Vermilion Energy
Annual Report 2023

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2023 A N N UA L R E P O R T EXCELLENCE. TRUST. RESPECT. RESPONSIBILITY.INTERNATIONALLY DIVERSIFIED | FREE CASH FLOW FOCUSED Table of Contents Message to Shareholders Management’s Discussion and Analysis Consolidated Financial Statements Notes to the Consolidated Financial Statements Corporate Information Annual General Meeting May 1, 2024 3:00 PM MT McMurray Room Calgary Petroleum Club 319 5th Avenue S.W. Calgary, Alberta 8 15 68 78 103 Details of the meeting will be included in the Information Circular, which will be available in March 2024, and will be posted on our website at https://www.vermilionenergy.com/invest-with-us/annual-general-meeting when available. Vermilion Energy Inc. ■ Page 1 ■ 2023 Annual Report Disclaimer Certain statements included or incorporated by reference in this document may constitute forward-looking statements or information under applicable securities legislation. Such forward-looking statements or information typically contain statements with words such as "anticipate", "believe", "expect", "plan", "intend", "estimate", "propose", or similar words suggesting future outcomes or statements regarding an outlook. Forward looking statements or information in this document may include, but are not limited to: capital expenditures and Vermilion’s ability to fund such expenditures; Vermilion’s additional debt capacity providing it with additional working capital; statements regarding the return of capital, the flexibility of Vermilion’s capital program and operations; business strategies and objectives; operational and financial performance; estimated volumes of reserves and resources; petroleum and natural gas sales; future production levels and the timing thereof, including Vermilion’s 2024 guidance, and rates of average annual production growth; the effect of changes in crude oil and natural gas prices, changes in exchange and inflation rates; significant declines in production or sales volumes due to unforeseen circumstances; the effect of possible changes in critical accounting estimates; statements regarding the growth and size of Vermilion’s future project inventory wells expected to be drilled in 2024; exploration and development plans and the timing thereof; Vermilion’s ability to reduce its debt; statements regarding Vermilion’s hedging program, its plans to add to its hedging positions, and the anticipated impact of Vermilion’s hedging program on project economics and free cash flows; the potential financial impact of climate-related risks; acquisition and disposition plans and the timing thereof; operating and other expenses, including the payment and amount of future dividends; royalty and income tax rates and Vermilion’s expectations regarding future taxes and taxability; and the timing of regulatory proceedings and approvals. Such forward-looking statements or information are based on a number of assumptions, all or any of which may prove to be incorrect. In addition to any other assumptions identified in this document, assumptions have been made regarding, among other things: the ability of Vermilion to obtain equipment, services and supplies in a timely manner to carry out its activities in Canada and internationally; the ability of Vermilion to market crude oil, natural gas liquids, and natural gas successfully to current and new customers; the timing and costs of pipeline and storage facility construction and expansion and the ability to secure adequate product transportation; the timely receipt of required regulatory approvals; the ability of Vermilion to obtain financing on acceptable terms; foreign currency exchange rates and interest rates; future crude oil, natural gas liquids, and natural gas prices; and management’s expectations relating to the timing and results of exploration and development activities. Although Vermilion believes that the expectations reflected in such forward-looking statements or information are reasonable, undue reliance should not be placed on forward-looking statements because Vermilion can give no assurance that such expectations will prove to be correct. Financial outlooks are provided for the purpose of understanding Vermilion’s financial position and business objectives, and the information may not be appropriate for other purposes. Forward-looking statements or information are based on current expectations, estimates, and projections that involve a number of risks and uncertainties which could cause actual results to differ materially from those anticipated by Vermilion and described in the forward-looking statements or information. These risks and uncertainties include, but are not limited to: the ability of management to execute its business plan; the risks of the oil and gas industry, both domestically and internationally, such as operational risks in exploring for, developing and producing crude oil, natural gas liquids, and natural gas; risks and uncertainties involving geology of crude oil, natural gas liquids, and natural gas deposits; risks inherent in Vermilion's marketing operations, including credit risk; the uncertainty of reserves estimates and reserves life and estimates of resources and associated expenditures; the uncertainty of estimates and projections relating to production and associated expenditures; potential delays or changes in plans with respect to exploration or development projects; Vermilion's ability to enter into or renew leases on acceptable terms; fluctuations in crude oil, natural gas liquids, and natural gas prices, foreign currency exchange rates, interest rates, and inflation rates; health, safety, and environmental risks; uncertainties as to the availability and cost of financing; the ability of Vermilion to add production and reserves through exploration and development activities; the possibility that government policies or laws may change or governmental approvals may be delayed or withheld; uncertainty in amounts and timing of royalty payments; risks associated with existing and potential future law suits and regulatory actions against or involving Vermilion; and other risks and uncertainties described elsewhere in this document or in Vermilion's other filings with Canadian securities regulatory authorities. The forward-looking statements or information contained in this document are made as of the date hereof and Vermilion undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events, or otherwise, unless required by applicable securities laws. This document contains references to sustainability/ESG data and performance that reflect metrics and concepts that are commonly used in such frameworks as the Global Reporting Initiative, the Task Force on Climate-related Financial Disclosures, and the Sustainability Accounting Standards Board. Vermilion has used best efforts to align with the most commonly accepted methodologies for ESG reporting, including with respect to climate data and information on potential future risks and opportunities, in order to provide a fuller context for our current and future operations. However, these methodologies are not yet standardized, are frequently based on calculation factors that change over time, and continue to evolve rapidly. Readers are particularly cautioned to evaluate the underlying definitions and measures used by other companies, as these may not be comparable to Vermilion’s. While Vermilion will continue to monitor and adapt its reporting accordingly, the Company is not under any duty to update or revise the related sustainability/ESG data or statements except as required by applicable securities laws. Vermilion Energy Inc. ■ Page 2 ■ 2023 Annual Report All crude oil and natural gas reserve and resource information contained in this document has been prepared and presented in accordance with National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities and the Canadian Oil and Gas Evaluation Handbook. Reserves estimates have been made assuming that development of each property in respect of which the estimate is made will occur, without regard to the likely availability of funding required for such development. The actual crude oil and natural gas reserves and future production will be greater than or less than the estimates provided in this document. Natural gas volumes have been converted on the basis of six thousand cubic feet of natural gas to one barrel of oil equivalent. Barrels of oil equivalent (boe) may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet to one barrel of oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Financial data contained within this document are reported in Canadian dollars unless otherwise stated. Vermilion Energy Inc. ■ Page 3 ■ 2023 Annual Report Abbreviations $M $MM AECO bbl(s) bbls/d boe boe/d GJ LSB mbbls mcf mmcf/d NBP NCIB NGLs PRRT tCO2e THE TTF WTI thousand dollars million dollars the daily average benchmark price for natural gas at the AECO ‘C’ hub in Alberta barrel(s) barrels per day barrel of oil equivalent, including: crude oil, condensate, natural gas liquids, and natural gas (converted on the basis of one boe for six mcf of natural gas) barrel of oil equivalent per day gigajoules light sour blend crude oil reference price thousand barrels thousand cubic feet million cubic feet per day the reference price paid for natural gas in the United Kingdom at the National Balancing Point Virtual Trading Point normal-course issuer bid natural gas liquids, which includes butane, propane, and ethane Petroleum Resource Rent Tax, a profit based tax levied on petroleum projects in Australia tonnes of carbon dioxide equivalent the price for natural gas in Germany, quoted in megawatt hours of natural gas, at the Trading Hub Europe the price for natural gas in the Netherlands, quoted in megawatt hours of natural gas, at the Title Transfer Facility Virtual Trading Point West Texas Intermediate, the reference price paid for crude oil of standard grade in US dollars at Cushing, Oklahoma Vermilion Energy Inc. ■ Page 4 ■ 2023 Annual Report Highlights Q4 2023 Results • • • • Q4 2023 fund flows from operations (“FFO”)(1) was $372 million ($2.27/basic share)(2) and exploration and development (“E&D”) capital expenditures(3) were $143 million, resulting in free cash flow (“FCF”)(4) of $229 million ($1.40/basic share)(5). Net debt(6) decreased by $164 million in Q4 2023 to $1.1 billion, the lowest level in a decade and a 50% reduction from the peak in 2020. In addition, Vermilion returned $45 million to shareholders comprised of $16 million of dividends and $29 million of share buybacks. Production during the fourth quarter of 2023 averaged 87,597 boe/d(8), comprised of 54,216 boe/d(8) from our North American assets and 33,381 boe/d(8) from our International assets. Q4 2023 production benefited from a full quarter of production from Australia and Ireland following maintenance downtime in the prior quarter, as well as increased production in the Netherlands due to new production from our 2023 drilling program. Year End 2023 Results • • • • • • 2023 FFO(1) was $1,143 million ($6.98/basic share)(2) and E&D capital expenditures(3) were $590 million, resulting in FCF(4) of $552 million ($3.37/basic share)(5). Net debt(6) decreased by $266 million in 2023 to $1.1 billion, representing a trailing net debt-to-FFO ratio(7) of under 1.0 times. In addition, Vermilion returned $160 million to shareholders, comprised of $65 million in dividends and $95 million of share buybacks. Reported a 2023 net loss of $238 million ($1.45/basic share) driven by non-cash impairment charges and dispositions, partially offset by strong price realization and acquisition activity. Excluding non-cash impairments, net earnings were $536 million ($3.27/basic share). Production during 2023 averaged 83,994 boe/d(8), which was at the mid-point of our 2023 guidance range. Strong performance across many of our business units served to offset wildfire-related downtime in Canada and maintenance downtime in Australia. Year-end 2023 proved developed producing ("PDP") reserves were 173 mmboe(9) and total proved plus probable ("2P") reserves were 430 mmboe(9), reflecting a reserve life index of 5.6 years and 14.0 years, respectively. The after-tax net present value of PDP reserves, discounted at 10%, is $3.2 billion(9) and the after-tax net present value of 2P reserves, discounted at 10%, is $5.7 billion(9), or $28.72 per basic share(9) after deducting year-end net debt. Outlook • • • In conjunction with our Q4 2023 release, we announced a quarterly cash dividend of $0.12 per share, payable on April 15, 2024 to shareholders of record on March 28, 2024. This quarterly cash dividend represents a 20% increase over the prior quarterly dividend. Given our strong financial position and continued operational momentum, we are increasing our capital return target to 50% of excess FCF and will manage to this target on a full-year basis versus our previous effective date of April 1, 2024. Year-to-date, we have repurchased and retired 1.4 million shares and plan to increase the pace of share buybacks starting immediately. Construction of the 16,000 boe/d Mica Montney battery is progressing as planned and remains on schedule for a mid-year start-up. With the additional capacity provided by this battery, we are able to move forward with the growth phase of our Mica Montney asset, and have drilled six wells on our 16-28 BC pad that will be completed and ready for tie-in during Q2 2024. • We continued to advance our deep gas exploration and development plans in Germany, with drilling operations nearly complete on the first well of our program. We expect to reach total depth in the coming weeks and will then move the