings totaling $7.2 billion (2022 - $7.0 billion) and corporate
credit facilities totaling $116 million (2022 - nil).
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91
Changes in loans and borrowings (Note 13) and corporate credit facilities (Note 14) are summarized in the table below:
Year ended December 31, 2023
Project level
borrowings
Tax equity
financing(2)
Green
Subordinated
Notes
Corporate
credit
facilities(3)
Total
Total, beginning of the year
$
6,971,722 $
— $
— $
(2,817) $
6,968,905
Financings, net of fees
Repayments
Other non-cash (1)
Exchange rate differences
Total, end of the year
331,326
(879,285)
65,426
42,337
287,003
490,016
1,106,632
2,214,977
—
(243,498)
(546)
—
(996,047)
(1,875,332)
1,033
—
1,918
1,304
(175,121)
43,095
$
6,531,526 $
42,959 $
491,049 $
110,990 $
7,176,524
(1) Other non-cash changes include amortization of fair value adjustments and deferred financings costs.
(2) Other non-cash adjustments for Tax Equity Financing also include a reduction in the Tax Equity liability, as a result of allocation of ITC to the tax equity
partner (Note 13.3).
(3) The balance of corporate credit facilities, as of December 31, 2023, is represented by the deferred financing cost amounting to $5 million (2022 - $3
million) associated with the syndicated revolving facility. This is included within the other assets in the Consolidated statements of financial position
(Note 10 and 14).
Year ended December 31, 2022
Total, beginning of the year
Financings net of fees paid
Repayments
Other non-cash (1)
Foreign exchange
Project level
borrowings
Corporate credit
facilities
$
7,592,214 $
41,825 $
2,029,252
(2,681,275)
8,753
22,778
770,021
(815,033)
80
290
Total
7,634,039
2,799,273
(3,496,308)
8,833
23,068
Total, end of the year
(1) Other non-cash changes include amortization of fair value adjustments and deferred financings costs.
6,971,722 $
$
(2,817) $
6,968,905
13. Loans and borrowings
Northland’s loans and borrowings, excluding the corporate credit facilities, as disclosed in Note 14, are comprised of the
following:
As at
Project level borrowing (Note 13.1)
Tax equity financing (Note 13.3)
Loans and borrowings at the project level
Green Subordinated Notes, Series 2023-A (Note 13.2)
Total loans and borrowings
Less: Current portion of loans and borrowings
Non-current portion of loans and borrowings
December 31, 2023
December 31, 2022
$
$
$
$
6,531,526 $
6,971,722
42,959
—
6,574,485 $
6,971,722
491,049
7,065,534 $
744,812
6,320,722 $
—
6,971,722
793,881
6,177,841
The estimated fair value of loans and borrowings, including Tax Equity Financing and Green Subordinated Notes, as at
December 31, 2023 is $7.2 billion (2022 - $7.0 billion).
As at and for the year ended December 31, 2023, and as at the approval date of these Consolidated Financial Statements,
Northland has complied with all the applicable financial covenants under the respective credit agreements.
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13.1 Project level non-recourse borrowing
Northland generally finances projects and its operating facilities through non-recourse, secured credit arrangements either
at the subsidiary or at the holding company level. These loans and borrowing are summarized in the table below:
Name of the Projects
Rate (1)
Maturity
New York Wind (3)
Nordsee One (3)
EBSA (NPCDI) (3)
Jardin (3)
Thorold (3)
Kirkland Lake(3)
Gemini (3)
Deutsche Bucht (3)
Mont Louis
North Battleford (3)
Solar Phase I (3)(4)
Solar Phase II (4)
McLean's
Helios (5)
Grand Bend
Cochrane Solar (3)
Spy Hill (3)
Spanish Portfolio (3)
Oneida Storage (3)
Weighted average and total
Current
Long-term
(1) The weighted average all-in interest rates of the subsidiary borrowings.
2.0%
2.3%
4.2%
6.0%
6.4%
4.2%
3.6%
2.4%
6.6%
5.0%
4.4%
4.5%
6.0%
15.0%
4.2%
4.6%
4.1%
2.0%
6.4%
3.4%
2025
2026
2026
2029
2030
2030
2031
2031
2031
2032
2032
2034
2034
2034
2035
2035
2036
2042
5.1 (d)
$
$
Amount drawn as at
December 31, 2023 (2)
$
Amount drawn as at
December 31, 2022 (2)
327,059
535,382
518,847
65,796
206,980
45,955
1,919,470
1,028,411
58,482
502,797
148,763
108,187
100,143
9,767
281,136
149,261
119,584
845,702
—
6,971,722
793,881
6,177,841
241,556 $
397,458
716,618
61,741
199,337
44,235
1,750,305
933,017
54,346
483,730
135,028
100,060
93,419
—
264,074
139,195
114,229
788,178
15,000
6,531,526 $
744,812
5,786,714 $
(2) Amounts drawn as at December 31, 2023 and 2022, exclude letters of credit secured by the facilities or project-level credit agreements.
(3) Net of transaction costs and/or fair value adjustments.
(4) Solar Phase I and Solar Phase II include the nine entities that comprise Canadian Solar facilities.
(5) The all-in interest rate for Helios is in relation to a loan, which is denominated in Colombian Peso ("COP").
(a) As at December 31, 2023, $115 million of letters of credit secured by facility or project-level credit agreements was
outstanding (December 31, 2022 -$104 million).
(b) On March 30, 2023, Northland restructured EBSA’s long-term loan (“EBSA Loan”) resulting in an extension of the
maturity date of EBSA Loan to March 2026 from the previous maturity date of December 2024. In addition to this, certain
covenants were amended to allow EBSA more flexibility to pursue growth opportunities into the generation business. The
aggregate amount of EBSA Loan and the applicable interest remained unchanged. Based on the terms of the amended loan
agreements, Northland assessed EBSA Loan restructuring as a modification of a loan as defined under IFRS 9. Accordingly,
gain on modification amounting to $1 million was recognized and is presented under the “Finance Cost” line in the
Consolidated statements of income (loss).
Subsequently, on December 18, 2023, Northland undertook a restructuring and upsizing of the EBSA-related credit facility,
increasing it by an additional $190 million, net of transaction cost to a total of $711 million. The facility's maturity date was
extended to December 18, 2026, accompanied by an increase in the applicable all-in annual rate to 4.20%, from the
previous rate of 3.70%. Based on the terms of the amended loan agreements, Northland assessed the second restructuring
of the EBSA Loan as an Extinguishment of loan as defined under IFRS 9. Accordingly, loss on extinguishment amounting to
$2 million was recognized and is presented under the “Finance Cost” line in the Consolidated statements of income (loss).
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| 2023 ANNUAL REPORT |
93
(c) On April 24, 2023, Northland restructured and upsized the commercial bank tranche of its loan related to the Thorold
facility (“Thorold Loan”). The restructuring resulted in (i) additional debt of $26 million to finance the upgrade to the
Thorold facility; (ii) a decrease in all-in rate from 6.7% to 6.4%; and (iii) reduction of certain LC requirements. The loan
maturity date remains unchanged as March 2030. Based on the terms of the amended loan agreements, Northland has
assessed Thorold Loan restructuring as modification of loan as defined under IFRS 9. Accordingly, loss on modification
amounting to $1 million was recognized and is presented under the “Finance Cost” line in the Consolidated statements of
income (loss).
(d) On May 15, 2023, Northland closed the lending arrangement with Canada Infrastructure Bank (“Credit Agreement”) in
relation to the Oneida Energy Storage Project. Under the CIB Credit Agreement, lenders have established a non-revolving
construction and term loan credit facility, which is comprised of Tranche A and Tranche B for $235 million and $444 million,
respectively, to finance the project construction cost and a non-revolving credit facility, comprising of Tranche C for
$15 million, to cash collateralize letters of credits. The entire amount of Tranche C had been utilized to provide letter of
credit in favor of IESO relating to Interconnection Bid security. The maturity date of Tranche C is linked with the date of
project reaching the commercial operations.
(e) On December 21, 2023, Northland amended its Spanish Portfolio debt agreement, allowing Northland to better manage
its cash flows and debt servicing ability. Key amendments include modifying the repayment schedule (including deferring
the scheduled repayments of $33 million due in Q4 2023 to a later period), introducing additional cash sweep payments in
2024 and 2025 to manage the potential interim volatility in merchant pricing, adjusting debt sizing ratios for wind assets
post-2025 and implementing a pool price rebalancing mechanism. The overall debt size, pricing, and tenure remain
unchanged. Northland assessed the above amendments as modification of a loan, as defined under IFRS-9, recognizing a
modification loss of $25 million, which is presented under the “Finance Cost” line in the Consolidated statements of income
(loss). Transaction costs of $1 million were treated as deferred costs offsetting the revised carrying value of debt.
13.2 Green Subordinated Notes, Series 2023-A
On June 21, 2023, Northland closed the issuance of $500 million ($490 million, net of transaction costs) of Fixed-to-Fixed
Rate Green Subordinated Notes, Series 2023-A, with a maturity date of June 30, 2083 (the “Green Notes”). The Green Notes
carry a fixed coupon rate of 9.250% per annum until the first reset date on June 30, 2028. Thereafter, the coupon rates
reset at 5-year Government of Canada yield plus i) 5.844% for the period from June 30, 2028, until June 30, 2033, ii) 6.094%,
for the period from June 30, 2033, to June 30, 2048, and iii) 6.844% for the period from June 30, 2048, to the maturity date
on June 30, 2083.
13.3 Tax-equity financing
During the year ended December 31, 2023, the funding of tax-equity financing, in relation to the New York Wind, was
completed and as a result the project received $287 million, net of transaction cost of $10 million, representing 100% of the
total tax equity commitment. Tax-equity financing is denominated in US Dollar and the implied interest cost on this
financing reflects the agree targeted rate of return with the tax equity investor. The maturity date by which the tax equity
investor is expected to achieve the agreed targeted rate of return, is estimated to be in June 2029.
Upon achieving the commercial operations, during the year ended December 31, 2023, management determined that the
ITCs are deemed to have been earned as of December 31, 2023 and therefore the tax equity liability was reduced by the ITC
amount of $239 million (Note 12) with a corresponding reduction in property, plant and equipment (Note 4).
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14. Corporate credit facilities
The corporate credit facilities are summarized in the table below:
Facility
size
Amount
drawn as at
December 31,
2023
Outstanding
letters of
credit (5)
Available
capacity
Maturity
Amount
drawn as at
December
31, 2022
Sustainability linked loan (SLL) syndicated
revolving facility (1)
Bilateral letter of credit facility
Export credit agency backed Letter of
Credit ("LC") facility (2)
Export credit agency backed LC facility (3)
Hai Long Related credit A LC Facility
$ 1,000,000 $
115,656 $
361,057 $
523,287
Sep. 2028 $
150,000
200,000
200,000
500,000
—
—
—
—
133,746
16,254
Sep. 2024
89,291
110,709
Mar. 2025
42,168
157,832
n/a
475,936
24,064
Sep. 2027
Total
$ 2,050,000 $
115,656 $ 1,102,198 $
832,146
$
—
—
—
—
—
—
(1) The amount drawn under the syndicated revolving facility is denominated in Canadian Dollars amounting to $25 million and Euro amounting to
€62 million (CAD equivalent of $91 million, converted at the period-end exchange rates) and the maturity date was extended to September 2028.
(2) During June 2023, the Export credit agency backed LC facility size was increased by $100 million and the maturity date was extended to March 2025.
(3) With effect from December 29, 2023, the facility limit increased from by $100 million. This facility does not have a specified maturity date.
(4) Deferred financing cost, as at December 31, 2023, associated with the syndicated revolving facility amounting to $5 million (December 31, 2022 - $3
million) is included within the other assets in the Consolidated statements of financial position (Note 10).
(5) As at December 31, 2023, outstanding letters of credit include LCs issued in favor of joint ventures amounting to $833 million (Note 8 (d)).
Amounts drawn and letters of credit under the syndicated revolving facility and bilateral letter of credit are collateralized by
general security agreement that constitutes a first-priority lien on all of the real property, present and future property and
assets of Northland.
15. Provisions and other liabilities
Details of Northland’s provisions and liabilities are summarized below:
As at
December 31, 2023 December 31, 2022
Decommissioning liabilities (Note 15.1)
$
429,165 $
Lease liability (Note 7.2)
Band adjustments
Loan payable to minority shareholder of a subsidiary (a)
Pension and benefits (Note 15.2)
Others
Total provisions and other liabilities
Less: Current portion of provisions and other liabilities
Long term portion of Provisions and other liabilities
187,226
66,648
43,498
34,654
7,428
768,619 $
(28,236)
740,383 $
$
$
372,747
155,212
121,523
57,228
22,565
8,905
738,180
(32,793)
705,387
(a) Loan payable to a shareholder represents amount owed by Nordsee One under a shareholder loan arrangement on
which interest is accrued at an annual rate of 10% and repayments are made based on the partner’s share of distributable
funds from operations.
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| 2023 ANNUAL REPORT |
95
15.1 Decommissioning liabilities
Decommissioning liabilities are recognized for renewable facilities. A portion of Northland’s onshore wind and solar facilities
are located on lands leased from private and public landowners. Under the terms of the leases, upon expiration or
termination of leases, Northland is obligated to restore the leased lands to near to their original condition and remove all
wind turbines, solar panels and equipment. Northland’s obligations for decommissioning of its offshore wind facilities are
based on the government regulations in the applicable jurisdictions. No decommissioning liabilities are recognized for utility
and the efficient natural gas facilities until the time Northland determines that the facility will no longer be operated or
maintained and should be decommissioned.
As of December 31, 2023, the gross undiscounted total decommissioning liabilities aggregates to $656 million (2022 -
$489 million). Northland estimated the discounted value of its total decommissioning liabilities to be $429 million (2022 -
$373 million), based on an estimated total future liability. A long term discount rate of 2.2% to 4.1% (2022 - 0.5% to 3.9%)
and a long term inflation rate, where applicable, of 2.2% to 4.1% (2022 - 2% to 3.9%) was used to calculate the discounted
value of the decommissioning liabilities.
The following table reconciles the movements in Northland’s total decommissioning liabilities:
Year ended December 31,
Total, beginning of year
Additions (1)
Accretion
Exchange rates changes
Total, end of year
2023
372,747 $
46,139
7,131
3,148
429,165 $
2022
357,621
8,431
3,820
2,875
372,747
$
$
(1) Additions during the year, primarily reflects the periodic updates in the cost estimate for renewable facilities and annual revision in the inflation and
discount rates for all the facilities.
15.2 Pension and post-employment benefits
One of Northland’s facilities, EBSA, has a defined benefits pension plan (“pension plan”) which has been closed to new
members since 2010, and only a small portion of plan members remain active employees of EBSA. The pension plan
establishes the pension an employee will receive upon retirement based on factors such as employee age, years of service
and compensation levels when employed.
The accounting of pensions involves estimating the cost of the benefit that will be paid in a remote time horizon and
attributes this cost through the expected period in which each employee is expected to receive a pension in accordance
with the plan conditions; this requires the extensive use of estimates and assumptions on inflation, mortality, employee
turnover and discount rates, among other factors.
The liability recognized in the Consolidated statements of financial position, in respect of the defined benefits pensions, is
the present value of the defined benefit obligation at December 31, 2023, together with the adjustments of actuarial gains
or losses not recognized. The actuarial gains and losses are recorded against the net equity in Consolidated statements of
comprehensive income (loss), in the period they arise.
The present value of the defined benefit obligation is calculated by independent actuaries by discounting the estimated
cash outflows using the interest rates yield curve of the Public Debt Securities of the Government of Colombia adjusted for
inflation for terms approximating the remaining pension obligations.
The movement of the pension obligations balances, as included within provision and other liabilities in the Consolidated
statements of financial position, was as follows:
Year ended December 31,
Total, beginning of year
Interests net cost
Actuarial adjustments
Payments made directly by the Company
Foreign exchange
Total, end of year
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2023
$
22,565 $
2,297
6,474
(2,838)
6,156
$
34,654 $
2022
30,675
2,013
(4,764)
(2,731)
(2,628)
22,565
16. Equity
16.1 Common shares
Northland is authorized to issue an unlimited number of Shares. The changes in the Shares during 2023 and 2022 are
summarized as follows:
Shares outstanding, beginning of year
Shares issued under equity offering
Shares issued under the LTIP
Shares issued under the DRIP
Change in deferred taxes (1)
December 31, 2023
December 31, 2022
Shares
Amount
Shares
Amount
250,017,357 $
4,945,983
226,882,751 $
4,005,462
1,210,537
40,908
20,894,982
851,610
10,286
3,701,642
—
279
97,904
313
14,974
2,224,650
—
591
85,424
2,896
Total common shares outstanding, end of year
254,939,822 $
5,085,387
250,017,357 $
4,945,983
(1) Relates to difference in treatment between tax and IFRS.
Dividend Reinvestment Plan
The DRIP provides shareholders with the right to reinvest their dividends in Shares at a 3% discount to the market price as
defined in the DRIP. Shares issued under the DRIP can be sourced from treasury or purchased on the secondary market at
the election of Northland’s Board of Directors. Northland’s Board of Directors has the discretion to alter the discount or
source of Shares issued under DRIP.
Share-based Compensation
Northland’s share-based compensation plans provides for a maximum of 3,100,000 shares to be reserved and available for
grant to employees of Northland and its subsidiaries. As at December 31, 2023, 1,153,043 Shares remain available for
future issuance under the share-based compensation plans. Shares may be awarded based on development profits, which
arise from new projects or acquisitions. The costs recognized for Development LTIP in the period depend on management’s
best estimate of a project’s expected development profit and expected timing of project milestones.
For the year ended December 31, 2023, Northland expensed $2.8 million (2022 - $5.7 million), respectively of costs under
the share-based compensation plans. No forfeitures are assumed to occur. The balance of accrued awards related to the
Development LTIP is included in other payables and accrued liabilities since these awards are expected to be settled in cash.
For the year ended December 31, 2023, settlements under the compensation plans are summarized below, all of which
were settled in cash.
Deferred rights
Restricted share units
Development LTIP
Performance Share Units
Deferred Shares Units
Total
Year ended December 31,
$
2023
1,372 $
1,054
635
542
460
$
4,063 $
2022
1,377
1,680
2,029
992
789
6,867
Deferred Rights include amount of $0.3 million (2022 - $0.6 million), which were settled in Northland’s Shares, during the
year ended December 31, 2023, respectively.