rig to the next location, where the second well of our program will be drilled during Q2 2024. • In Croatia, we drilled the first exploration well on the SA-7 block in Q1 2024 and reached total measured depth of 2,371 metres, where we discovered hydrocarbons in multiple zones. We plan to evaluate and test these zones during the second quarter while commencing drilling on the second of four wells planned on the SA-7 block this year. Construction of the gas plant on the SA-10 block is progressing as planned and remains on schedule for a mid-year start-up. Vermilion Energy Inc. ■ Page 5 ■ 2023 Annual Report ($M except as indicated) Financial Petroleum and natural gas sales Cash flows from operating activities Fund flows from operations (1) Fund flows from operations ($/basic share) (2) Fund flows from operations ($/diluted share) (2) Net (loss) earnings Net (loss) earnings ($/basic share) Cash flows used in investing activities Capital expenditures (3) Acquisitions (10) Dispositions Asset retirement obligations settled Repurchase of shares Cash dividends ($/share) Dividends declared % of fund flows from operations (11) Payout (12) % of fund flows from operations (12) Free cash flow (4) Long-term debt Net debt (6) Net debt to four quarter trailing fund flows from operations (7) Operational Production (8) Crude oil and condensate (bbls/d) NGLs (bbls/d) Natural gas (mmcf/d) Total (boe/d) Average realized prices Crude oil and condensate ($/bbl) NGLs ($/bbl) Natural gas ($/mcf) Production mix (% of production) % priced with reference to WTI % priced with reference to Dated Brent % priced with reference to AECO % priced with reference to TTF and NBP Netbacks ($/boe) Operating netback (13) Fund flows from operations ($/boe) (14) Operating expenses General and administration expenses Average reference prices WTI (US $/bbl) Dated Brent (US $/bbl) AECO ($/mcf) TTF ($/mcf) Share information ('000s) Shares outstanding - basic Shares outstanding - diluted (15) Weighted average shares outstanding - basic Weighted average shares outstanding - diluted (15) Q4 2023 Q3 2023 Q4 2022 2023 2022 522,969 343,831 372,117 2.27 2.27 (803,136) (4.91) 132,932 142,887 25,724 14,855 28,937 28,736 0.10 16,227 475,532 118,436 270,218 1.65 1.62 57,309 0.35 170,404 125,639 5,238 — 13,582 11,645 0.10 16,367 842,693 495,195 284,220 1.74 1.70 395,408 2.42 168,053 169,305 4,558 — 16,508 — 0.08 13,058 2,022,555 1,024,528 1,142,611 6.98 6.98 (237,587) (1.45) 576,435 590,191 273,018 197,007 56,966 94,838 0.40 65,248 3,476,394 1,814,220 1,634,865 10.00 9.71 1,313,062 8.03 1,059,292 551,817 539,713 — 37,514 71,659 0.28 45,769 4 % 6 % 5 % 6 % 3 % 188,051 155,588 198,871 712,405 635,100 51 % 58 % 70 % 62 % 39 % 229,230 914,015 1,078,567 0.9 144,575 966,505 1,242,522 1.2 114,915 1,081,351 1,344,586 0.8 552,420 914,015 1,078,567 0.9 1,083,048 1,081,351 1,344,586 0.8 32,866 7,412 283.91 87,597 107.91 33.38 8.48 29 % 17 % 31 % 23 % 57.48 48.83 15.35 2.60 78.32 84.05 2.30 17.45 162,271 166,456 163,335 163,335 31,417 7,344 263.80 82,727 106.94 27.77 6.32 34 % 13 % 34 % 19 % 49.30 35.76 16.26 2.77 82.26 86.76 2.61 14.11 163,666 167,904 163,946 166,392 38,915 7,497 234.23 85,450 115.02 39.93 17.43 38 % 18 % 30 % 14 % 70.00 35.08 16.81 1.65 82.65 88.71 4.64 38.36 163,227 168,616 163,105 167,397 31,727 7,296 269.83 83,994 102.43 31.54 8.17 33 % 13 % 33 % 21 % 49.22 37.90 17.03 2.68 77.63 82.62 2.64 17.40 162,271 166,456 163,719 163,719 37,530 7,961 238.18 85,187 123.89 45.95 18.99 38 % 16 % 30 % 16 % 70.15 52.65 15.75 1.86 94.23 101.19 5.25 48.35 163,227 168,616 163,489 168,426 Vermilion Energy Inc. ■ Page 6 ■ 2023 Annual Report (1) (2) (3) (4) (5) (6) (7) (8) (9) Fund flows from operations (FFO) is a total of segments measure comparable to net (loss) earnings that is comprised of sales less royalties, transportation, operating, G&A, corporate income tax, PRRT, windfall taxes, interest expense, realized gain (loss) on derivatives, realized foreign exchange gain (loss), and realized other income (expense). The measure is used to assess the contribution of each business unit to Vermilion's ability to generate income necessary to pay dividends, repay debt, fund asset retirement obligations, and make capital investments. FFO does not have a standardized meaning under IFRS and therefore may not be comparable to similar measures provided by other issuers. More information and a reconciliation to primary financial statement measures can be found in the “Non-GAAP and Other Specified Financial Measures” section of this document. Fund flows from operations per share (basic and diluted) are supplementary financial measures and are not standardized financial measures under IFRS, and therefore may not be comparable to similar measures disclosed by other issuers. They are calculated using FFO (a total of segments measure) and basic/ diluted shares outstanding. The measure is used to assess the contribution per share of each business unit. More information and a reconciliation to primary financial statement measures can be found in the “Non-GAAP and Other Specified Financial Measures” section of this document. Capital expenditures is a non-GAAP financial measure that is the sum of drilling and development costs and exploration and evaluation costs from the Consolidated Statements of Cash Flows. More information and a reconciliation to primary financial statement measures can be found in the “Non-GAAP and Other Specified Financial Measures” section of this document. Free cash flow (FCF) and excess free cash flow (EFCF) are non-GAAP financial measures comparable to cash flows from operating activities. FCF is comprised of FFO less drilling and development and exploration and evaluation expenditures and EFCF is FCF less payments on lease obligations and asset retirement obligations settled. More information and a reconciliation to primary financial statement measures can be found in the “Non-GAAP and Other Specified Financial Measures” section of this document. Free cash flow per basic share is a non-GAAP supplementary financial measure and is not a standardized financial measure under IFRS and may not be comparable to similar measures disclosed by other issuers. It is calculated using FCF and basic shares outstanding. Net debt is a capital management measure comparable to long-term debt and is comprised of long-term debt (excluding unrealized foreign exchange on swapped USD borrowings) plus adjusted working capital (defined as current assets less current liabilities, excluding current derivatives and current lease liabilities). More information and a reconciliation to primary financial statement measures can be found in the “Non-GAAP and Other Specified Financial Measures” section of this document. Net debt to trailing FFO is a supplementary financial measure and is not a standardized financial measure under IFRS. It may not be comparable to similar measures disclosed by other issuers and is calculated using net debt (capital management measure) and FFO (total of segment measure). The measure is used to assess the ability to repay debt. Information in this document is included by reference; refer to the "Non-GAAP and Other Specified Financial Measures" section of this document. Please refer to Supplemental Table 4 "Production" of the accompanying Management's Discussion and Analysis for disclosure by product type. Estimated gross proved, developed and producing, total proved, and total proved plus probable reserves as evaluated by McDaniel & Associates Consultants Ltd. (“McDaniel”) in a report dated March 5, 2024 with an effective date of December 31, 2023 (the “2023 McDaniel Reserves Report”). See Vermilion’s annual information form for the year ended December 31, 2023 for additional information, including reserve pricing assumptions. Per share metrics calculated using basic shares outstanding at December 31, 2023. (10) Acquisitions is a non-GAAP financial measure that is calculated as the sum of acquisitions and acquisitions of securities from the Consolidated Statements of Cash Flows, Vermilion common shares issued as consideration, the estimated value of contingent consideration, the amount of acquiree's outstanding long- term debt assumed, and net acquired working capital deficit or surplus. More information and a reconciliation to primary financial statement measures can be found in the “Non-GAAP and Other Specified Financial Measures” section of this document. (11) Dividends % of FFO is a supplementary financial measure that is not standardized under IFRS and may not be comparable to similar measures disclosed by other issuers, calculated as dividends divided by FFO. The ratio is used by management as a metric to assess the cash distributed to shareholders. Reconciliation to primary financial statement measures can be found in the “Non-GAAP and Other Specified Financial Measures” section of this document. (12) Payout and payout % of FFO are a non-GAAP financial measure and a non-GAAP ratio, respectively, that are not standardized under IFRS and may not be comparable to similar measures disclosed by other issuers. Payout is comparable to dividends declared and is comprised of dividends declared plus drilling and development costs, exploration and evaluation costs, and asset retirement obligations settled, while the ratio is calculated as payout divided by FFO. More information and a reconciliation to primary financial statement measures can be found in the “Non-GAAP and Other Specified Financial Measures” section of this document. (13) Operating netback is a non-GAAP financial measure comparable to net earnings and is comprised of sales less royalties, operating expense, transportation costs, PRRT, and realized hedging gains and losses. More information and a reconciliation to primary financial statement measures can be found in the “Non- GAAP and Other Specified Financial Measures” section of this document. (14) Fund flows from operations per boe is a supplementary financial measure that is not standardized under IFRS and may not be comparable to similar measures disclosed by other issuers, calculated as FFO by boe production. Fund flows from operations per boe is used by management to assess the profitability of our business units and Vermilion as a whole. More information and a reconciliation to primary financial statement measures can be found in the “Non-GAAP and Other Specified Financial Measures” section of this document. (15) Diluted shares outstanding represent the sum of shares outstanding at the period end plus outstanding awards under the Long-term Incentive Plan (“LTIP”), based on current estimates of future performance factors and forfeiture rates. Vermilion Energy Inc. ■ Page 7 ■ 2023 Annual Report Message to Shareholders We made significant progress in 2023 towards our debt reduction and asset high-grading initiatives, while also advancing key growth projects in Canada, Germany, and Croatia. We closed the Corrib acquisition in Ireland and completed the disposition of select non-core assets in southeast Saskatchewan early in the year. These transactions further strengthened our asset base by adding more low emission, premium-priced European natural gas to our portfolio while divesting less efficient, higher cost assets in Canada. With this high-graded asset base, we were able to deliver on the midpoint of our annual production guidance of 84,000 boe/d despite wildfire-related downtime in Western Canada and unplanned downtime in Australia. Our ability to meet annual production guidance highlights the advantages of operating a diversified portfolio as we were able to reallocate capital to offset the production impacts in Canada and Australia. With strong operational performance in the fourth quarter, we achieved average production of 87,597 boe/d in Q4 2023, representing a 6% increase over the prior quarter. Vermilion generated $1.1 billion of fund flows from operations (“FFO”) in 2023, representing the second strongest year in the history of the company. After accounting for E&D capital expenditures, we generated $552 million of free cash flow (“FCF”), of which 29%, or $160 million ($0.98 per share), was returned directly to shareholders through an increased dividend and share buybacks, and an additional $266 million ($1.62/share) was returned indirectly through debt reduction. Q4 2023 FFO and FCF was $372 million and $229 million, respectively, representing a 38% and 59% increase over the prior quarter, primarily due to higher production from our high-margin Australia and Ireland business units and tax adjustments. Net debt decreased by $266 million in 2023 to end the year at $1.1 billion, which is the lowest level in a decade and represents 0.9 times our annual FFO. This is a key milestone for the company as it aligns with our internal leverage target of one times net debt to FFO or less, and positions us for increasing shareholder returns, including a 20% increase to our quarterly dividend effective Q1 2024, previously announced with our 2024 budget. As a result of the progress achieved on debt reduction, we are now able to accelerate our return of capital. The return of capital framework outlined with our 2024 budget release in December contemplated a capital return target of 30% of excess FCF ("EFCF") in Q1 2024, increasing to 50% of EFCF effective April 1, 2024. Given our strong financial position and continued operational momentum, we now plan to increase our capital return target to 50% of EFCF on a full-year basis for 2024 with a corresponding increase in share buybacks starting immediately, as we continue to believe share buybacks represent a competitive use of capital. Our disciplined focus on strengthening the balance sheet and high-grading the asset base, along with diligent capital