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| 2023 ANNUAL REPORT |
97
16.2 Equity offering
On March 1, 2022, Northland established an at-the-market equity program (“ATM program”) that allowed Northland to
issue Shares upto an equivalent of $500 million from treasury, at Northland’s discretion. On September 7, 2022, Northland
renewed its ATM program to issue Shares upto an equivalent of additional $750 million from treasury, at the Company’s
discretion. The ATM program was renewed following the termination of the previous ATM program as a result of having
exercised the full allotment permitted under the program. Any common shares sold under the ATM program are sold
through the TSX.
During the year ended December 31, 2023, Northland issued 1,210,537 Shares, under the ATM program at an average price
of $34.43 per Share, for gross proceeds of $42 million (net proceeds $41 million).
Since the inception of the ATM program on March 1, 2022, Northland issued a total of 22,105,519 Shares at an average
price of $40.93 per Share for gross proceeds of $905 million (net proceeds $893 million). On July 16, 2023, the ATM
Program expired and therefore, has been terminated.
16.3 Preferred shares
As at December 31, 2023, Northland’s preferred shares balance contains Series 1 and Series 2 Preferred Shares.
Series 1 and 2 Preferred Shares
In 2010, Northland issued 6,000,000 Series 1 Preferred Shares at a price of $25.00 per share, for gross proceeds of $150
million. The annual dividend rate resets every five years at a rate equal to the then five-year Government of Canada bond
yield plus 2.80%. The holders of the Series 1 Preferred Shares are entitled to fixed cumulative dividends, payable quarterly,
as and when declared by the Board of Directors.
On August 31, 2020, Northland announced that the fixed quarterly dividends on the Series 1 Preferred Shares will be
payable at an annual rate of 3.2% ($0.2001 per share per quarter) until September 29, 2025.
Holders of Series 1 Shares had the right, at their option to convert all or part of their Series 1 Shares, on a one-for-one basis,
into shares of the other series. Accordingly, effective September 30, 2020, 1,237,754 Series 1 Preferred Shares were
converted in to equal number of Series 2 Preferred Shares.
The Series 2 Preferred Shares carry the same features as the Series 1 Preferred Shares, except that holders are entitled to
receive quarterly floating-rate cumulative dividends, as and when declared by the Board of Directors, at an annual rate
equal to the then three-month Government of Canada treasury bill yield plus 2.80% (2.80% as of December 31, 2022). The
holders of Series 2 Preferred Shares have the right to convert their shares into Series 1 Preferred Shares on September 30,
2025, and on September 30 of every fifth year thereafter.
As at December 31, 2023 there were 4,762,246 (2022 - 4,762,246) Series 1 Preferred Shares outstanding, representing
equity of $114 million (2022 - $114 million).
As at December 31, 2023 there were 1,237,754 (2022 - 1,237,754) Series 2 Preferred Shares outstanding, representing
equity of $31 million (2022 - $31 million).
Series 3 Preferred Shares
In 2012, Northland issued 4,800,000 Series 3 Preferred Shares at a price of $25.00 per share, for gross proceeds of $120
million, with annual dividend rate reset every five years at a rate equal to the then five-year Government of Canada Bond
yield plus 3.46%. The holders of the Series 3 Preferred Shares were entitled to fixed cumulative dividends, payable
quarterly, as and when declared by the Board of Directors. Series 3 Preferred Shares, provided the holders a right, at their
option, to convert these shares into Series 4 Preferred Shares on December 31, 2022, and on December 31 of every fifth
year thereafter, subject to certain conditions.
On November 25, 2022, Northland announced its intention to redeem all of its 4,800,000 issued and outstanding Series 3
Preferred Shares on January 3, 2023 (the “Redemption Date”) at a price of $25.00 per share together with all accrued and
unpaid dividends of $0.32 per share for an aggregate redemption value of $122 million (Note 9). Accordingly, during the
year ended December 31, 2023, all issued and outstanding Series 3 Preferred Shares were redeemed on the Redemption
Date.
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Preferred share dividends, excluding tax, were paid as follows:
Series 1
Series 2
Series 3
Total
16.4 Dividends
Dividends declared per share and in aggregate were as follows:
Dividends declared per Share
Aggregate dividends declared
Dividends in cash
Dividends in shares
Total
Year ended December 31,
2023
3,812 $
2,291
—
2022
3,811
1,299
6,096
6,103 $
11,206
Year ended December 31,
2023
1.20 $
2022
1.20
$
$
$
205,828
97,641
$
303,469 $
196,523
88,059
284,582
Dividends declared during the year include dividends amounting to $26 million, which remained unpaid as at December 31,
2023 (December 31, 2022 - $26 million).
17. Non-controlling interests
Non-controlling interests (NCI) relate to the interests not owned by Northland. Subsidiaries with non-controlling interests
that are material to Northland’s Consolidated Financial Statements include Gemini (40%), Nordsee One (15%) and GMS
Solar (37.5%). Summarized financial information for subsidiaries with material non-controlling interests in the Consolidated
statements of financial position (representing 100% ownership) is as follows:
As at December 31, 2023
Current assets (1)
Long-term assets
Current liabilities
Long-term liabilities
Gemini
Nordsee
GMS Solar
Other (2)
Total
As at December 31, 2022
Gemini
Nordsee
GMS Solar
Other (2)
Total
$
$
$
$
415,334 $
2,558,225 $
588,368 $
1,834,117
147,020
208,403
258,790
1,223,466
216,681
1,605,210
194,260
189,903
160,853
767,631
156,887
663,592
1,029,547 $
5,603,582 $
1,133,384 $
3,422,227
Current assets (1)
Long-term assets
Current liabilities
Long-term liabilities
492,971 $
2,772,390 $
550,943 $
2,050,265
181,466
187,257
173,486
1,254,491
235,972
1,261,110
176,012
169,789
95,759
921,553
165,338
634,940
1,035,180 $
5,523,963 $
992,503 $
3,772,096
(1) As at December 31, 2023, restricted cash of nil (December 31, 2022 - $1 million) is included for Gemini, $29 million (December 31, 2022 - $29 million)
for Nordsee where the availability of funds is intended for debt repayments.
(2) Other includes subsidiaries with NCI that are not individually material to Northland’s Consolidated Financial Statements, including: McLean’s (50%),
Grand Bend (50%), CEEC (61.6% ), EBSA (0.6%), Oneida (27.6% ), ScotWind Projects (24.5%) and Elecdey Lezuza, S.A under the Spanish portfolio
(33.8%).
| NORTHLAND POWER INC. |
| 2022 ANNUAL REPORT |
99
The change in material NCI during the year ended December 31, 2023, and 2022 is as follows:
Gemini
Nordsee (3)
GMS Solar
As at January 1, 2023
$
267,869 $
57,172 $
33,081 $
Other (2)
(25,031) $
Total
333,091
Increase in NCI arising on dilution of interest in
subsidiaries (a)
Net income (loss) attributable (1)
Dividends and distributions (1)
Allocation of other comprehensive income (loss) (1)
Disposal or other adjustments (4)
As at December 31, 2023
—
—
—
29,808
29,808
69,233
11,605
(106,737)
(10,856)
—
(842)
1,505
(4,250)
(1,434)
—
—
(10,128)
(3,281)
79,062
(8,956)
(119,943)
(589)
(622)
(13,721)
(10,750)
$
219,509 $
67,935 $
18,774 $
(8,671) $
297,547
As at January 1, 2022
$
149,464 $
32,988 $
30,225 $
(3,845) $
208,832
Gemini
Nordsee (3)
GMS Solar
Other
Total
Additional contribution by NCI
Net income (loss) attributable (1)
Dividends and distributions (1)
Allocation of other comprehensive income (loss) (1)
Disposal or other adjustments (4)
As at December 31, 2022
—
—
116,210
14,133
—
921
1,320
1,320
(3,540)
127,724
(71,441)
73,636
—
—
(3,113)
(19,248)
(93,802)
6,605
3,446
5,048
—
282
—
85,571
3,446
$
267,869 $
57,172 $
33,081 $
(25,031) $
333,091
(1) Net income (loss), dividends and distributions, and other comprehensive income (loss) are shown at the respective non-controlling interest share.
(2) Other includes subsidiaries with NCI that are not individually material to Northland’s Consolidated Financial Statements, including: McLean’s (50%),
Grand Bend (50%), CEEC (61.6% ), EBSA (0.6%), Oneida (27.6% ), ScotWind Projects (24.5%) and Elecdey Lezuza, S.A under the Spanish portfolio
(33.8%).
(3) As at January 1, 2022, Nordsee comprised of NCI balances relating to Nordsee One, Nordsee Two and Nordsee Three.
(4) Disposal of NCI relates to de-recognition of NCI interest of Energia in 2023 and Nordsee Two and Nordsee Three due to formation of Nordsee
Offshore Wind Cluster partnership in 2022.
(a) On May 9, 2023, Northland signed a partnership agreement with the ESB, a leading Irish utility company for a 24.5%
interest in the ScotWind Projects, while retaining 75.5% ownership. Based on management’s assessment, it is concluded
that Northland continues to retain the control over the ScotWind projects and thereby, will continue to consolidate the
assets and liabilities of the ScotWind Projects as per IFRS 10 – Consolidated Financial Statements. Additionally, as a result of
the introduction of a new shareholder and a decrease in Northland’s ownership interest below 100%, the fair value of the
net assets, amounting to $8 million, representing minority shareholders interest in the ScotWind Project was recognized as
NCI. The remaining increase in the NCI is represented by additional contributions by NCI shareholders in ScotWind and
Oneida Energy Storage Project during the year ended December 31, 2023.
18. Financial risk management
Northland’s risk management objective, as it relates to financial risks and uncertainties, is to mitigate fluctuations in cash
flows and ensure stable cash levels available to pay dividends to shareholders and fund growth. Northland does not seek to
mitigate fair value risk. Northland classifies financial risks into market risk, counterparty risk and liquidity risk, noting that
these risks can be impacted by geopolitical or regulatory uncertainties. Northland manages financial risks by identifying,
evaluating and mitigating in compliance with internal policies and external requirements under non-recourse project
financing arrangements. Northland uses derivative financial instruments to manage certain financial risks but does not
engage in speculative activity. Material financial risks are monitored and reported regularly to the Audit Committee of the
Board of Directors. The risks associated with Northland’s financial instruments and Northland’s policies for mitigating these
risks are described below.
100
| NORTHLAND POWER INC. |
| 2023 ANNUAL REPORT |
18.1 Market Risk
Market risk is the risk that the fair value of Northland’s future cash flows will fluctuate because of changes in market prices.
Financial instruments affected by market risk include loans and borrowings and derivative financial instruments as well as
Northland’s preferred shares and the Green Notes. Revenue and supply contracts can also be affected by market risk. Types
of market risk to which Northland is exposed are discussed below.
(i) Interest rate risk
Interest rate risk refers to the risk that the value of a financial instrument or cash flows associated with the instrument will
fluctuate due to changes in market interest rates. Northland manages this risk by securing fixed-rate debt or entering into
interest rate swap agreements prior to or around the time of financial close that effectively convert floating rate interest
exposures to a fixed rate. In certain jurisdictions, such as Taiwan, Northland is unable to secure interest rate swaps for the
full tenor of underlying debt; in those cases Northland intends to manage this risk with rolling hedge strategies.
Changes in the fair value of interest rate swap contracts designated for hedge accounting are recorded in Northland’s
consolidated statements of comprehensive income (loss) to the extent that the hedge arrangements are effective. The fair
values for these interest rate swap contracts are based on calculations and valuation models using observable market rates.
For the year ended December 31, 2023, if interest rates had been 100 basis points higher or lower with all other variables
held constant, income before income taxes from the change in fair value of the interest rate swaps prior to the application
of hedge accounting would have been $233 million higher or lower. This change would have had no impact on Northland’s
cash flows.
The counterparties to Northland’s interest rate derivative contracts are well-capitalized financial institutions with strong
credit ratings. See “Counterparty Risk” below.
(ii) Credit spread risk
Credit spread risk as it affects Northland refers to the risk that the loan margin charged by current or future lenders (a
borrower-specific margin added to the underlying interest rate) will increase, making the cost of debt capital more
expensive. Credit spread risk cannot be hedged. Northland manages this risk by: (i) entering into long-term financings with
defined credit spreads over the amortization period whenever possible; (ii) ensuring loans are fully amortized (repaid) by
maturity; and (iii) monitoring credit markets and making prudent decisions about the timing and method of original
financings, refinancing and repricing opportunities.
(iii) Currency risk
Currency risk arises because the Canadian dollar equivalent of transactions, assets or liabilities denominated in foreign
currencies may vary due to changes in foreign exchange rates. Northland is exposed to changes in the Euro, US dollar,
Colombian peso, Taiwan dollar, Polish Zloty, and to a lesser degree, other currencies on construction projects with expenses
in currencies different than the funding currency, or development expenses on early-stage projects in other jurisdictions.
Primary exposure to Northland arises from the Euro-denominated financial statements and cash distributions at Gemini,
Nordsee One, Deutsche Bucht, and the Spanish Portfolio, and Colombian peso-denominated financial statements and cash
distributions from EBSA, and development spending at the pipeline projects. Management manages this risk by hedging
material net foreign currency cash flows to the extent practical and economical to minimize material cash flow fluctuations.
Exchange rate gains and losses on the currency derivatives that have been recognized in OCI are recognized in net income in
the same period during which corresponding gains or losses arising from the translation of the Consolidated Financial
Statements of the self-sustaining foreign operation are recognized in net income.
At December 31, 2023, if the Canadian dollar had been 5% higher or lower against the U.S. dollar with all other variables
held constant, income before taxes from the change in fair value of the U.S. dollar foreign exchange contracts prior to the
application of hedge accounting would have been $2 million higher or lower. If the Canadian dollar had been 5% higher or
lower against the euro with all other variables held constant, income before taxes from the change in fair value of the euro
foreign exchange contracts prior to the application of hedge accounting would have been $96 million lower or higher. If the
Canadian dollar had been 5% higher or lower against the Colombian peso with all other variables held constant, income
before taxes from the change in fair value of the Colombian peso foreign exchange contracts (used to effectively hedge
equity distribution from EBSA) would have been $31 million lower or higher.
The counterparties to Northland’s currency derivative contracts are well-capitalized financial institutions with strong credit
ratings. See “Counterparty Risk” below.
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| 2023 ANNUAL REPORT |
101
(iv) Commodity price risk
Commodity price risk arises where: (i) PPA revenues or components of PPA revenues depend upon certain electricity
market indices; (ii) government subsidiary or feed-in-tariff programs define a floor price but electricity market prices may
exceed those floors; (iii) a portion of revenue is not contracted and subject to changes in electricity prices; (iv) PPA revenues
for efficient natural gas facilities are fixed, not linked to natural gas prices or the cost of natural gas is not substantively
passed through to the off-taker; (v) the value of a financial instrument or cash flows associated with the instrument
fluctuates due to changes in commodity prices; or (vi) the price of a component in a supply agreement is linked to the price
of one or several commodities.
Northland manages this risk by: (i) entering into PPAs that provide a fixed price for all, or substantially all, electricity
production, provide a price linked to commodity prices or include pass-through of commodity costs to the offtaker; (ii)
entering into financial power and natural gas hedges to stabilize contractual economics or protect against a specific risk,
including natural gas costs and electricity prices.
Northland has exposure to Dutch electricity market prices under Gemini’s PPA when the market price falls below the
contractual floor price. For the year ended December 31, 2023, the average wholesale market price was above the
contractual floor price, so the revenue was not impacted by this floor.
Northland has indirect exposure to German electricity market prices under the Nordsee One and Deutsche Bucht PPAs
whereby the facilities do not receive revenue for periods where the market power price remains negative for longer than
six consecutive hours.
Northland has exposure to Spanish electricity market prices under the Spanish Portfolio regulated asset base framework
where facilities earn their stated guaranteed pre-tax rate of return. For the year ended December 31, 2023, two wind assets
in the Spanish Portfolio have already earned their guaranteed pre-tax rate of return, so are directly exposed to Spanish
electricity market prices.
18.2 Financial Counterparty Risk
Counterparty risk is the risk that a counterparty fails to perform its contractual obligations which could result in losses in
financial assets. Northland is exposed to counterparty risk in several areas including: (i) cash and cash equivalents held with
banks and financial institutions; (ii) counterparty exposures arising from: (a) contractual obligations, which include but are
not limited to sales contracts, equipment supply, delivery, installation and maintenance contracts, fuel supply and fuel
transportation agreements, energy marketing contracts and construction contracts, (b) derivative financial instruments, (c)
trade receivables due from customers, (d) loan receivables due from partners and other entities, and (e) claims payable by
an insurer; and (iii) unfunded loan commitments from financial institutions for the construction of projects. The maximum
exposure to counterparty risk, other than for the loan commitments, is equal to the carrying value of the financial assets.
Northland manages counterparty risk by contracting with highly creditworthy counterparties wherever possible, such as
government-related entities and large financial institutions. Northland’s cash, derivative financial instruments, unfunded
loan commitments and insurance policies are contracted with creditworthy financial institutions. Northland’s gas,
transportation, equipment supply/ installation, maintenance and construction contracts are with highly rated and/or large,
well-capitalized counterparties wherever possible. Northland also manages counterparty risk by conducting comprehensive
initial credit analyses on potential counterparties to material and/or long-term contracts and monitoring counterparties
over time.
As at December 31, 2023, approximately 53.5% (2022 - 46.3%) of Northland’s consolidated trade receivables, excluding
third-party partner loan receivable, were receivable from creditworthy government-related entities.
In 2023, approximately 66.9% (2022 - 51.8%) of Northland’s consolidated sales were derived indirectly from the sale of
electricity to government-related entities. For electricity and other sales, Northland and its subsidiaries have not provided
allowance accounts and have not purchased credit derivatives to mitigate counterparty risk. All significant accounts
receivable amounts are current as at December 31, 2023.
The nature of Northland’s business and contractual arrangements, and the quality of its counterparties generally serve to
minimize counterparty risk.
102
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| 2023 ANNUAL REPORT |
18.3 Liquidity Risk
Liquidity risk is the risk that Northland: (i) may not have sufficient funds to settle a transaction on the due date; (ii) may be
forced to sell financial assets or terminate financial liabilities at a value that is not the fair market value; or (iii) may be
unable to settle or recover a financial asset at all. Liquidity risk arises through an excess of financial obligations over
available financial assets at any point in time.
Northland manages liquidity risk to maintain sufficient cash or readily available funding in order to meet expected liquidity
requirements. Northland achieves this by: (i) maintaining prudent cash balances, availability under committed credit
facilities and access to capital markets; (ii) implementing financing structures and derivatives or hedging strategies that
minimize the risk of material cash flow impacts; and (iii) actively monitoring open positions to assess and proactively adapt
to possible market liquidity concerns.