allocation, has made the company much stronger and much more resilient today. We ended 2023 with a strong balance sheet and have continued our operational momentum from the fourth quarter into 2024. Our 2024 capital program is well underway and we are very pleased with how things are progressing on our three key growth initiatives in Canada, Germany and Croatia. The development of our gas prospects in Germany and Croatia will increase our exposure to premium-priced European gas, while the expansion of our Montney infrastructure in Canada will set the stage for long-term development and growth of this asset. We are excited about Vermilion’s outlook and believe we have a robust portfolio capable of generating strong compounded returns for our shareholders through a combination of modest annual production growth, a resilient and growing base dividend and share buybacks. We would like to thank all our stakeholders for their ongoing support and contributions, and we look forward to providing further updates on our 2024 operational and financial results as the year progresses. Q4 2023 Operations Review North America Production from our North American operations averaged 54,216 boe/d(1) in Q4 2023, a decrease of 4% from the previous quarter due to natural declines in both Canada and the United States. In the Deep Basin, we drilled five (5.0 net), completed five (5.0 net), and brought on production four (4.0 net) Mannville liquids-rich conventional natural gas wells. At Mica we drilled the initial four (4.0 net) Montney liquids-rich shale gas wells on our BC lands as part of our winter drilling program in advance of the expected start-up of our 8-33 BC battery in mid-2024. In Saskatchewan, we completed and brought on production one (1.0 net) light and medium crude oil well, while in the United States, we participated in the drilling of six (2.0 net) non-operated light and medium crude oil wells in Wyoming. Construction of the 16,000 boe/d Mica Montney battery is progressing as planned and remains on schedule for a mid-year start-up. Once operational, this battery will more than double our Montney infrastructure capacity to approximately 20,000 boe/d. With this additional capacity, we are able to move forward with the growth phase of our Mica Montney asset, and to date have drilled eight of the 11 planned wells on or offsetting our recent 16-28 BC pad. The two wells that were previously drilled on this pad and brought on production in March 2023 have produced nearly 700,000 boe combined to the end of February 2024, including over 215,000 barrels of liquids (83% light crude oil). Six of the new wells are expected to be completed and ready for tie-in during Q2 2024 to align with the start-up of the new battery. Vermilion Energy Inc. ■ Page 8 ■ 2023 Annual Report International Production from our International operations averaged 33,381 boe/d(1) in Q4 2023, an increase of 29% over the previous quarter primarily due to a full quarter of production at our Australia and Ireland operations following maintenance downtime in the prior quarter, as well as increased production in the Netherlands due to new production from our 2023 drilling program. We continued to advance our deep gas exploration and development plans in Germany, with drilling operations nearly complete on our first well of our program. We expect to reach total depth in the coming weeks and will then move the rig to the next location, where the second well of our program will be drilled during Q2 2024. In Croatia, construction of the gas plant on the SA-10 block is progressing as planned and remains on schedule for start-up mid-year. This gas plant will facilitate production from the SA-10 block where we have previous gas discoveries. Subsequent to year-end, we commenced drilling on the first exploration well on the SA-7 block and reached total measured depth of 2,371 metres, where we discovered hydrocarbons in multiple zones. We plan to evaluate and test these zones during the second quarter while commencing drilling on the second of four wells planned on the SA-7 block this year. In addition, we recently signed a farmout agreement with the INA Group to jointly develop the SA-7 block. INA is the largest integrated oil and gas company in Croatia and brings local expertise and access to existing infrastructure that will play a critical role in developing this asset. 2023 Reserves Update Our 2023 proved developed producing (“PDP”) reserves decreased by 8% from the prior year to 172.7 mmboe(2) while our total proved plus probable (“2P”) reserves decreased by 18% from the prior year to 429.8 mmboe(2), primarily due to dispositions, production, and technical revisions, including technical revisions resulting from capital allocation decisions. Early in the year, we divested a non-core asset in southeast Saskatchewan which accounted for 11.6 mmboe of the PDP reduction and 32.4 mmboe of the 2P reduction. During the second half of the year we divested non-core assets in the USA, contributing 0.7 mmboe to the PDP reduction and 13.9 mmboe of the 2P reduction. The closing of the Corrib acquisition in Ireland in Q1 2023 added 12.5 mmboe of premium priced European gas to our PDP reserves and 17.2 mmboe to our 2P reserves. Over the past couple years, we have placed a great deal of focus on asset high-grading and advancing several key growth projects within our portfolio to increase FCF per share. As a result, some of our near-term capital allocation priorities have shifted, with a greater emphasis on funding our Mica Montney development and Germany exploration program. With this in mind, we have updated future capital allocation estimates to align with our long-term capital priorities, including our return of capital framework. As a result, we have removed or divested reserves associated with undeveloped locations that are not prioritized for investment under our current plans. The assets most impacted by these capital allocation decisions are located in the USA and Saskatchewan. Approximately 40% of the 2P technical revisions relate to capital allocation decisions and therefore, some of these formerly assigned reserves could be recognized at a future date if they align with our capital allocation parameters at that time. In addition, we expect to recognize additional reserves over time from our Mica Montney and Germany exploration program as we develop these assets. The PDP and 2P reserve life index at December 31, 2023 is 5.6 years and 14.0 years, respectively, both of which are in line with our long-term average and appropriately reflect the conventional composition of our asset base. The after-tax net present value of PDP reserves, discounted at 10%, is $3.2 billion(2) and the after-tax net present value of 2P reserves, discounted at 10%, is $5.7 billion(2), or $28.72 per basic share(3) after deducting year-end net debt. The following table provides a summary of company interest reserves by reserve category and region on an oil equivalent basis. Please refer to Vermilion's 2023 Annual Information Form for the year ending December 31, 2023 ("2023 Annual Information Form") for detailed information by country and product type. BOE (mboe) North America International Vermilion Proved Developed Producing 112,204 60,502 172,706 Proved Developed Non-Producing 5,450 6,892 12,342 Proved Undeveloped 78,031 5,305 83,336 Proved 195,685 72,700 268,385 Probable 120,355 41,098 161,453 Proved Plus Probable 316,040 113,798 429,838 Vermilion Energy Inc. ■ Page 9 ■ 2023 Annual Report The following table provides a reconciliation of changes in company interest reserves by reserve category and region. Please refer to Vermilion's 2023 Annual Information Form for detailed information by country and product type and for an explanation concerning the reserve change categories. The following tables may not total due to rounding. PDP (mboe) December 31, 2022 Discoveries Extensions & Improved Recovery Technical Revisions Acquisitions Dispositions Economic Factors Production December 31, 2023 1P (mboe) December 31, 2022 Discoveries Extensions & Improved Recovery Technical Revisions Acquisitions Dispositions Economic Factors Production December 31, 2023 2P (mboe) December 31, 2022 Discoveries Extensions & Improved Recovery Technical Revisions Acquisitions Dispositions Economic Factors Production December 31, 2023 North America International 133,879 — 5,399 2,931 2,791 (12,456) 194 (20,534) 112,204 54,738 — 293 2,706 12,548 — 339 (10,122) 60,502 North America International 244,670 — 23,735 (28,211) 2,812 (27,361) 575 (20,534) 195,685 68,461 — 692 729 12,548 — 395 (10,122) 72,699 North America International 412,044 — 27,280 (59,548) 3,613 (47,310) 495 (20,534) 316,040 110,744 — 25 (2,951) 17,209 — (1,107) (10,122) 113,799 Vermilion 188,617 — 5,692 5,637 15,339 (12,456) 533 (30,656) 172,706 Vermilion 313,129 — 24,428 (27,483) 15,360 (27,361) 969 (30,657) 268,385 Vermilion 522,790 — 27,305 (62,500) 20,823 (47,310) (612) (30,657) 429,838 Additional information about our 2023 McDaniel Reserves Report can be found in our 2023 Annual Information Form on our website at www.vermilionenergy.com and on SEDAR+ at www.sedarplus.ca. Outlook and Guidance Update Our Q1 2024 capital program is progressing as planned with a primary focus on Montney drilling and battery construction, Germany exploration drilling and Croatia gas plant construction. Most of the production from the Q1 2024 activity will not be on stream until mid-year or later, and as a result we expect Q1 2024 production to be in the range of 83,000 to 85,000 boe/d. Organizational Update Mr. Bryce Kremnica has stepped down as Vice President of North America. We would like to thank Mr. Kremnica for his many contributions to Vermilion over the past 18 years. Mr. Randy McQuaig has been promoted to Vice President, North America and will become a member of Vermilion’s Executive Committee. Mr. McQuaig has been with Vermilion since 2013 and most recently held the position of Director of Canada Business Unit Assets, a position he has held since 2021. Mr. McQuaig has 30 years of operations and executive management experience, and has a Bachelor of Science degree in Petroleum Engineering from the University of Alberta. Vermilion Energy Inc. ■ Page 10 ■ 2023 Annual Report Commodity Hedging Vermilion hedges to manage commodity price exposures and increase the stability of our cash flows. In aggregate, as of March 6, 2024, we have 33% of our expected net-of-royalty production hedged for 2024. With respect to individual commodity products, we have hedged 46% of our European natural gas production, 28% of our crude oil production, and 29% of our North American natural gas volumes for 2024, respectively. Please refer to the Hedging section of our website under Invest With Us for further details using the following link: https://www.vermilionenergy.com/invest-with-us/hedging. (Signed “Dion Hatcher”) Dion Hatcher President & Chief Executive Officer March 6, 2024 (1) (2) (3) Please refer to Supplemental Table 4 "Production" of the accompanying Management's Discussion and Analysis for disclosure by product type. Estimated gross proved, developed and producing, total proved, and total proved plus probable reserves as evaluated by McDaniel & Associates Consultants Ltd. (“McDaniel”) in a report dated March 5, 2024 with an effective date of December 31, 2023 (the “2023 McDaniel Reserves Report”). Net present value of discounted cash flows as provided in the 2023 McDaniel Reserves Report. See Vermilion’s annual information form for the year ended December 31, 2023 for additional information, including reserve pricing assumptions. Per share metrics calculated using basic shares outstanding at December 31, 2023, refer to Highlights table for additional information. Vermilion Energy Inc. ■ Page 11 ■ 2023 Annual Report Non-GAAP and Other Specified Financial Measures This report and other materials released by Vermilion includes financial measures that are not standardized, specified, defined, or determined under IFRS and are therefore considered non-GAAP or other specified financial measures and may not be comparable to similar measures presented by other issuers. These financial measures include: Total of Segments Measures Fund flows from operations (FFO): Most directly comparable to net (loss) earnings, FFO is comprised of sales less royalties, transportation, operating, G&A, corporate income tax, PRRT, windfall taxes, interest expense, realized gain (loss) on derivatives, realized foreign exchange gain (loss), and realized other income (expense). The measure is used to assess the contribution of each business unit to Vermilion's ability to generate income necessary to pay dividends, repay debt, fund asset retirement obligations and make capital investments. Sales Royalties Transportation Operating General and administration Corporate income tax expense Windfall taxes PRRT Interest expense Realized gain (loss) on derivatives Realized foreign exchange gain (loss) Realized other (expense) income Fund flows from operations Equity based compensation Unrealized (loss) gain on derivative instruments (1) Unrealized foreign exchange (loss) gain (1) Accretion Depletion and depreciation Deferred tax recovery (expense) Gain on business combination Loss on disposition Impairment (expense) reversal Unrealized other expense Net (loss) earnings (1) $/boe 111.95 (9.85) (2.54) (15.75) (1.86) (6.70) (7.18) (0.59) (2.67) (13.07) 0.49 0.42 52.65 $/boe 68.64 (5.93) (2.95) (15.35) (2.60) (2.54) (0.03) 2.74 (3.01) 10.33 (0.73) 0.26 48.83 Q4 2023 $M 522,969 (45,148) (22,441) (116,937) (19,810) (19,374) (249) 20,860 (22,909) 78,737 (5,529) 1,948 372,117 (7,871) 141,126 4,834 (19,469) (259,012) 110,758 (5,607) (125,539) (1,016,094) 1,621 (803,136) Q4 2022 $M 842,693 (68,303) (21,976) (136,247) (13,344) (41,958) (222,859) (5,045) (22,506) (43,940) 18,845 (1,140) 284,220 (5,377) 549,693 (47,405) (16,501) (171,926) (196,733) — — — (563) 395,408 2023 $M $/boe 103.99 2,022,555 (8.43) (191,694) (2.71) (88,856) (16.81) (513,381) (80,716) (1.65) (91,932) (5.18) (78,426) (27.50) 20,860 (0.62) (2.78) (85,212) (5.42) 234,365 (4,532) 2.33 (0.14) (420) 35.08 1,142,611 (42,756) 179,707 12,438 (78,187) (712,619) 190,193 439,487 (352,367) (1,016,094) — (237,587) 2022 $M $/boe 67.10 3,476,394 (6.36) (306,017) (2.95) (78,896) (17.03) (489,034) (2.68) (57,677) (3.05) (208,153) (2.60) (222,859) (18,318) 0.69 (2.83) (82,858) 7.77 (405,894) 15,195 (0.15) (0.01) 12,982 37.90 1,634,865 (44,390) 540,801 (84,464) (58,170) (577,134) (288,707) — — 192,094 (1,833) 1,313,062 Unrealized gain on derivative instruments, Unrealized foreign exchange gain (loss), and Unrealized other expense are line items from the respective Consolidated Statements of Cash Flows. Non-GAAP Financial Measures and Non-GAAP Ratios Free cash flow (FCF) and excess free cash flow (EFCF): Most directly comparable to cash flows from operating activities, FCF is comprised of fund flows from operations less drilling and development costs and exploration and evaluation cost and EFCF is comprised of FCF less payments on lease obligations and asset retirement obligations settled. The measure is used to determine the funding available for investing and financing activities including payment of dividends, repayment of long-term debt, reallocation into existing business units and deployment into new ventures. EFCF is used to determine the funding available to return to shareholders after costs attributable to normal business operations. Vermilion Energy Inc. ■ Page 12 ■ 2023 Annual Report ($M) Cash flows from operating activities Changes in non-cash operating working capital Asset retirement obligations settled Fund flows from operations Drilling and development Exploration and evaluation Free cash flow Payments on lease obligations Asset retirement obligations settled Excess free cash flow Q4 2023 343,831 (651) 28,937 372,117 (132,308) (10,579) 229,230 (3,977) (28,937) 196,316 Q4 2022 495,195 (227,483) 16,508 284,220 (157,849) (11,456) 114,915 (8,019) (16,508) 90,388 2023 1,024,528 61,117 56,966 1,142,611 (569,110) (21,081) 552,420 (17,094) (56,966) 478,360 2022 1,814,220 (216,869) 37,514 1,634,865 (528,056) (23,761) 1,083,048 (21,168) (37,514) 1,024,366 Adjusted working capital: Defined as current assets less current liabilities, excluding current derivatives and current lease liabilities. The measure is used to calculate net debt, a capital measure disclosed above. ($M) Current assets Current derivative asset Current liabilities Current lease liability Current derivative liability Adjusted working capital As at Dec 31, 2023 823,514 (313,792) (696,074) 21,068 732 (164,552) Dec 31, 2022 714,446 (162,843) (892,045) 19,486 55,845 (265,111) Capital expenditures: Calculated as the sum of drilling and development costs and exploration and evaluation costs from the Consolidated Statements of Cash Flows and most directly comparable to cash flows used in investing activities. We consider capital expenditures to be a useful measure of our investment in our existing asset base. Capital expenditures are also referred to as E&D capital. ($M) Drilling and development Exploration and evaluation Capital expenditures Q4 2023 132,308 10,579 142,887 Q4 2022 157,849 11,456 169,305 2023 569,110 21,081 590,191 2022 528,056 23,761 551,817 Operating netback: Most directly comparable to net (loss) earnings and is calculated as sales less royalties, operating expense, transportation costs, PRRT, and realized hedging gains and losses presented on a per unit basis. Management assesses operating netback as a measure of the profitability and efficiency of our field operations. Payout and payout % of FFO: A non-GAAP financial measure and non-GAAP ratio respectively most directly comparable to dividends declared. Payout is comprised of dividends declared plus drilling and development costs, exploration and evaluation costs, and asset retirement obligations settled. The measure is used to assess the amount of cash distributed back to shareholders and reinvested in the business for maintaining production and organic growth. The reconciliation of the measure to primary financial statement measure can be found below. Management uses payout and payout as a percentage of FFO (also referred to as the payout or sustainability ratio). ($M) Dividends Declared Drilling and development Exploration and evaluation Asset retirement obligations settled Payout % of fund flows from operations Q4 2023 16,227 132,308 10,579 28,937 188,051 Q4 2022 13,058 157,849 11,456 16,508 198,871 2023 2022 65,248 569,110 21,081 56,966 712,405 45,769 528,056 23,761 37,514 635,100 51 % 70 % 62 % 39 % Acquisitions: The sum of acquisitions and acquisitions of securities from the Consolidated Statements of Cash Flows, Vermilion common shares issued as consideration, the estimated value of contingent consideration, the amount of acquiree's outstanding long-term debt assumed, and net Vermilion Energy Inc. ■ Page 13 ■ 2023 Annual Report acquired working capital deficit or surplus. We believe that including these components provides a useful measure of the economic investment associated with our acquisition activity and is most directly comparable to cash flows used in investing activities. A reconciliation to the acquisitions line items in the Consolidated Statements of Cash Flows can be found below. ($M) Acquisitions, net of cash acquired Acquisition of securities Acquired working capital deficit Acquisitions Capital Management Measure Q4 2023 Q4 2022 2,669 17,448 5,607 25,724 3,594 964 — 4,558 2023 142,281 21,603 109,134 273,018 2022 510,309 23,282 6,122 539,713 Net debt: Is in accordance with IAS 1 "Presentation of Financial Statements" and is most directly comparable to long-term debt. Net debt is comprised of long-term debt (excluding unrealized foreign exchange on swapped USD borrowings) plus adjusted working capital and represents Vermilion's net financing obligations after adjusting for the timing of working capital fluctuations. ($M) Long-term debt Adjusted working capital Unrealized FX on swapped USD borrowings Net debt As at Dec 31, 2023 914,015 164,552 — 1,078,567 Dec 31, 2022 1,081,351 265,111 (1,876) 1,344,586 Ratio of net debt to four quarter trailing fund flows from operations 0.9 0.8 Supplementary Financial Measures Net debt to four quarter trailing fund flows from operations: Calculated as net debt (capital management measure) over the FFO (total of segments measure) from the preceding four quarters. The measure is used to assess the ability to repay debt. Dividends % of FFO: Calculated as dividends declared divided by FFO (total of segments measure). The measure is used by management as a metric to assess the cash distributed to shareholders. Fund flows from operations per boe: Calculated as FFO (total of segments measure) by boe production. Fund flows from operations per boe is used by management to assess the profitability of our business units and Vermilion as a whole. Vermilion Energy Inc. ■ Page 14 ■ 2023 Annual Report Management's Discussion and Analysis The following is Management’s Discussion and Analysis (“MD&A”), dated March 6, 2024, of Vermilion Energy Inc.’s (“Vermilion”, “we”, “our”, “us” or the “Company”) operating and financial results as at and for the three months and year ended December 31, 2023 compared with the corresponding periods in the prior year. This discussion should be read in conjunction with the audited consolidated financial statements for the year ended December 31, 2023 and 2022, together with the accompanying notes. Additional information relating to Vermilion, including its Annual Information Form, is available on SEDAR+ at www.sedarplus.ca or on Vermilion’s website at www.vermilionenergy.com. The audited consolidated financial statements for the year ended December 31, 2023 and comparative information have been prepared in Canadian dollars and in accordance with International Financial Reporting Standards (“IFRS” or, alternatively, “GAAP”) as issued by the International Accounting Standards Board ("IASB"). This MD&A includes references to certain financial measures which are not specified, defined, or determined under IFRS and are therefore considered non-GAAP and other specified financial measures. These financial measures are unlikely to be comparable to similar financial measures presented by other issuers. For a full description of these non-GAAP and other specified financial measures and a reconciliation of these measures to their most directly comparable GAAP measures, please refer to “Non-GAAP and Other Specified Financial Measures”. Product Type Disclosure Under National Instrument 51-101 "Standards of Disclosure for Oil and Gas Activities", disclosure of production volumes should include segmentation by product type as defined in the instrument. In this report, references to "crude oil" and "light and medium crude oil" mean "light crude oil and medium crude oil" and references to "natural gas" mean "conventional natural gas". In addition, in Supplemental Table 4 "Production", Vermilion provides a reconciliation from total production volumes to product type and also a reconciliation of "crude oil and condensate" and "NGLs" to the product types "light crude oil and medium crude oil" and "natural gas liquids". Production volumes reported are based on quantities as measured at the first point of sale. Vermilion Energy Inc. ■ Page 15 ■ 2023 Annual Report Guidance On January 6, 2023, we released our 2023 capital budget and associated production guidance, which incorporated the March 31, 2023 close date of the acquisition of an incremental 36.5% interest in the Corrib Natural Gas Project (“Corrib”) in Ireland. On March 8, 2023, we decreased annual production guidance to 82,000 to 86,000 boe/d to reflect the southeast Saskatchewan asset sale and unplanned downtime in Australia, and decreased operating expense guidance to reflect the southeast Saskatchewan asset sale and lower European gas prices. On May 3, 2023, we updated royalty rate guidance to include Netherlands windfall royalties, which were previously included in windfall tax guidance, and provided revisions to 2023 guidance items to reflect the assumptions used in management's most recent forecast. On November 1, 2023, we increased capital expenditure guidance by $20 million primarily due to the acceleration of some Montney development as a result of the timely receipt of permits, and revised other 2023 guidance items to reflect the assumptions used in management's most recent forecast. The Company’s guidance and results for 2023 are as follows: Category Production (boe/d) E&D capital expenditures ($MM) Royalty rate, including windfall royalties (% of sales) (2) Operating ($/boe) Transportation ($/boe) General and administration ($/boe) Cash taxes (% of pre-tax FFO) Windfall tax, excluding windfall royalties (% of pre-tax FFO) (3) 2023 Guidance (1) 82,000 - 86,000 590 10 - 12% $16.50 - 17.50 $2.75 - 3.25 $2.00 - 2.50 6 - 8% 8 - 10% 2023 Actual (1) 83,994 590 9.5% $17.03 $2.95 $2.68 5.5% 6.0% On December 12, 2023, we released our 2024 capital budget and associated production guidance, which assumes a mid-year startup of the new BC Montney battery and Croatia gas plant. The Company’s guidance for 2024 is as follows: Category Production (boe/d) E&D capital expenditures ($MM) Royalty rate (% of sales) Operating ($/boe) Transportation ($/boe) General and administration ($/boe) Cash taxes (% of pre-tax FFO) Asset retirement obligations settled ($MM) Payments on lease obligations ($MM) (4) 2024 Guidance (1) 82,000 - 86,000 $600 - 625 7 - 9% $17.00 - 18.00 $3.00 - 3.50 $2.50 - 3.00 5 - 7% $60 $30 - 60 (1) (2) Final 2023 guidance reflects foreign exchange assumptions of CAD/USD 1.35, CAD/EUR 1.46, and CAD/AUD 0.89. Actual 2023 results reflects foreign exchange rates of CAD/USD 1.35, CAD/EUR 1.46, and CAD/AUD 0.90. Current 2024 guidance reflects foreign exchange assumptions of CAD/USD 1.35, CAD/EUR 1.47, and CAD/AUD 0.89. Royalty rate guidance includes the temporary windfall royalty that was enacted by the Netherlands in the fourth quarter of 2022. This royalty applies to 2023 and 2024 and, for natural gas sales, is calculated as 65% of the excess of the realized price for a subject year versus the threshold price of €0.50/Nm3 (€13.40/mcf). This royalty is deductible against current income taxes. (3) Windfall tax guidance incorporates windfall taxes as legislated in EU member states in which Vermilion does business. Windfall royalties in the Netherlands are (4) excluded from windfall tax guidance, and have been included in royalty rate guidance, above. Payments on lease obligations includes contractual amounts owing on leases, as well as up to $30 million to account for accelerated principal payments that may be made in 2024. Vermilion Energy Inc. ■ Page 16 ■ 2023 Annual Report Vermilion's Business Vermilion is a Calgary, Alberta-based international oil and gas producer focused on the acquisition, exploration, development, and optimization of producing properties in North America, Europe, and Australia. We manage our business through our Calgary head office and our international business unit offices. Vermilion Energy Inc. ■ Page 17 ■ 2023 Annual Report 2023 production of 83,994 boe/dNorth America: 67%International: 33%2023 capital expenditures of $590.2MMNorth America: 64%International: 36%2023 fund flows from operations of $1,142.6MMNorth America: 47%International: 53% Consolidated Results Overview Production (1) Crude oil and condensate (bbls/d) NGLs (bbls/d) Natural gas (mmcf/d) Total (boe/d) Build (draw) in inventory (mbbls) Financial metrics Fund flows from operations ($M) (2) Per share ($/basic share) Net (loss) earnings ($M) Per share ($/basic share) Cash flows from operating activities ($M) Free cash flow ($M) (3) Long-term debt ($M) Net debt ($M) (4) Activity Capital expenditures ($M) (5) Acquisitions ($M) (6) Dispositions ($M) Q4 2023 Q4 2022 Q4/23 vs. Q4/22 2023 2022 2023 vs. 2022 32,866 7,412 283.91 87,597 442 38,915 7,497 234.23 85,450 (242) 372,117 284,220 1.74 2.27 395,408 (803,136) 2.42 (4.91) 495,195 343,831 229,230 114,915 914,015 1,081,351 1,078,567 1,344,586 142,887 25,724 14,855 169,305 4,558 — (16)% (1)% 21% 3% 31% 31% N/A N/A (31)% 100% (16)% (20)% (16)% 31,727 7,296 269.83 83,994 513 37,530 7,961 238.18 85,187 39 6.98 (1.45) 1,142,611 1,634,865 10.00 (237,587) 1,313,062 8.03 1,024,528 1,814,220 552,420 1,083,048 914,015 1,081,351 1,078,567 1,344,586 590,191 273,018 197,007 551,817 539,713 — (16)% (8)% 13% (1)% (30)% (30)% N/A N/A (44)% (49)% (16)% (20)% 7% (1) (2) (3) (4) (5) (6) Please refer to Supplemental Table 4 "Production" for disclosure by product type. Fund flows from operations (FFO) and FFO per share are a total of segments measure and supplementary financial measure respectively most directly comparable to net (loss) earnings and net (loss) earnings per share, respectively. The measures do not have a standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other issuers. FFO is comprised of sales less royalties, transportation, operating, G&A, corporate income tax, PRRT, windfall taxes, interest expense, and realized loss (gain) on derivatives, plus realized gain (loss) on foreign exchange and realized other income (expense). The measure is used to assess the contribution of each business unit to Vermilion's ability to generate income necessary to pay dividends, repay debt, fund asset retirement obligations and make capital investments. A reconciliation to the primary financial statement measures can be found within the "Non-GAAP and Other Specified Financial Measures" section of this MD&A. Free cash flow (FCF) is a non-GAAP financial measure most directly comparable to cash flows from operating activities; it does not have a standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other issuers. FCF is comprised of fund flows from operations less drilling and development costs and exploration and evaluation costs. The measure is used to determine the funding available for investing and financing activities including payment of dividends, repayment of long-term debt, reallocation into existing business units and deployment into new ventures. A reconciliation to primary financial statement measures can be found within the "Non-GAAP and Other Specified Financial Measures" section of this MD&A. Net debt is a capital management measure in accordance with IAS 1 "Presentation of Financial Statements" and is most directly comparable to long-term debt. Net debt is comprised of long-term debt (excluding unrealized foreign exchange on swapped USD borrowings) plus adjusted working capital (defined as current assets less current liabilities, excluding current derivatives and current lease liabilities), and represents Vermilion's net financing obligations after adjusting for the timing of working capital fluctuations. Net debt excludes lease obligations which are secured by a corresponding right-of-use asset. A reconciliation to the primary financial statement measures can be found within the "Financial Position Review" section of this MD&A. Capital expenditures is a non-GAAP financial measure that does not have a standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other issuers. The measure is calculated as the sum of drilling and development costs and exploration and evaluation costs from the Consolidated Statements of Cash Flows. We consider capital expenditures to be a useful measure of our investment in our existing asset base. Capital expenditures are also referred to as E&D capital. A reconciliation to the primary financial statement measures can be found within the "Non-GAAP and Other Specified Financial Measures" section of this MD&A. Acquisitions is a non-GAAP financial measure that does not have a standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other issuers. The measure is calculated as the sum of acquisitions, net of cash and acquisitions of securities from the Consolidated Statements of Cash Flows, Vermilion common shares issued as consideration, the estimated value of contingent consideration, the amount of acquiree's outstanding long-term debt assumed, and net acquired working capital deficit or surplus. We believe that including these components provides a useful measure of the economic investment associated with our acquisition activity. A reconciliation to the acquisitions line item in the Consolidated Statements of Cash Flows can be found in "Supplemental Table 3: Capital Expenditures and Acquisitions" section of this MD&A. Vermilion Energy Inc. ■ Page 18 ■ 2023 Annual Report Financial performance review Q4 2023 vs. Q4 2022 • We recorded net loss of $803.1 million ($(4.91)/basic share) for Q4 2023 compared to $395.4 million ($2.42/basic share) in Q4 2022. The increase in net loss was primarily due to impairment charges of $1.0 billion and decreases in unrealized derivative gains of $408.6 million due to changes in our mark-to-market position. The increase to net loss was partially offset by higher fund flows from operations primarily driven by a reduction in windfall tax expense in the quarter due to timing of recognition at the end of 2022 compared to throughout 2023. Vermilion Energy Inc. ■ Page 19 ■ 2023 Annual Report "Other" contains equity based compensation, accretion, unrealized other, and gain on business combination$MMNet loss of $803.1MM in Q4 2023 compared to net earnings of $395.4MM in Q4 2022$395.4$307.5$87.9$(1,016.1)$(356.3)$(125.5)$(87.1)$(8.9)$(803.1)Q4 2022Deferred taxFund flows from operationsImpairmentUnrealized derivatives, foreign exchangeLoss on dispositionDepletion and depreciationOtherQ4 2023-1,000-5000500 • We generated cash flows from operating activities of $343.8 million in Q4 2023 compared to $495.2 million in Q4 2022 and fund flows from operations of $372.1 million in Q4 2023 compared to $284.2 million in Q4 2022. The increase in fund flows from operations was primarily driven by timing of windfall taxes, and partially offset by lower commodity prices. The variance between cash flows from operating activities and fund flows from operations is primarily due to non-cash working capital impacts of the full year windfall taxes payable recorded on higher pricing in the last quarter of 2022. 2023 vs. 2022 Vermilion Energy Inc. ■ Page 20 ■ 2023 Annual Report "Pricing net of derivatives" contains pricing variance on sales volumes (WTI, AECO, Dated Brent & TTF and NBP) and realized derivatives. "Sales volume" is the sum of sales volume variance in all regions. "Other" contains transportation, operating expense, general and administration, interest, realized foreign exchange, and other realized income.$MMIncreased FFO driven by lower windfall taxes. Decreased cash flows from operating activities driven by working capital timing. $284.2$222.6$48.5$23.2$(150.4)$(46.6)$(9.4)$372.1$495.2$343.8Cash flows from operating activitiesQ4 2022 - FFOWindfall taxesTaxesRoyaltiesPricing net of derivativesSales volumeOtherQ4 2023 - FFO200300400500600"Other" contains equity based compensation, depletion and depreciation, and unrealized other$MMNet loss of $237.6MM in 2023 compared to $1,313.1MM in 2022$1,313.1$478.9$439.5$(1,208.2)$(492.3)$(352.4)$(264.2)$(152.0)$(237.6)2022Deferred taxGain on business combinationsImpairmentFund flows from operationsLoss on sale of assetsUnrealized derivatives, foreign exchangeOther2023-50005001,0001,5002,000 • For the year ended December 31, 2023, we recorded net loss of $237.6 million compared to net earnings of $1,313.1 million for the comparable period in 2022. The net loss was primarily due to impairment charges of $1.0 billion compared to impairment reversal of $192.1 million, a decrease in FFO driven by lower commodity prices and lower production, and the loss recognized on the sale of assets. This was partially offset by the gain recognized on the Corrib acquisition. • For the year ended December 31, 2023 as compared to 2022, cash flows from operating activities decreased by $789.7 million to $1,024.5 million and fund flows from operations decreased by $492.3 million to $1,142.6 million. The decrease in fund flows from operations was primarily driven by a 40% decrease in our consolidated realized price from $111.95/boe to $67.10/boe, and a decrease in sales volumes primarily driven by the Australian Wandoo platform shutdown for the first three quarters of the year. This was partially offset by decreases in tax expense, windfall tax expense and royalties due to the pricing and sales volume changes. Variances between cash flows from operating activities and funds flow from operations are primarily driven by working capital timing differences. Production review Q4 2023 vs. Q4 2022 • Consolidated average production of 87,597 boe/d in Q4 2023 increased compared to Q4 2022 production of 85,450 boe/d. Production increased primarily due to the acquired 36.5% interest in the Corrib Natural Gas Project in 2023 and new production from our Mica Montney development, partially offset by the sale of non-core assets in southeast Saskatchewan and natural declines. 2023 vs. 2022 • Consolidated average production of 83,994 boe/d in the year ended December 31, 2023 decreased compared to the prior year comparative period production of 85,187 boe/d. Production decreased primarily due to unplanned downtime in Australia partially offset by increased production in Ireland due to the acquisition of an additional 36.5% interest in the Corrib Natural Gas Project. Production in Canada was relatively flat as growth in the Mica Montney assets offset unplanned downtime due to wildfires in the Deep Basin and the sale of non-core assets in southeast Saskatchewan. Vermilion Energy Inc. ■ Page 21 ■ 2023 Annual Report "Pricing net of derivatives" contains pricing variance on sales volumes (WTI, AECO, Dated Brent & TTF and NBP) and realized derivatives. "Sales volume" is the sum of sales volume variance in all regions. "Other" contains general and administration, interest, realized foreign exchange, and other realized income.$MMCash flows from operating activities and funds flow from operations decreased on lower commodity prices$1,634.9$155.4$144.4$80.0$(633.2)$(180.4)$(58.5)$1,142.6$1,814.2$1,024.5Cash flows from operating activities2022 - FFOTaxesWindfall taxesRoyalties, transportation, operating expensePricing net of derivativesSales volumeOther2023 - FFO1,0001,2001,4001,6001,8002,000 Activity review • • • For the three months ended December 31, 2023, capital expenditures were $142.9 million. In our North America core region, we invested capital expenditures of $58.7 million. In Canada, capital expenditures totaled $53.8 million as we drilled five (5.0 net), completed five (5.0 net), and brought on production four (4.0 net) Mannville liquids rich conventional natural gas wells in the Deep Basin. At Mica we drilled the initial four (4.0 net) Montney liquids-rich shale gas wells on our BC lands as part of our winter drilling program in advance of the expected start-up of our 8-33 BC battery in mid-2024. In Saskatchewan, we completed and brought on production one (1.0 net) light and medium crude oil well. In the United States, $4.9 million was incurred as we participated in the drilling of six (2.0 net) non- operated light and medium crude oil wells in Wyoming. In our International core region, capital expenditures of $84.2 million were invested during Q4 2023. In the Netherlands and France, we invested $10.8 million and $11.2 million, respectively, primarily on facilities and subsurface maintenance activities. In Germany, we invested $33.0 million as we advanced our deep gas exploration and development plans and commenced drilling activities. In Ireland, $11.9 million was invested on our Corrib plant refrigeration project. In Australia, $9.3 million was invested as we preformed routine maintenance and workover activities. In Central and Eastern Europe, $8.0 million was invested on construction for the gas plant on the SA-10 block and site preparation for the upcoming drilling program on the SA-7 block. Financial sustainability review Free cash flow • Free cash flow of $552.4 million decreased by $530.6 million for the year ended December 31, 2023 compared to the prior year period primarily driven by decreased fund flows from operations on lower pricing, lower production and sales volumes, and higher expenditures on drilling and development activities. Long-term debt and net debt • Long-term debt decreased to $0.9 billion as at December 31, 2023 from $1.1 billion as at December 31, 2022 primarily as a result of revolving credit facility repayments of $146.3 million. As at December 31, 2023, net debt decreased to $1.1 billion (December 31, 2022 - $1.3 billion), primarily as a result of revolving credit facility net repayments of $146.3 million, funded by the disposition of our southeast Saskatchewan assets for $182.2 million, and $552.4 million of free cash flow generated during the year, and offset by spend on acquisition activities primarily due to the purchase of an additional 36.5% working interest in our operated Corrib project for $192.4 million (net of cash and working capital deficit acquired). The ratio of net debt to four quarter trailing fund flows from operations(1) increased