As at December 31, 2023, Northland and its subsidiaries were holding cash and cash equivalents of $642 million (2022 -
$1,300 million), including $65 million held corporately (2022 - $335 million), and had available borrowing capacity under the
syndicated revolving facility of $523 million.
The contractual maturities of Northland’s financial liabilities at December 31, 2023 are as follows:
Derivative contracts
Euro foreign exchange contracts
Colombian peso foreign exchange contracts
US dollar foreign exchange contracts
Taiwan dollar foreign exchange contracts
Interest-bearing loans and borrowings
2024
2025-2026
2027-2028
>2028
Total
$
480,969 $
278,425 $
575,524 $
1,161,213 $
2,496,131
634,290
652,901
—
—
114,401
—
9,112
—
7,111
—
214,897
296,689
634,290
783,525
511,586
Outstanding principal
738,522
2,394,048
1,272,830
2,350,255
6,755,655
Interest, including interest rate swaps
271,873
442,396
Corporate credit facilities, including interest
Green Subordinated Notes, including interest
Leases
Total
5,583
—
18,562
8,074
—
35,519
245,106
123,989
208,125
33,872
274,922
1,234,297
—
500,000
193,485
137,646
708,125
281,438
$
2,802,700 $
3,272,863 $
2,683,455 $
4,783,675 $ 13,542,693
Northland is also subject to internal liquidity risk because it conducts its business activities through separate legal entities
(subsidiaries and affiliates) and is dependent on cash distributions from those entities to fund development expenses,
defray corporate expenses and pay dividends. Most operating subsidiaries hold non-recourse debt. Such non-recourse
financing agreements typically prohibit distributions if the loan is in default (notably for non-payment of principal or
interest) or if the entity fails to achieve a benchmark debt service coverage ratio.
Northland will be required to refinance, renew or extend debt instruments as they become due. The ability to refinance,
renew or extend debt instruments is dependent on the capital markets up to the time of maturity and any credit ratings for
Northland at the relevant time, which may affect the availability, pricing or terms and conditions of replacement financing.
| NORTHLAND POWER INC. |
| 2023 ANNUAL REPORT |
103
19. Financial instruments
19.1 Financial instrument classification and fair value hierarchy
All financial instruments for which fair value is recognized or disclosed are categorized within the fair value hierarchy, based
on the lowest level input that is significant to the fair value measurement. The carrying values of financial instruments as at
December 31, 2023 and 2022, along with the respective fair value hierarchy are as follows:
As at December 31, 2023
Financial assets at amortized cost (1)
Financial assets at fair value through profit and loss
Financial assets at fair value through OCI
Financial liabilities at fair value through profit and loss
Financial liabilities at fair value through OCI
Financial liabilities at amortized cost (2)
Level 1
Level 2
Level 3 (3)
Total
$
813,501 $
1,031,248 $
— $
1,844,749
—
—
—
—
238,476
124,415
(118,379)
(9,516)
26,106
—
—
—
264,582
124,415
(118,379)
(9,516)
$
— $
(7,841,242) $
— $
(7,841,242)
As at December 31, 2022
Financial assets at amortized cost (1)
Financial assets at fair value through profit and loss
Financial assets at fair value through OCI
Financial liabilities at fair value through profit and loss
Level 1
Level 2
Level 3 (3)
Total
$
1,459,975 $
797,833 $
— $
2,257,808
—
—
—
462,180
275,256
(98,408)
14,539
—
—
476,719
275,256
(98,408)
Financial liabilities at fair value through OCI
Financial liabilities at amortized cost (2)
(1) Includes cash and cash equivalents, restricted cash, trade and other receivables, finance lease receivable, long-term deposits and certain other assets.
(8,069,772) $
(7,567)
(8,069,772)
(7,567)
— $
— $
—
—
$
(2) Includes trade and other payables, dividends payable, interest-bearing loans and borrowings, corporate credit facilities, and other liabilities (excluding
decommissioning liabilities and taxes payable).
(3) Represents embedded derivative relating to the energy price component linked to the market price in 20-year indexed Renewable Energy Certificate
(REC) agreement with the New York State Energy Research and Development Authority (NYSERDA) for the New York Wind projects.
The table below sets out the significant unobservable inputs used to value level 3 derivative financial instruments:
Derivative Financial
Instrument
Valuation
Technique
Embedded derivatives
Long-term price
forecast
Significant
unobservable
inputs
Average Illiquid
forward energy
prices (per MWh)
Range
% change
US$ 40.51 to
US$ 40.82
5% increase / (decrease)
in Average forward
energy prices
Sensitivity of input
to the fair value
(In CAD)
22,233
Additional details of Northland’s income and expenses with respect to its financial instruments are as follows:
Year ended December 31,
Income (expense) on financial assets at amortized cost
Expense (income) on financial liabilities at amortized cost
Expense (income) on net financial liabilities at fair value through profit and loss
2023
10,899 $
376,197
2022
11,794
332,810
303,898 $
(460,704)
$
$
104
| NORTHLAND POWER INC. |
| 2023 ANNUAL REPORT |
19.2 Derivative financial instruments
The derivative financial instruments consist of the following:
As at December 31, 2023
Current
assets
Current
liabilities
Long-term
assets
Long-term
liabilities
Total
Derivatives designated for hedge accounting
Interest rate contracts
Foreign exchange contracts
$
48,045 $
2,671
(1,222) $
(33)
39,687 $
34,012
(8,168) $
(93)
78,342
36,557
Derivatives not designated for hedge accounting
Interest rate contracts
Foreign exchange contracts
Cross currency interest rate contracts
Embedded derivatives (1)
69,275
13,241
4,117
2,362
139,711 $
(229)
(25,872)
—
—
116,292
35,551
—
23,744
249,286 $
(29,504)
(49,078)
(13,696)
—
155,834
(26,158)
(9,579)
26,106
261,102
Total
(1) Represents embedded derivative relating to the energy price component linked to the market price in 20-year indexed Renewable Energy Certificate
(100,539) $
(27,356) $
$
(REC) agreement with the New York State Energy Research and Development Authority (NYSERDA) for the New York Wind projects.
As at December 31, 2022
Current
assets
Current
liabilities
Long-term
assets
Long-term
liabilities
Total
Derivatives designated for hedge accounting
Interest rate contracts
Foreign exchange contracts
$
50,756 $
6,161
(950) $
—
128,773 $
89,566
(6,439) $
(178)
172,140
95,549
Derivatives not designated for hedge accounting
Interest rate contracts
Foreign exchange contracts
Cross currency interest rate contracts
Embedded derivatives (1)
61,609
58,015
69,537
2,751
(9,545)
(8,453)
(78,348)
—
230,534
42,485
—
11,788
(70)
(1,992)
—
—
282,528
90,055
(8,811)
14,539
Total
$
248,829 $
(97,296) $
503,146 $
(8,679) $
646,000
(1) Represents embedded derivative relating to the energy price component linked to the market price in 20-year indexed Renewable Energy Certificate
(REC) agreement with the New York State Energy Research and Development Authority (NYSERDA) for the New York Wind projects.
The change in derivative financial instruments for the year ended December 31, 2023 and 2022 is as follows:
Balance as at
Dec. 31, 2022
asset (liability)
Interest rate contracts
Foreign exchange contracts
$
Commodity contracts
Cross currency interest rate
contracts
Embedded derivatives
454,668 $
185,604
(8,811)
—
14,539
Changes in
fair value
recognized
in OCI (1)
(101,461) $
(62,743)
—
—
—
Designated in hedge
relationships
Fair value changes
on derivatives not
designated in
hedge
relationships (2)
Foreign
exchange
gain (loss)
Balance as at
Dec 31, 2023
asset (liability)
Fair value
changes (2)
11,915 $
3,753
—
—
—
(126,694) $
(116,349)
(4,252) $
134
8,979
(168)
(9,578)
11,567
(1)
—
234,176
10,399
—
(9,579)
26,106
Total
$
646,000 $
(164,204) $
15,668 $
(232,075) $
(4,287) $
261,102
(1) Amounts recognized in “Change in fair value of hedged derivative contracts” in the Consolidated statements of comprehensive income (loss),
representing the change in fair value recognized in OCI, net of amounts reclassified to the Consolidated statements of income (loss) on settlement.
(2) Amounts recognized in “Fair value (gain) loss on financial instruments” in the Consolidated statements of income (loss). These amounts represent fair
value changes, net of realized gains and losses on settlements during the year ended December 31, 2023. Realized gains and losses are recorded in
“Finance costs, net” for interest rate contracts and “Foreign exchange (gain) loss” for foreign exchange contracts”.
(3) Derivative contracts include cash and accrued payments amounting to $18 million and realized fair value loss amounting to $109 million, relating to
the contracts that were settled / terminated during the year ended December 31, 2023.
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| 2023 ANNUAL REPORT |
105
Balance as at
Dec. 31, 2021
asset (liability)
Interest rate contracts
$
(323,571) $
Changes in
fair value
recognized
in OCI (1)
378,218 $
Fair value changes
on derivatives not
designated in
hedge
relationships (2)
Foreign
exchange
gain (loss)
Balance as at
Dec. 31, 2022
asset
(liability)
Fair value
changes (2)
29,901 $
359,710 $
10,410 $
Designated in hedge
relationships
Foreign exchange contracts
130,139
47,484
(2,297)
Commodity contracts
Embedded derivatives
Total
(22,186)
—
—
—
—
—
$
(215,618) $
425,702 $
27,604 $
10,278
13,208
14,539
397,735 $
—
167
—
10,577 $
454,668
185,604
(8,811)
14,539
646,000
(1) Amounts recognized in “Change in fair value of hedged derivative contracts” in the Consolidated statements of comprehensive income (loss),
representing the change in fair value recognized in OCI, net of amounts reclassified to the Consolidated statements of income (loss) on settlement.
(2) Amounts recognized in “Fair value (gain) loss on financial instruments” in the Consolidated statements of income (loss). These amounts represent fair
value changes, net of realized gains and losses on settlements during the Year ended December 31, 2022. Realized gains and losses are recorded in
“Finance costs, net” for interest rate contracts, “Foreign exchange (gain) loss” for foreign exchange contracts” and “Fair value (gain) loss on financial
instruments” for power forward contracts.
(3) Derivative contracts include cash received amounting to $18 million and realized fair value gain amounting to $54 million, relating to the contracts
that were settled / terminated during the year ended December 31, 2022.
(a) Foreign exchange forward contracts, designated for hedge accounting
Carrying amount (asset/(liability))
Notional amount - EUR
Notional amount - COP
Maturity date
Hedge ratio (1)
Change in discounted spot value of outstanding hedging
instruments since January 1
Change in value of hedged item used to determine hedge
effectiveness
Weighted average hedged rate for the year (including
forward points):
EUR foreign exchange forward contracts
COP foreign exchange forward contracts
$
$
$
December 31, 2023
36,557 $
327,286
—
December 31, 2022
95,549
707,287
5,060,402,566
January 2024 - August 2032
December 2023 - August 2032
1:1
(6,145) $
(652) $
1:1
(2,617)
(1,153)
€0.6080:CAD$1
—
€0.6112:CAD$1
COP$2,874:CAD$1
(1) The foreign exchange forward contracts are denominated in the same currency as the highly probable future payments (US$) and the net investment
in foreign operations; therefore, the hedge ratio is 1:1.
106
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| 2023 ANNUAL REPORT |
Foreign exchange hedge reserve
Euro contracts
Colombian Peso
contracts
Cost of
hedging
Forward
component
Cost of
hedging
Forward
component
Total foreign
exchange
hedge
reserve in AOCI
Total, beginning of the year 2022
Add: Costs of hedging deferred during the year in OCI
$
(8,690) $
64,122
9,429 $
—
(1,188) $
610
4,222 $
—
Add: Change in fair value of hedging instrument
recognized in OCI for the year (effective portion)(1)
Less: Re-classified to the Consolidated statements of
income (loss)
Less: Deferred Tax
Total, end of the year 2022
Add: Costs of hedging deferred during the year in OCI
—
(5,336)
—
(2,997)
(17,186)
—
(169)
—
—
$
38,246 $
(56,266)
2,301
6,394 $
—
—
(747) $
189
6,139
7,364 $
—
3,773
64,732
(8,333)
(17,355)
8,440
51,257
(56,077)
Add: Change in fair value of hedging instrument
recognized in OCI for the year (effective portion)(1)
Less: Re-classified to the Consolidated statements of
income (loss)
Less: Deferred Tax
Total, end of the year 2023
(1) The deferred tax recovery amounting to $24 million (2022 - $12 million), applicable to the foreign exchange hedge reserve has been recognized in
1,050
11,560 $
2,378
8,517 $
—
(572) $
(30,992) $
(12,972)
(1,225)
4,116
(14)
—
—
—
—
—
$
(12,986)
3,428
(11,487)
2,891
OCI.
The hedge ineffectiveness recognized in “fair value (gain) loss on financial instruments” in the Consolidated statements of
income (loss) related to foreign currency contracts (cash flow and net investment hedges) for the year ended December 31,
2023, was $26.2 million (2022 - $1.9 million).
(b) Interest rate swaps, designated for hedge accounting
Carrying amount (asset/(liability))
Notional amount - CAD
Notional amount - EUR
Notional amount - COP
Maturity date
Hedge ratio (1)
Change in fair value of outstanding hedging instruments since
January 1
Change in value of hedged item used to determine hedge
effectiveness
$
$
$
December 31, 2023
78,342 $
355,801
1,766,261
—
January 2024 - March 2035
1:1
December 31, 2022
172,140
382,776
1,917,273
29,272,480
April 2023 - March 2035
1:1
(109,949) $
169,003 $
415,317
(433,924)
(1) The interest rate swaps mirror the interest rate of the debts; therefore, the hedge ratio is 1:1.
Interest rate hedge reserve
Canadian Dollar
interest rate
swaps
(9,640) $
Euro interest
rate swaps
Total interest rate
hedge reserve
$
Total, beginning of the year 2022
Add: Change in fair value of hedging instrument recognized in OCI for
the year (effective portion)(1)
Less: Re-classified to the Consolidated statements of income (loss)
Total, end of the year 2022
Add: Change in fair value of hedging instrument recognized in OCI for
the year (effective portion)(1)
Less: Re-classified to the Consolidated statements of income (loss)
Total, end of the year 2023
(1) The deferred tax recovery amounting to $16 million (2022 - $86 million), applicable to the interest rate hedge reserve has been recognized in OCI.
(1,459)
156,595 $
(3,468)
61,907 $
—
9,631 $
(195,474) $
353,528
16,927 $
(91,220)
26,566
(7,296)
1
$
$
380,094
(1,458)
173,522
(98,516)
(3,468)
71,538
(205,114)
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| 2023 ANNUAL REPORT |
107
The hedge ineffectiveness recognized in “fair value (gain) loss on financial instruments” in the Consolidated statements of
income (loss) related to interest rate contracts (cash flow hedges) for the year ended December 31, 2023 was $1 million
(2022 - $4 million).
(d) Hedge ineffectiveness
The fair value of the hedged item used as the basis for recognizing hedge ineffectiveness for the year, by risk category, are:
Fair value of hedged items (hypothetical derivatives)
Cash flow hedge – interest rate risk
Net investment hedge – foreign currency risk
20. Net income (loss) per share
The basic and diluted net income (loss) is calculated as follows:
Net income (loss) during the year attributable to the shareholders
Less: preferred share dividends, net (Note 16.3)
Net income (loss) attributable to common shareholders for basic and diluted earnings
December 31,
2023
(38,059) $
5,448 $
December 31,
2022
(207,062)
6,100
$
$
Year ended December 31,
2022
827,733
2023
(175,194) $
(6,103)
(181,297) $
(11,206)
816,527
$
$
Weighted average number of shares outstanding for the basic and diluted earnings per share are as follows:
Weighted average number of shares outstanding, basic and diluted
21. Finance costs (income), net
Net finance costs consist of the following:
Interest on debt, borrowings and bank fees
Amortization of deferred financing costs
Accretion of decommissioning liabilities (Note 15.1)
Lease interest (Note 7.2)
Finance costs, gross
Less: Finance income
Finance costs, net
Year ended December 31,
2022
236,156,878
2023
252,710,386
Year ended December 31,
2023
$
339,101 $
33,023
7,131
4,073
383,328 $
(61,516)
321,812 $
$
$
2022
305,111
24,317
3,820
3,382
336,630
(13,521)
323,109
For the year ended December 31, 2023, $13.5 million of finance costs (2022 - $5.5 million), were incurred from project
financing related to facilities under construction were capitalized in construction-in-progress.
108
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| 2023 ANNUAL REPORT |
22. Impairment of non-financial assets
Northland's impairment tests are performed either at the facility level, which represents a CGU, or at a group of CGUs for
which goodwill is allocated and monitored. PP&E, intangible assets and goodwill have been allocated to CGUs to determine
the carrying amount.
The calculation of value-in-use is most sensitive to the following assumptions:
•
•
Growth rate - 3.03% - 7.37% (2022 - 3.10% - 5.57%) is used to extrapolate CGU cash flow projections in the discounted
cash flow approach. The rate is based on readily available published industry research. The rate was further adjusted
to reflect inflation rate of overseas jurisdictions where applicable.
Discount rate - Pre-tax discount rates reflect the current market assessment of the risks specific to each CGU. The
discount rate was estimated based on the weighted average cost of capital for the industry. The rate was further
adjusted to reflect the market assessment of any risk specific to the CGU for which future estimates of cash flows have
not been adjusted. The discount rates were further adjusted to reflect country specific risks for the overseas
jurisdictions where applicable. The rates are as follows:
Pre-tax discount rates
Applicable to PPA cash flows:
Applicable to other cash flows (1):
(1) Other cash flows include post-PPA cash flows and utility cash flows.
October 1, 2023
6.0% - 9.3%
6.0% - 11.3%
October 1, 2022
6.0% - 8.7%
6.0% - 10.7%
Northland completed its annual comprehensive impairment assessment based on value-in-use estimates which are derived
from the long-range forecasts and market values observed in the marketplace or FVLCS. Except for goodwill relating to the
Spanish portfolio, which is discussed below, Northland did not identify any impairments of goodwill or reversals of prior
impairments as a result of this review.
Spanish Portfolio
During the year, a new Royal Decree-Law ("RDL") was enacted, introducing certain regulatory framework changes, that
resulted in the deferral of cash flows to beyond 2025. Consequently, upon completing the required annual impairment test,
the recoverable amount of the Spanish Portfolio decreased, prompting management to recognize an impairment charge of
$163 million, representing all of the goodwill related to the Spanish Portfolio.