to 0.9 as at December 31, 2023 (December 31, 2022 - 0.8) primarily due to lower four quarter trailing fund flows from operations on lower prices and lower production. • • (1) Net debt to four quarter trailing fund flows from operations is a supplementary financial measure that does not have a standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other issuers. It is calculated as net debt (capital measure) over the FFO from the preceding four quarters (total of segments measure). The measure is used to assess our ability to repay debt. Vermilion Energy Inc. ■ Page 22 ■ 2023 Annual Report Benchmark Commodity Prices Crude oil WTI ($/bbl) WTI (US $/bbl) Edmonton Sweet index ($/bbl) Edmonton Sweet index (US $/bbl) Saskatchewan LSB index ($/bbl) Saskatchewan LSB index (US $/bbl) Canadian C5+ Condensate index ($/bbl) Canadian C5+ Condensate index (US $/bbl) Dated Brent ($/bbl) Dated Brent (US $/bbl) Natural gas North America AECO 5A ($/mcf) Henry Hub ($/mcf) Henry Hub (US $/mcf) Europe(1) NBP Day Ahead ($/mmbtu) NBP Month Ahead ($/mmbtu) NBP Day Ahead (€/mmbtu) NBP Month Ahead (€/mmbtu) TTF Day Ahead ($/mmbtu) TTF Month Ahead ($/mmbtu) TTF Day Ahead (€/mmbtu) TTF Month Ahead (€/mmbtu) Average exchange rates CDN $/US $ CDN $/Euro Realized prices Crude oil and condensate ($/bbl) NGLs ($/bbl) Natural gas ($/mcf) Total ($/boe) (1) Q4 2023 Q4 2022 Q4/23 vs. Q4/22 2023 2022 2023 vs. 2022 106.67 78.32 99.60 73.13 97.12 71.31 103.83 76.24 114.46 84.05 2.30 3.92 2.88 16.69 18.32 11.38 12.50 17.45 18.51 11.90 12.63 1.36 1.47 112.24 82.65 109.85 80.89 106.05 78.09 113.19 83.35 120.47 88.71 4.64 8.50 6.26 26.09 43.51 18.82 31.38 38.36 49.98 27.67 36.05 1.36 1.39 107.91 33.38 8.48 68.64 115.02 39.93 17.43 103.99 (5)% (5)% (9)% (10)% (8)% (9)% (8)% (9)% (5)% (5)% (50)% (54)% (54)% (36)% (58)% (40)% (60)% (55)% (63)% (57)% (65)% —% 6% (6)% (16)% (51)% (34)% 104.77 77.63 100.37 74.36 97.97 72.59 103.38 76.60 111.51 82.62 2.64 4.00 2.74 16.63 19.85 11.39 13.60 17.40 20.52 11.92 14.06 1.35 1.46 122.62 94.23 120.25 92.41 118.22 90.85 121.96 93.72 131.68 101.19 5.25 8.67 6.66 31.78 41.44 23.21 30.26 48.35 52.59 35.30 38.40 1.30 1.37 102.43 31.54 8.17 67.10 123.89 45.95 18.99 111.95 (15)% (18)% (17)% (20)% (17)% (20)% (15)% (18)% (15)% (18)% (50)% (54)% (59)% (48)% (52)% (51)% (55)% (64)% (61)% (66)% (63)% 4% 7% (17)% (31)% (57)% (40)% NBP and TTF pricing can occur on a day-ahead ("DA") or month-ahead ("MA") basis. DA prices in a period reflect the average current day settled price on the next days' delivery and MA prices in a period represent daily one month futures contract prices which are determined at the end of each month. In a rising price environment, the DA price will tend to be greater than the MA price and vice versa. Natural gas in the Netherlands and Germany is benchmarked to the TTF and production is generally equally split between DA and MA contracts. Natural gas in Ireland is benchmarked to the NBP and is sold on DA contracts. As an internationally diversified producer, we are exposed to a range of commodity prices. In our North America core region, our crude oil is sold at benchmarks linked to WTI (including the Edmonton Sweet index, the Saskatchewan LSB index, and the Canadian C5+ index) and our natural gas is sold at benchmarks linked to the AECO index (in Canada) or the Henry Hub ("HH") index (in the United States). In our International core region, our crude oil is sold with reference to Dated Brent and our natural gas is sold with reference to NBP, TTF, or indices highly correlated to TTF. Vermilion Energy Inc. ■ Page 23 ■ 2023 Annual Report • • • • • • Crude oil prices decreased in Q4 2023 relative to Q4 2022 after US production rose above expectations, which offset price support from improved demand growth and heightened geopolitical risks. Canadian dollar WTI and Brent prices both decreased by 5% in Q4 2023 relative to Q4 2022. In Canadian dollar terms, year-over-year, the Edmonton Sweet differential widened by $4.68/bbl to a discount of $7.07/bbl against WTI, and the Saskatchewan LSB differential widened by $3.36/bbl to a discount of $9.55/bbl against WTI. Approximately 34% of Vermilion’s Q4 2023 crude oil and condensate production was priced at the Dated Brent index, which averaged a premium to WTI of US$5.73/bbl, while the remainder of our crude oil and condensate production was priced at the Saskatchewan LSB, Canadian C5+, Edmonton Sweet, and WTI indices. In Canadian dollar terms, year-over-year, prices for European natural gas linked to NBP and TTF decreased by 36% and 55% respectively on a day-ahead basis. On a month ahead basis, NBP and TTF decreased by 58% and 63% respectively. Prices declined in response to low seasonal and industrial demand in Europe, strong LNG import volumes and historically high storage levels. While prices are off their Q3 2022 highs, they remained elevated compared to historical levels due to lost Russian pipeline supply, global LNG imports competitiveness, and weather related risk premiums. Year-over-year natural gas prices in Canadian dollar terms at NYMEX HH, and AECO decreased by 54% and 50% respectively. Both NYMEX HH and AECO prices declined due to strong production growth, weak seasonal demand and historically high storage levels. For Q4 2023, average European natural gas prices represented a $15.44/mcf premium to AECO. Approximately 41% of our natural gas production in Q4 2023 benefited from this premium European pricing. Vermilion Energy Inc. ■ Page 24 ■ 2023 Annual Report $/bblQ4 2023 realized crude oil and condensate price was a $8.31/bbl premium to Edmonton Sweet IndexDated Brent (34% of Q4 2023 sales volumes)WTI (11% of Q4 2023 sales volumes)Canadian C5+ (14% of Q4 2023 sales volumes)Crude oil and condensate realized priceSaskatchewan LSB (30% of Q4 2023 sales volumes)Edmonton Sweet index (11% of Q4 2023 sales volumes)Q4 2022Q4 2022Q1 2023Q2 2023Q4 202390.00100.00110.00120.00130.00$/mcfQ4 2023 realized natural gas price was a $6.18/mcf premium to AECONBP DA (23% of Q4 2023 sales volumes)TTF DA (18% of Q4 2023 sales volumes)Natural gas realized priceHenry Hub (3% of Q4 2023 sales volumes)AECO (5A) (56% of Q4 2023 sales volumes)Q4 2022Q4 2022Q1 2023Q2 2023Q4 20230.0010.0020.0030.0040.00 North America Production (1) Crude oil and condensate (bbls/d) NGLs (bbls/d) Natural gas (mmcf/d) Total production volume (boe/d) (1) Q4 2023 Q4 2022 2023 2022 18,862 7,412 167.65 54,216 25,291 7,497 154.26 58,499 20,925 7,296 168.22 56,257 24,393 7,961 151.30 57,571 Please refer to Supplemental Table 4 "Production" for disclosure by product type. Sales Royalties Transportation Operating General and administration (1) Corporate income tax expense (1) Fund flows from operations Drilling and development Free cash flow (1) Includes amounts from Corporate segment. Q4 2023 $M 236,969 (36,186) (12,151) (57,368) 4,338 1,164 136,766 (58,704) 78,062 $/boe 47.51 (7.25) (2.44) (11.50) 0.87 0.23 27.42 Q4 2022 $M 360,295 (50,945) (13,014) (72,694) 513 (712) 223,443 (113,892) 109,551 2023 $M $/boe 66.95 1,012,549 (144,998) (9.47) (43,914) (2.42) (256,841) (13.51) (4,267) 0.10 (20) (0.13) 562,509 41.52 (380,200) 182,309 2022 $M $/boe 49.31 1,510,517 (240,432) (7.06) (2.14) (45,467) (268,271) (12.51) (20,651) (0.21) (1,011) — 934,685 27.39 (338,556) 596,129 $/boe 71.88 (11.44) (2.16) (12.77) (0.98) (0.05) 44.48 Production from our North American operations averaged 54,216 boe/d in Q4 2023, a decrease of 4% from the previous quarter due to natural declines in both Canada and the United States. In the Deep Basin, we drilled five (5.0 net), completed five (5.0 net), and brought on production four (4.0 net) Mannville liquids rich conventional natural gas wells. At Mica we drilled the initial four (4.0 net) Montney liquids-rich shale gas wells on our BC lands as part of our winter drilling program in advance of the expected start-up of our 8-33 BC battery in mid-2024. In Saskatchewan, we completed and brought on production one (1.0 net) light and medium crude oil well, while in the United States, we participated in the drilling of six (2.0 net) non-operated light and medium crude oil wells in Wyoming. Sales Canada United States North America Q4 2023 $M 200,102 36,867 236,969 $/boe 44.73 71.65 47.51 Q4 2022 $M 315,897 44,398 360,295 2023 $M $/boe 861,391 65.13 151,158 83.51 66.95 1,012,549 2022 $M $/boe 46.73 1,344,284 166,233 71.97 49.31 1,510,517 $/boe 70.33 87.46 71.88 Sales in North America decreased for the three months and year ended December 31, 2023 versus the comparable prior year periods due to lower realized prices and a decrease in production. Vermilion Energy Inc. ■ Page 25 ■ 2023 Annual Report Royalties Canada United States North America Q4 2023 $M (25,759) (10,427) (36,186) $/boe (5.76) (20.27) (7.25) Q4 2022 $M (38,747) (12,198) (50,945) $/boe (7.99) (22.94) (9.47) 2023 $M (103,511) (41,487) (144,998) $/boe (5.62) (19.75) (7.06) 2022 $M (196,005) (44,427) (240,432) $/boe (10.26) (23.38) (11.44) Royalties in North America decreased on a dollar and per unit basis for the three months and year ended December 31, 2023 versus the comparable prior year periods primarily due to decreased sliding scale royalties on lower commodity prices and lower production. Royalties as a percentage of sales for the three months and year ended December 31, 2023 were 15.3% and 14.3% respectively, compared to the prior year comparative period of 14.1%. and 15.9% respectively. Transportation Canada United States North America Q4 2023 $M (11,701) (450) (12,151) $/boe (2.62) (0.87) (2.44) Q4 2022 $M (12,919) (95) (13,014) $/boe (2.66) (0.18) (2.42) 2023 $M (43,163) (751) (43,914) $/boe (2.34) (0.36) (2.14) 2022 $M (44,849) (618) (45,467) $/boe (2.35) (0.33) (2.16) Transportation expense in North America remained relatively flat on a dollar and per boe basis for the three months and year ended December 31, 2023 versus the comparable prior periods. Operating expense Canada United States North America Q4 2023 $M (51,129) (6,239) (57,368) $/boe (11.43) (12.13) (11.50) Q4 2022 $M (63,305) (9,389) (72,694) $/boe (13.05) (17.66) (13.51) 2023 $M (233,417) (23,424) (256,841) $/boe (12.66) (11.15) (12.51) 2022 $M (240,899) (27,372) (268,271) $/boe (12.60) (14.40) (12.77) Operating expenses in North America decreased on a dollar and per boe basis for the three months and year ended December 31, 2023 compared to the prior year period primarily the disposition of the properties in southeast Saskatchewan in Q1 2023 combined with lower routine maintenance costs in the United States and lower fuel and electricity costs in Canada. Vermilion Energy Inc. ■ Page 26 ■ 2023 Annual Report International Production (1) Crude oil and condensate (bbls/d) Natural gas (mmcf/d) Total production volume (boe/d) Total sales volume (boe/d) (1) Q4 2023 Q4 2022 2023 2022 14,004 116.27 33,381 28,598 13,624 79.97 26,953 29,585 10,802 101.61 27,737 26,330 13,135 86.88 27,616 27,506 Please refer to Supplemental Table 4 "Production" for disclosure by product type. Sales Royalties Transportation Operating General and administration Corporate income tax expense PRRT Fund flows from operations Drilling and development Exploration and evaluation Free cash flow $/boe 108.70 (3.41) (3.91) (22.64) (9.18) (7.81) 7.93 69.68 Q4 2023 $M 286,000 (8,962) (10,290) (59,569) (24,148) (20,538) 20,860 183,353 (73,604) (10,579) 99,170 Q4 2022 $M $/boe 2023 $M 482,398 (17,358) (8,962) (63,553) (13,857) (41,246) (5,045) 332,377 (43,957) (11,456) 276,964 (6.38) (3.29) (23.35) (5.09) (15.15) (1.85) 122.12 177.23 1,010,006 (46,696) (44,942) (256,540) (76,449) (91,912) 20,860 514,327 (188,910) (21,081) 304,336 2022 $M $/boe 105.09 1,965,877 (65,585) (4.86) (33,429) (4.68) (220,763) (26.69) (37,026) (7.95) (207,142) (9.56) 2.17 (18,318) 53.52 1,383,614 (189,500) (23,761) 1,170,353 $/boe 195.81 (6.53) (3.33) (21.99) (3.69) (20.63) (1.82) 137.82 Production from our International operations averaged 33,381 boe/d in Q4 2023, an increase of 29% over the previous quarter primarily due to a full quarter of production at our Australia and Ireland operations following maintenance downtime in the prior quarter, as well as increased production in the Netherlands due to new production from our 2023 drilling program. We continued to advance our deep gas exploration and development plans in Germany, with drilling operations nearly complete on our first well of our program. We expect to reach total depth in the coming weeks and will then move the rig to the next location, where the second well of our program will be drilled during Q2 2024. Sales Australia France Netherlands Germany Ireland Central and Eastern Europe International Q4 2023 $M 36,381 52,472 51,661 44,150 100,430 906 286,000 $/boe 143.69 116.92 102.80 101.18 102.28 109.42 108.70 Q4 2022 $M 95,420 77,910 119,668 121,011 64,753 3,636 482,398 $/boe 139.95 119.68 281.75 218.13 162.16 356.05 177.23 2023 $M 36,381 285,626 186,854 195,481 302,404 3,260 1,010,006 $/boe 143.69 109.47 107.38 104.26 97.24 141.77 105.09 2022 $M 221,187 365,431 562,857 481,260 324,345 10,797 1,965,877 $/boe 148.15 132.90 279.87 231.34 194.05 313.02 195.81 As a result of changes in inventory levels, our sales volumes for crude oil in Australia, France, and Germany may differ from our production volumes in those business units. The following table provides the crude oil sales volumes (consisting entirely of "light crude oil and medium crude oil") for those jurisdictions. Crude oil sales volumes (bbls/d) Australia France Germany International Q4 2023 2,752 4,878 1,472 9,102 Q4 2022 7,411 7,076 1,721 16,208 2023 694 7,149 1,481 9,324 2022 4,090 7,533 1,337 12,960 Vermilion Energy Inc. ■ Page 27 ■ 2023 Annual Report Sales decreased on a dollar and per unit basis for the three months and year