23. Income taxes
23.1 Tax expense and temporary difference
The following table summarizes the tax expense reported in the Consolidated statements of income (loss):
Year ended December 31,
Current taxes
Based on taxable income of current year
Tax on dividend payments
Total current taxation expense
Deferred taxes
Deferred tax on origination and reversal of temporary differences
Deferred tax due to changes in tax rates
Prior-year under (over) provision
Total deferred tax expense (recovery)
Total income tax expense (recovery)
2023
2022
141,113 $
2,441
143,554 $
198,894
4,482
203,376
(108,064) $
2,245
1,394
(104,425) $
39,129 $
99,288
270
1,728
101,286
304,662
$
$
$
$
$
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| 2023 ANNUAL REPORT |
109
The following table summarizes the tax expense reported directly in equity:
Year ended December 31,
Deferred taxes related to change in fair value of hedged derivative contracts
Deferred taxes related to pension expense
Deferred taxes related to foreign exchange
Total income tax expense (recovery) in OCI
Deferred taxes related to origination and reversal of temporary differences related to
issuance of shares (Note 16.1)
Total income tax expense (recovery) in equity
The following table summarizes the reconciliation of Northland’s effective tax rate:
Year ended December 31,
Income (loss) before income taxes
Combined basic Canadian federal and provincial income tax rate
Income tax expense (recovery) based on statutory rate
Items giving rise to differences between accounting and tax expense
Minority interest
Benefit not recognized
Manufacturing and processing rate reduction
Deferred tax expense (recovery) relating to changes in tax rates or change in legal
structure
Tax expense associated with payment of preferred share dividends
Rate difference related to temporary differences in foreign jurisdictions
Adjustment for non-deductible (taxable) expenses and incentives
Other
Total income tax expense (recovery)
2023
(39,875) $
(1,788)
21,950
(19,713) $
(313)
2022
97,314
1,523
(393)
98,444
(2,896)
(20,026) $
95,548
$
$
$
2023
2022
$
(57,003)
$
1,260,119
26.5 %
26.5 %
(15,106)
333,933
(18,071)
(12,750)
555
2,245
2,441
13,227
62,502
4,086
39,129
$
(30,970)
12,151
(2,717)
270
4,482
8,885
(27,322)
5,950
304,662
$
Northland, while resident in Canada, operates in a number of foreign jurisdictions. The enacted blended tax rates relevant
to the computation of tax expense (recovery) are: Canada 26.5% (2022 - 26.5%), Germany 30.1% (2022 - 30.1%),
Netherlands 25.8% (2022 - 25.8%), Luxembourg 24.9% (2022 - 24.9%), Mexico 30.0% (2022 - 30.0%), Colombia 35.0% (2022
- 35.0%), United States 26.1% (2022 - 26.1%), and Spain 25.0% (2022 - 25.0%).
The following table summarizes the components of the net deferred tax asset and liability:
As at December 31,
Deductible (taxable) temporary differences
Property, plant and equipment
Contracts
Derivative financial instruments
Fair value debt increments
Tax credits
Canadian renewable conservation expense
Financing fees
Losses available for carryforward
Interest available for carryforward
Other
Total (net) deferred tax asset (liability)
110
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| 2023 ANNUAL REPORT |
2023
2022
$
(580,402) $
(98,595)
(41,059)
(1,376)
2,359
6,052
20,064
53,706
84,825
8,893
(545,533) $
$
(525,057)
(121,172)
(121,616)
1,362
5
5,973
24,020
18,447
42,778
4,924
(670,336)
The following table reconciles the opening and ending balance of Northland’s net deferred tax liability:
As at December 31,
Opening balance, net deferred tax liability
Tax expense (recovery) recognized in income statement
Tax expense (recovery) in OCI
Effect of foreign exchange recognized in OCI
Tax expense (recovery) recognized in equity
Deferred tax asset disposed on sale
Other
Ending net, deferred tax liability
2023
670,337 $
(104,425)
(41,663)
21,950
(313)
—
(353)
545,533 $
$
$
The following temporary differences have not been recognized in Northland’s Consolidated Financial Statements:
2022
470,015
101,286
98,837
(393)
(2,896)
3,488
—
670,337
2022
91,313
106,828
80,461
174,734
3,846
2023
$
113,471 $
188,702
3,018
—
3,386
$
308,577 $
457,182
Year ended December 31,
Non-capital losses carried forward
Net capital loss
Fair value change in debt instrument
Non-deductible interest carried forward
Other deductible temporary differences
Total deductible temporary differences
Northland has operating losses available for carry forward in Canada, Mexico, Spain, United Kingdom and Korea which are
expected to expire beginning in 2026 as follows:
2025 – 2028
2029 – 2033
2034 – 2038
2039 – 2043
Total
Canada
UK
Korea
Mexico
Spain
$
$
— $
202
2,604
14,316
17,122 $
— $
—
—
35,398
35,398 $
— $
—
27,958
2,527 $
148,451
—
—
27,958 $
150,978 $
—
—
—
63,614
63,614
23.2 Temporary differences associated with Northland investments
The temporary difference associated with investments in Northland’s subsidiaries is $275 million (2022 - $256 million). A
deferred tax liability associated with these investments has not been recognized because Northland controls the timing of
the reversal and it is probable that the temporary difference will not reverse in the foreseeable future.
Northland periodically assesses its liabilities and contingencies for all tax years open to audit based upon the latest
information available. For those matters where it is probable that an adjustment will be made, Northland has recorded its
best estimate of these liabilities, including related interest charges. Inherent uncertainties exist in estimates of tax
contingencies due to implementation of changes in tax laws. Although Northland believes it has adequately provided for
the probable outcome of these matters, future results may include adjustments to these estimated tax liabilities in the
period the assessments are made or resolved or when the statute of limitation lapses. The final outcome of tax
examinations may result in a materially different outcome than assumed in the tax liabilities.
23.3 International tax reforms – Introduction of Pillar Two model rules
As of December 31, 2023, Pillar Two legislation has been enacted or substantively enacted in jurisdictions where Northland
operates. In compliance with recent IAS 12 amendments, management has assessed Northland’s potential exposure to
Pillar Two model rules. Management’s assessment is based on the available information relating to Northland’s current and
prior year’s financial performance. However, it is not necessarily predictive of future circumstances and does not serve as a
forecast of future profits. The effective tax rates under Pillar Two in all relevant jurisdictions exceed 15%, and management
is unaware of any circumstances likely to change this. Consequently, based on the assessment, management does not
anticipate additional tax exposure under the Pillar Two model rule.
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| 2023 ANNUAL REPORT |
111
24. Operating segment information
Northland has identified operating segments as outlined below based on the nature of operations, asset class and materiality. Northland analyzes the performance of
its operating segments based on their operating income, which is defined as sales less operating expenses.
Significant information for each segment for the Consolidated statements of income (loss) is as follows:
Year ended December 31,
2023
External
sales
Inter company
sales (1)
Total sales
Cost of
sales
Operating
costs
G&A costs (2)
Depreciation
and
amortization
Other
income (3)
Operating
income
Finance
costs, net
Offshore wind facilities
$ 1,140,015 $
— $ 1,140,015 $
— $ 201,187 $
14,081 $
384,010 $
— $ 540,737 $ 131,116
Onshore renewable facilities
North America(4)
Spain
Efficient natural gas facilities
Canada
Utilities
Colombia
Other (1) (4)
Elimination
Total
217,938
216,963
—
—
217,938
216,963
—
—
33,331
50,830
1,818
872
91,239
85,875
—
91,550
(375)
79,761
53,756
19,480
$ 434,901 $
— $ 434,901 $
— $
84,161 $
2,690 $
177,114 $
(375) $ 171,311 $
73,236
339,848
—
339,848
105,299
49,943
406
46,625
(10,899)
148,474
46,312
302,241
—
302,241
106,439
70,013
8,638
29,144
—
88,007
(794)
15,774
97,942
113,716
—
(97,942)
(97,942)
—
—
3,518
203,531
15,722
375
(109,430)
71,942
—
—
—
—
(97,942)
—
$ 2,232,779 $
— $ 2,232,779 $ 211,738 $ 408,822 $
229,346 $
652,615 $
(10,899) $ 741,157 $ 321,812
(1) Other external sales include energy marketing activities. Other inter-segment sales include inter-company management fees, energy marketing activities and maintenance services, which are eliminated on
consolidation.
(2) General and administrative costs include development costs.
(3) Other income includes finance lease income.
(4) North American geographical segment excludes the Mexican La Lucha Solar Project. Northland monitors the financial performance of the La Lucha separately for its financial and operating decision-making
accordingly, the operating results of the La Lucha Project is currently included in Others.
112
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| 2023 ANNUAL REPORT |
Year ended December 31,
2022
External
sales
Inter company
sales (1)
Total sales
Cost of
sales
Operating
costs
G&A costs
(2)
Depreciation
and
amortization
Other
income (3)
Operating
income
Finance
costs, net
Offshore wind facilities
$ 1,259,247 $
— $ 1,259,247 $
— $ 169,756 $
11,862 $
374,150 $
— $ 703,479 $ 173,150
Onshore renewable facilities
North America(4)
Spain
Efficient natural gas facilities
Canada
Utilities
Colombia
Other (1) (4)
Elimination
Total
216,495
269,251
—
—
216,495
269,251
—
—
31,013
42,832
840
4,635
83,900
78,076
—
—
100,742
143,708
50,359
20,534
$ 485,746 $
— $ 485,746 $
— $
73,845 $
5,475 $
161,976 $
— $ 244,450 $
70,893
425,572
—
425,572
177,316
43,215
501
46,532
(11,271)
169,279
47,173
269,692
—
269,692
83,659
64,785
6,119
29,976
8,558
127,708
136,266
9,451
394
138,223
12,067
—
—
85,153
(124)
(23,869)
32,017
—
(127,708)
(127,708)
—
—
—
—
—
(127,708)
—
$ 2,448,815 $
— $ 2,448,815 $ 270,426 $ 351,995 $ 162,180 $
624,701 $
(11,271) $ 1,050,784 $ 323,109
(1) Other external sales include energy marketing activities. Other inter-segment sales include inter-company management fees, energy marketing activities and maintenance services, which are eliminated on
consolidation.