ended December 31, 2023 versus the prior year comparable periods due to lower realized prices across all business units combined with lower sales volumes primarily due to downtime in Australia. For the three months ended December 31, 2023, France sales decreased versus the prior year comparable period due to timing of scheduled vessels. Royalties France Netherlands Germany Central and Eastern Europe International Q4 2023 $M (7,150) (692) (736) (384) (8,962) $/boe (15.93) (1.38) (1.69) (46.38) (3.41) Q4 2022 $M (9,294) (512) (6,403) (1,149) (17,358) $/boe (14.28) (1.21) (11.54) (112.51) (6.38) 2023 $M (37,425) (1,567) (5,993) (1,711) (46,696) $/boe (14.34) (0.90) (3.20) (74.41) (4.86) 2022 $M (40,353) (512) (21,232) (3,488) (65,585) $/boe (14.68) (0.25) (10.21) (101.12) (6.53) Royalties in our International core region are primarily incurred in France, Germany and the Netherlands, where royalties include charges based on a percentage of sales and fixed per boe charges. Our production in Australia and Ireland is not subject to royalties. Royalties decreased on a dollar and per unit basis for the three months and year ended December 31, 2023 versus the comparable prior period primarily due to lower pricing, lower sales volumes, and adjustments for prior period royalties in Germany. Transportation France Germany Ireland International Q4 2023 $M (5,745) (3,486) (1,059) (10,290) $/boe (12.80) (7.99) (1.08) (3.91) Q4 2022 $M (4,589) (3,621) (752) (8,962) $/boe (7.05) (6.53) (1.88) (3.29) 2023 $M (24,511) (13,333) (7,098) (44,942) $/boe (9.39) (7.11) (2.28) (4.68) 2022 $M (20,100) (9,751) (3,578) (33,429) $/boe (7.31) (4.69) (2.14) (3.33) Transportation expense increased on a dollar and per unit basis for the three months and year ended December 31, 2023 versus the comparable prior periods primarily due to increased volumes in Ireland on acquisition production, and higher vessel costs in France. In addition to the above, for the year ended December 31, 2023, transportation expenses increased due to tariff adjustments in Germany. Our production in Australia, Netherlands and Central and Eastern Europe is not subject to transportation expense. Vermilion Energy Inc. ■ Page 28 ■ 2023 Annual Report Operating expense Australia France Netherlands Germany Ireland Central and Eastern Europe International Q4 2023 $M (10,677) (17,021) (9,143) (8,233) (13,948) (547) (59,569) $/boe (42.17) (37.93) (18.19) (18.87) (14.20) (66.06) (22.64) Q4 2022 $M (21,291) (12,638) (11,229) (13,292) (4,687) (416) (63,553) $/boe (31.23) (19.41) (26.44) (23.96) (11.74) (40.74) (23.35) 2023 $M (52,360) (80,134) (39,157) (43,857) (39,464) (1,568) (256,540) $/boe (206.80) (30.71) (22.50) (23.39) (12.69) (68.19) (26.69) 2022 $M (57,478) (57,588) (45,903) (41,523) (16,580) (1,691) (220,763) $/boe (38.50) (20.94) (22.82) (19.96) (9.92) (49.03) (21.99) Operating expenses decreased for the three months ended December 31, 2023 primarily due to reduced volume driven costs on lower sales in Australia due to downtime and fuel and electricity savings in Germany, partially offset by increased working interest acquired in Ireland, and higher electricity costs in France. Operating expenses increased for the year ended December 31, 2023 versus the prior comparable periods. On a dollar basis, increases were primarily due to the increased working interest acquired in Ireland, higher electricity costs in France, and increased processing fees in Germany and the Netherlands, partially offset by fuel and electricity savings in Germany and the Netherlands. On a per unit basis, the increase was primarily attributable to the shut-in of our Wandoo platform in Australia for maintenance, resulting in limited production as the platform resumed operations in early September and increased electricity rates in France. Vermilion Energy Inc. ■ Page 29 ■ 2023 Annual Report Consolidated Financial Performance Review ($M except per share) Total assets Long-term debt Petroleum and natural gas sales Net (loss) earnings Net (loss) earnings per share Basic Diluted Cash dividends ($/share) Financial performance Dec 31, 2023 Dec 31, 2022 6,235,821 914,015 2,022,555 (237,587) 6,991,058 1,081,351 3,476,394 1,313,062 Dec 31, 2021 5,905,323 1,651,569 2,079,761 1,148,696 (1.45) (1.45) 0.40 8.03 7.80 0.28 7.13 6.97 — Sales Royalties Transportation Operating General and administration Corporate income tax expense Windfall taxes PRRT Interest expense Realized gain (loss) on derivatives Realized foreign exchange (loss) gain Realized other income (expense) Fund flows from operations Equity based compensation Unrealized gain on derivative instruments (1) Unrealized foreign exchange gain (loss) (1) Accretion Depletion and depreciation Deferred tax recovery (expense) Gain on business combination Loss on disposition Impairment (expense) reversal Unrealized other income (expense) (1) Net (loss) earnings (1) $/boe 111.95 (9.85) (2.54) (15.75) (1.86) (6.70) (7.18) (0.59) (2.67) (13.07) 0.49 0.42 52.65 $/boe 68.64 (5.93) (2.95) (15.35) (2.60) (2.54) (0.03) 2.74 (3.01) 10.33 (0.73) 0.26 48.83 Q4 2023 $M 522,969 (45,148) (22,441) (116,937) (19,810) (19,374) (249) 20,860 (22,909) 78,737 (5,529) 1,948 372,117 (7,871) 141,126 4,834 (19,469) (259,012) 110,758 (5,607) (125,539) (1,016,094) 1,621 (803,136) Q4 2022 $M 842,693 (68,303) (21,976) (136,247) (13,344) (41,958) (222,859) (5,045) (22,506) (43,940) 18,845 (1,140) 284,220 (5,377) 549,693 (47,405) (16,501) (171,926) (196,733) — — — (563) 395,408 2023 $M $/boe 103.99 2,022,555 (191,694) (8.43) (88,856) (2.71) (513,381) (16.81) (80,716) (1.65) (91,932) (5.18) (78,426) (27.50) 20,860 (0.62) (85,212) (2.78) 234,365 (5.42) (4,532) 2.33 (0.14) (420) 35.08 1,142,611 (42,756) 179,707 12,438 (78,187) (712,619) 190,193 439,487 (352,367) (1,016,094) — (237,587) 2022 $M $/boe 67.10 3,476,394 (306,017) (6.36) (2.95) (78,896) (489,034) (17.03) (57,677) (2.68) (208,153) (3.05) (222,859) (2.60) (18,318) 0.69 (82,858) (2.83) (405,894) 7.77 15,195 (0.15) (0.01) 12,982 37.90 1,634,865 (44,390) 540,801 (84,464) (58,170) (577,134) (288,707) — — 192,094 (1,833) 1,313,062 Unrealized gain on derivative instruments, Unrealized foreign exchange gain (loss), and Unrealized other expense are line items from the respective Consolidated Statements of Cash Flows. Fluctuations in fund flows from operations may occur as a result of changes in production levels, commodity prices, and costs to produce petroleum and natural gas. In addition, fund flows from operations may be affected by the timing of crude oil shipments in Australia and France. When crude oil inventory is built up, the related operating expense, royalties, and depletion expense are deferred and carried as inventory on the consolidated balance sheet. When the crude oil inventory is subsequently drawn down, the related expenses are recognized within profit or loss. General and administration • General and administration expense increased for the three months and year ended December 31, 2023 versus the prior year comparable periods primarily due to increased activity and expected cash settlement of previously share-based settled expenses. Vermilion Energy Inc. ■ Page 30 ■ 2023 Annual Report PRRT and corporate income taxes • • PRRT for the three months and year ended December 31, 2023 decreased versus the comparable prior periods due to downtime in Australia resulting in PRRT recoveries from lower taxable income. Corporate income taxes for the three months and year ended December 31, 2023 decreased versus the comparable prior periods primarily due to lower taxable income as a result of decreased commodity prices in 2023. Windfall taxes • Windfall taxes are the temporary taxes levied pursuant to the European Union’s temporary solidarity contribution. The contribution set out minimum amounts to be calculated on taxable profits starting in 2022 and/or 2023, which are above a 20% increase of the average yearly taxable profits for 2018 to 2021. For the two-year period of this policy Vermilion incurred $301 million of incremental taxes. Interest expense • • Interest expense was consistent for the three months ended December 31, 2023 versus the comparable prior period. Interest expense increased for the year ended December 31, 2023 versus the comparable prior period primarily due to an increase in the percentage of our debt with fixed interest rates following the issuance of the 2030 senior unsecured notes, combined with the impact of a weaker Canadian Dollar on US Dollar interest payments. Realized gain or loss on derivatives • • For the three months and year ended December 31, 2023, we recorded realized gains on our natural gas hedges due to lower commodity pricing compared to the strike prices. A listing of derivative positions as at December 31, 2023 is included in “Supplemental Table 2” of this MD&A. Realized other income or expense • In the 2022 periods, realized other income related to amounts for the funding under the Saskatchewan Accelerated Site Closure program. In the 2023 periods, realized other expense included insurance proceeds received related to insurance claims, offset by miscellaneous transaction costs and other provisional charges. Net (loss) earnings Fluctuations in net (loss) earnings from period-to-period are caused by changes in both cash and non-cash based income and charges. Cash based items are reflected in fund flows from operations. Non-cash items include: equity based compensation expense, unrealized gains and losses on derivative instruments, unrealized foreign exchange gains and losses, accretion, depletion and depreciation expense, and deferred taxes. In addition, non-cash items may also include gains resulting from business combinations or charges resulting from impairment or impairment reversals. Equity based compensation Equity based compensation expense relates primarily to non-cash compensation expense attributable to long-term incentives granted to directors, officers, and employees under security-based arrangements. Equity based compensation expense decreased for the year ended December 31, 2023 versus the comparable prior period primarily due to the lower value of LTIP awards outstanding in the current period and lower bonuses under the employee bonus plan in the current period. Unrealized gain or loss on derivative instruments Unrealized gain or loss on derivative instruments arises as a result of changes in forecasts for future prices and rates. As Vermilion uses derivative instruments to manage the commodity price exposure of our future crude oil and natural gas production, we will normally recognize unrealized gains on derivative instruments when future commodity price forecasts decline and vice-versa. As derivative instruments are settled, the unrealized gain or loss previously recognized is reversed, and the settlement results in a realized gain or loss on derivative instruments. For the three months ended December 31, 2023, we recognized a net unrealized gain on derivative instruments of $141.1 million. This consists of unrealized gains of $73.4 million on our European natural gas commodity derivative instruments, $52.8 million on our North American crude oil derivative instruments, $25.9 million on our North American gas commodity derivative instruments and $3.6 million on our USD-to-CAD foreign exchange swaps, partially offset by losses of $14.6 million on our equity swaps. For the year ended December 31, 2023, we recognized a net unrealized gain on derivative instruments of $179.7 million. This consists of unrealized gains of $154.0 million on our European natural gas commodity derivative instruments, $29.2 million on our North American crude oil derivative instruments, $24.7 million on our North American natural gas commodity derivative instruments and $1.7 million on our USD-to-CAD foreign exchange swaps, partially offset by losses of $29.9 million on our equity swaps. Vermilion Energy Inc. ■ Page 31 ■ 2023 Annual Report Unrealized foreign exchange gains or losses As a result of Vermilion’s international operations, Vermilion has monetary assets and liabilities denominated in currencies other than the Canadian dollar. These monetary assets and liabilities include cash, receivables, payables, long-term debt, derivative instruments and intercompany loans. Unrealized foreign exchange gains and losses result from translating these monetary assets and liabilities from their underlying currency to the Canadian dollar. In 2023, unrealized foreign exchange gains and losses primarily resulted from: • The translation of Euro denominated intercompany loans from our international subsidiaries to Vermilion Energy Inc. An appreciation in the Euro against the Canadian dollar will result in an unrealized foreign exchange loss (and vice-versa). Under IFRS, the offsetting foreign exchange loss or gain is recorded as a currency translation adjustment within other comprehensive income. As a result, consolidated comprehensive income reflects the offsetting of these translation adjustments while net (loss) earnings reflects only the parent company's side of the translation. The translation of our USD denominated 2025 senior unsecured notes and USD denominated 2030 senior unsecured notes. • For the three months ended December 31, 2023, we recognized a net unrealized foreign exchange gain of $4.8 million, primarily driven by the effects of the US dollar weakening 2% against the Canadian dollar on our USD senior notes partially offset by the Euro strengthening 2% against the Canadian dollar in Q4 2023 on our intercompany loans. For the year ended December 31, 2023, we recognized a net unrealized foreign exchange gain of $12.4 million, primarily driven by an unrealized gain on our USD senior notes. Accretion Accretion expense is recognized to update