(2) General and administrative costs include development costs.
(3) Other income includes finance lease income.
(4) North American geographical segment excludes the Mexican La Lucha Solar Project. Northland monitors the financial performance of the La Lucha separately for its financial and operating decision-making
accordingly, the operating results of the La Lucha Project is currently included in Others.
| NORTHLAND POWER INC. |
| 2023 ANNUAL REPORT |
113
Significant information for each segment for the Consolidated statements of financial position is as follows:
As at December 31, 2023
PP&E, net
Contracts and
other intangibles,
net (1)
Goodwill
Investment in
joint ventures
Total assets
Offshore wind facilities
$
4,637,980 $
322,852 $
— $
— $
5,497,680
Onshore renewable facilities
North America(2)
Spain
Efficient natural gas facilities
Canada
Utilities
Colombia
Other(1) (2)
Total
1,392,555
1,406,339
6,506
—
54,741
—
—
—
1,704,882
1,628,503
$
2,798,894 $
6,506 $
54,741 $
— $
3,333,385
700,454
35,803
120,229
—
1,142,259
550,434
492,171
6,694
464,377
—
1,171,011
75,015
—
899,885
2,481,963
$
9,179,933 $
446,870 $
639,347 $
899,885 $ 13,626,298
(1) Other includes $28 million in relation to an Option Lease Agreement, entered with the Scottish government which provides Northland with
development exclusivity over the awarded sites for a period of up to 10 years.
(2) North American geographical segment excludes the Mexican La Lucha Solar Project. Northland monitors the financial performance of the La Lucha
separately for its financial and operating decision-making accordingly, the operating results of the La Lucha Project is currently included in Others.
As at December 31, 2022
PP&E, net
Contracts and
other intangibles,
net (1)
Goodwill
Investment in
joint ventures
Total assets
Offshore wind facilities
$
4,899,741 $
367,412 $
— $
— $
6,381,260
Onshore renewable facilities
North America
Spain
Efficient natural gas facilities
Canada
Utilities
Colombia
Other
Total
1,151,725
1,448,339
—
—
54,741
158,825
—
—
1,108,590
1,974,257
$
2,600,064 $
— $
213,566 $
— $
3,082,847
728,730
41,411
120,229
—
1,174,181
431,144
717,905
5,800
378,823
—
936,634
1,004,008
101,152
—
441,565
2,647,687
$
9,377,584 $
515,775 $
712,618 $
441,565 $ 14,222,609
(1) Other includes $33 million in relation to an Option Lease Agreement, entered with the Scottish government which provides Northland with
development exclusivity over the awarded sites for a period of up to 10 years.
114
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Geographical Information
Northland has operations in multiple geographic locations across the world. The following table presents consolidated sales
and property plant, and equipment spread across various significant geographic locations:
Sales
Netherlands
Germany
Canada
Spain
Colombia
Others
Total
Property, plant and equipment, net
As at
Netherlands
Germany
Canada
Spain
United States
Colombia
Others
Total
Year ended December 31,
2023
589,128 $
550,887
548,428
218,411
302,241
23,684
2,232,779 $
2022
645,743
613,504
642,178
269,651
269,692
8,047
2,448,815
$
$
December 31, 2023 December 31, 2022
$
$
2,419,327 $
2,218,653
1,750,106
1,406,339
538,465
567,807
279,236
9,179,933 $
2,615,028
2,284,713
1,687,973
1,448,339
653,124
445,465
242,942
9,377,584
25. Related-party disclosures
25.1 Compensation of key management personnel
Remuneration of key management personnel, consisting of the Board of Directors and members of executive management,
expensed in the year ended December 31, 2023, and 2022 is outlined in the table below. In 2023, Northland granted Shares
to key management personnel to settle a part of share-based compensation. Share-based compensation is tied directly to
executive seniority and the success of development and construction projects as well as acquisition activities.
Year ended December 31,
Salaries and short-term employee benefits
Share-based compensation - shares issued under the LTIP (Note 16.1)
Share-based compensation - cash component
Total
2023
11,437 $
279
3,654
2022
9,643
591
4,382
15,370 $
14,616
$
$
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| 2023 ANNUAL REPORT |
115
25.2 Transactions with joint ventures
Summarized below are the material transactions and balances with the joint ventures as at and for the year ended
December 31, 2023:
As at
Loan receivable from joint ventures (Note 10.1)
Loan payable to joint ventures (Note 11)
Year ended December 31,
Cost recharges to joint ventures (Note 8)
Interest income from joint ventures (Note 10.1)
December 31, 2023
December 31, 2022
$
$
405,368 $
14,999
2023
36,472 $
9,600
—
—
2022
23,739
—
26. Litigation, claims, contingencies and commitments
Litigation, claims and other contingencies arise from time to time in the ordinary course of business for Northland. None of
these contingencies, individually or in aggregate, are expected to result in a liability that would have a material adverse
effect on Northland.
26.1 Milestone payments for development project acquisitions
In the course of business, Northland enters into acquisition agreements that may result in Northland making additional
payments to the seller and/or directly to the development project previously acquired, upon the successful completion of
certain milestones. As at December 31, 2023, Northland’s best estimate of the future contingent payments is approximately
$142 million of milestone payments under its development project arrangements. These contingent payments were not
recognized in the Consolidated statements of financial position.
26.2 Contingencies and commitments
The following is a summary of the material commitments that Northland and its subsidiaries have entered into as at
December 31, 2023, in addition to the commitments outlined in the above notes.
The majority of Northland’s revenues are earned under long-term PPAs with government-related entities. In certain
circumstances, if a facility fails to meet the performance requirements under its respective PPA, penalties may apply, or the
contract may be terminated after a specified period of time.
Certain Northland gas facilities and corporate subsidiaries have entered into agreements for the purchase of natural gas and
natural gas transportation for various terms. Certain contracts include penalties for failure to purchase a minimum annual
volume of natural gas or, in the case of transportation agreements, include substantial demand charges incurred whether
or not gas is shipped.
Northland’s natural gas turbines and wind turbines are maintained under long-term contracts with the original equipment
suppliers. In certain circumstances, if Northland were to terminate any of the agreements, the termination payment would
be material.
Under certain circumstances, Northland provides parental guarantees to third-parties in respect of its subsidiaries. As at
December 31, 2023, outstanding parental guarantees issued totaled $334 million (2022: $229 million) and related primarily
to the development and construction of Oneida and New York Wind projects.
Northland’s share of contingencies and commitments in relation to its joint ventures are disclosed in (Note 8 (d)).
26.3 Capital commitments
In the normal course of operations, as at December 31, 2023, Northland has committed to future spending of
approximately $507 million (2022: $69 million) on capital projects, primarily relating to the construction of Oneida Storage,
and Thorold expansion projects in Canada and other routine capital maintenance work on certain operational projects in
Canada, USA and Colombia.
116
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Corporate Information
Directors and Executive Officers Of
Northland Power Inc.
Directors
Mr. John W. Brace (Chair)
Ms. Linda L. Bertoldi
Ms. Lisa Colnett
Mr. Kevin Glass
Mr. Russell Goodman
Mr. Keith Halbert
Ms. Helen Mallovy Hicks
Mr. Ian Pearce
Mr. Eckhardt Ruemmler
Ms. Ellen Smith
Executive Officers
Mr. Mike Crawley
President and Chief Executive Officer
Ms. Pauline Alimchandani
Chief Financial Officer
Ms. Rachel Stephenson
Chief People Officer
Mr. Yonni Fushman
Chief Administrative & Legal Officer and
Corporate Secretary
Mr. Calvin MacCormack
Executive Vice President,
Efficient Natural Gas & Utilities
Ms. Michelle Chislett
Executive Vice President, Onshore Renewables
Mr. Pierre-Emmanuel Frot
Executive Vice President,
Project Management Office
General Information
Registrar and Transfer Agent
Computershare Trust Company of Canada
100 University Avenue
Toronto, Ontario, Canada
M5J 2Y1
Attention: Equity Services
Common Shares and
Preferred Shares
Northland’s common shares and Series 1 and Series
2 preferred shares are listed on the Toronto Stock
Exchange and trade under the symbols NPI, NPI.PR.A
and NPI.PR.B respectively.
Tax Considerations
Northland’s common shares, preferred shares and
convertible unsecured subordinated debentures are
qualified investments for RRSPs and DPSPs under the
Income Tax Act (Canada).
Contact Information
Investor Relations
Adam Beaumont
Vice President
Dario Neimarlija
Vice President
investorrelations@northlandpower.com
647-288-1019
Northland Power Inc.
30 St. Clair Avenue West
3rd floor
Toronto, Ontario, Canada
M4V 3A1
416-962-6262
northlandpower.com
Northland Power Annual Report | 2023
117
.
Global Head Office
30 St. Clair Avenue West
3rd Floor,
Toronto (Ontario) Canada
M4V 3A1
northlandpower.com
investorrelations@northlandpower.com