the present value of the asset retirement obligation balance. For the three months and year ended December 31, 2023, accretion expense increased versus the comparable prior periods primarily due to the impact of a higher asset retirement obligation balance at December 31, 2023 and the strengthening of the Euro against the Canadian dollar. Depletion and depreciation Depletion and depreciation expense is recognized to allocate the cost of capital assets over the useful life of the respective assets. Depletion and depreciation expense per unit of production is determined for each depletion unit (which are groups of assets within a specific production area that have similar economic lives) by dividing the sum of the net book value of capital assets and future development costs by total proved plus probable reserves. Fluctuations in depletion and depreciation expense are primarily the result of changes in produced crude oil and natural gas volumes, and changes in depletion and depreciation per unit. Fluctuations in depletion and depreciation per unit are the result of changes in reserves, depletable base (net book value of capital assets and future development costs), and relative production mix. Depletion and depreciation on a per boe basis for the three months ended December 31, 2023 of $34.00 increased from $21.22 in the comparable prior period primarily due to higher future development costs increasing the depletable base, lower reserve estimates, and the strengthening of the Euro against the Canadian dollar, partially offset by the southeast Saskatchewan disposition completed at the end of Q1 2023 decreasing the depletable base. Depletion and depreciation on a per boe basis for the year ended December 31, 2023 of $23.64 increased from $18.59 in the comparable prior period primarily due to higher future development costs increasing the depletable base, lower reserve estimates, acquisition activity, and strengthening of the Euro against the Canadian dollar. Deferred tax Deferred tax assets arise when the tax basis of an asset exceeds its accounting basis (known as a deductible temporary difference). Conversely, deferred tax liabilities arise when the tax basis of an asset is less than its accounting basis (known as a taxable temporary difference). Deferred tax assets are recognized only to the extent that it is probable that there are future taxable profits against which the deductible temporary difference can be utilized. Deferred tax assets and liabilities are measured at the enacted or substantively enacted tax rate that is expected to apply when the asset is realized, or the liability is settled. As such, fluctuations in deferred tax expenses and recoveries primarily arise as a result of: changes in the accounting basis of an asset or liability without a corresponding tax basis change (e.g. when derivative assets and liabilities are marked-to-market or when accounting depletion differs from tax depletion), changes in available tax losses (e.g. if they are utilized to offset taxable income), changes in estimated future taxable profits resulting in a derecognition or recognition of deferred tax assets, and changes in enacted or substantively enacted tax rates. For the year ended December 31, 2023, the Company recorded a deferred tax recovery of $190.2 million compared to a deferred tax expense of $288.7 million in the prior year period. The recovery recorded in the current year is primarily attributable to the Q1 2023 disposition of assets in southeast Saskatchewan and the impairment charges recorded in Saskatchewan, France, and United States cash generating units (“CGUs”). Vermilion Energy Inc. ■ Page 32 ■ 2023 Annual Report Gain on business combination On March 31, 2023, Vermilion purchased Equinor Energy Ireland Limited ("EEIL") from Equinor ASA. The acquisition adds an incremental 36.5% interest in the Corrib Natural Gas Project, increasing Vermilion's operated interest to 56.5%. The acquisition makes Vermilion the largest provider of domestic natural gas in Ireland. The gain on the business combination primarily resulted from increases in working capital and the fair value of capital assets from when the purchase and sale agreement was entered into in November 2021 and when the acquisition closed in March 2023. Loss on dispositions In March 2023, Vermilion sold non-core assets in southeast Saskatchewan for net proceeds of $182.2 million. The book value of the net assets disposed of was $409.0 million resulting in a loss on disposition of $226.8 million. In December 2023, Vermilion sold non-core assets in Wyoming for net proceeds of $16.3 million and resulted in a loss on disposition of $125.5 million. The book value of the net assets disposed of was $141.8 million and consisted of $142.5 million of capital assets and $0.7 million of asset retirement obligations. Impairment In the fourth quarter of 2023, indicators of impairment were present in our France CGU due to changes in forecasted cost assumptions and in our Saskatchewan and United States CGUs due to negative technical revisions. As a result of the indicators of impairment, the Company performed impairment calculations on the identified CGUs and the recoverable amounts were determined using fair value less costs to sell, which considered future after-tax cash flows from proved plus probable reserves and an after-tax discount rate of 13.0% for Saskatchewan and 15.0% for France and United States. Based on the results of the impairment tests completed, the Company recognized non-cash impairment charges of $1.0 billion. Inputs used in the measurement of capital assets are not based on observable market data and fall within level 3 of the fair value hierarchy. Vermilion Energy Inc. ■ Page 33 ■ 2023 Annual Report Taxes Current income tax rates Vermilion typically pays corporate income taxes in France, Netherlands, Australia and Germany. In addition, Vermilion pays PRRT in Australia which is a profit based tax applied at a rate of 40% on sales less operating expenses, capital expenditures, and other eligible expenditures. PRRT is deductible in the calculation of taxable income in Australia. For 2023 and 2022, taxable income was subject to corporate income tax at the following statutory rates: Jurisdiction Canada United States France Netherlands (1) Germany Ireland Australia (1) Jurisdiction France (1) Netherlands (2) Germany Ireland (1) 2023 24.4 % 21.0 % 25.8 % 50.0 % 31.2 % 25.0 % 30.0 % 2022 24.6 % 21.0 % 25.8 % 50.0 % 31.3 % 25.0 % 30.0 % 2023 N/A N/A 33.0 % 75.0 % 2022 33.0 % 33.0 % 33.0 % 75.0 % In the Netherlands, an additional 10% uplift deduction is allowed against taxable income that is applied to operating expenses, eligible general and administration expenses, and tax deductions for depletion and abandonment retirement obligations. Windfall Taxes On October 6, 2022 the Council of the European Union adopted a regulation that implemented a temporary windfall tax on the profits of oil and gas producers resident in the European Union. This windfall tax was referred to as a temporary solidarity contribution and was calculated on the amount by which the taxable profits for the elected years exceeded the greater of zero and 120% of the average taxable profits for the 2018 to 2021 period. The regulation required Member States to implement the temporary solidarity contribution at a minimum rate of 33% while providing Member States with the option to apply the temporary solidarity contribution to fiscal years beginning on or after January 1, 2022, January 1, 2023, or both. The windfall tax does not apply to 2024 or later years. The following table summarizes the manner of implementation of the temporary solidarity contribution by the Member States in which Vermilion operates: (2) For 2022, France implemented a windfall tax; however, did not extend for 2023. For 2023 and 2024, Netherlands has implemented a windfall royalty which, for natural gas sales, is calculated as 65% of the excess of the realized price for a subject year versus the threshold price of €0.50/Nm3 (€13.40/mcf). This royalty is deductible against current income taxes. Tax legislation changes In December 2021, the Organization for Economic Co-operation and Development (“OECD”) issued model rules for a new global minimum tax framework (“Pillar Two”). The objective of Pillar Two is to ensure that large multinational enterprises are subjected to a minimum 15% effective tax rate in each jurisdiction in which they operate. Most of the countries where Vermilion operates are in the process of enacting, or have enacted, tax legislation to comply with Pillar Two with effect from January 1, 2024. The Company expects that Pillar Two will not have a material impact on income tax expense. In May 2023, the IASB issued amendments to IAS 12, “Income Taxes” (“IAS 12”) to address the impacts and additional disclosure requirements related to Pillar Two. Vermilion has applied the mandatory exception required by IAS 12 and accordingly has not accounted for any related deferred income tax assets or liabilities. Vermilion Energy Inc. ■ Page 34 ■ 2023 Annual Report Tax pools As at December 31, 2023, we had the following tax pools: (1) ($M) Canada United States France Netherlands Germany Ireland Australia Total (1) Deduction calculated using various declining balance rates. (2) Deduction calculated using a combination of straight-line over the assets life and unit of production method. (3) Deduction calculated using a unit of production method. (4) Tax Losses 1,385,458 154,400 2,461 — — 1,512,603 133,480 3,188,402 Oil & Gas Assets 1,511,948 335,395 255,272 52,905 242,588 — 157,455 2,555,563 (4) (1) (5) (3) (6) (4) (4) (3) (2) (2) Other 28,433 72,309 — — 17,045 — — 117,787 Total 2,925,839 562,104 257,733 52,905 259,633 1,512,603 290,935 5,861,752 (5) (6) Tax losses can be carried forward and applied at 100% against taxable income. Tax losses can be carried forward and are available to offset the first €1 million of taxable income and 50% of taxable profits in excess each taxation year. Tax losses of $49 million created prior to January 1, 2018 are carried forward and applied at 100% against taxable income, tax losses of $105 million created after January 1, 2018 are carried forward and applied to 80% of taxable income in each taxation year. Vermilion Energy Inc. ■ Page 35 ■ 2023 Annual Report Financial Position Review Balance sheet strategy We regularly review whether our forecast of fund flows from operations is sufficient to finance planned capital expenditures, dividends, share buy- backs, and abandonment and reclamation expenditures. To the extent that fund flows from operations forecasts are not expected to be sufficient to fulfill such expenditures, we will evaluate our ability to finance any shortfall by reducing some or all categories of expenditures, with issuances of equity, and/or with debt (including borrowing using the unutilized capacity of our existing revolving credit facility). We have a long-term goal of maintaining a ratio of net debt to four quarter trailing fund flows from operations of approximately 1.0. As at December 31, 2023, we have a ratio of net debt to four quarter trailing fund flows from operations of 0.9. We will continue to monitor for changes in forecasted fund flows from operations and, as appropriate, will adjust our exploration, development capital plans (and associated production targets), and return of capital plans to target optimal debt levels. Maintaining a strong balance sheet is a core principle of Vermilion and will remain a focus going forward. As debt reduction continues, we will plan to increase the amount of free cash flow that is available for the return of capital, while taking into account other capital requirements. Net debt Net debt is reconciled to long-term debt, as follows: ($M) Long-term debt Adjusted working capital deficit (1) Unrealized FX on swapped USD borrowings Net debt As at Dec 31, 2023 914,015 164,552 — 1,078,567 Dec 31, 2022 1,081,351 265,111 (1,876) 1,344,586 0.9 0.8 Ratio of net debt to four quarter trailing fund flows from operations (1) Adjusted working capital is a non-GAAP financial measure that is not standardized under IFRS and may not be comparable to similar measures disclosed by other issuers. It is defined as current assets less current liabilities, excluding current derivatives and current lease liabilities. The measure is used to calculate net debt, a capital measure disclosed above. Reconciliation to the primary financial statement measures can be found in the “Non-GAAP and Other Specified Financial Measures” section of this document. As at December 31, 2023, net debt decreased to $1.1 billion (December 31, 2022 - $1.3 billion), due to debt repayments of $146.3 million funded by the disposition of our southeast Saskatchewan assets for $182.2 million and $552.4 million of free cash flow generated during the year offset by the acquisition of an additional 36.5% working interest in our operated Corrib project for $198.0 million (net of cash and working capital deficit acquired). The ratio of net debt to four quarter trailing fund flows from operations as at December 31, 2023 increased to 0.9 (December 31, 2022 - 0.8) due to lower four quarter trailing fund flows from operations, driven primarily by decreased commodity prices. Long-term debt The balances recognized on our balance sheet are as follows: Revolving credit facility 2025 senior unsecured notes 2030 senior unsecured notes Long-term debt As at Dec 31, 2023 — 395,839 518,176 914,015 Dec 31, 2022 147,666 404,463 529,222 1,081,351 Vermilion Energy Inc. ■ Page 36 ■ 2023 Annual Report Revolving Credit Facility As at December 31, 2023, Vermilion had in place a bank revolving credit facility maturing May 29, 2027 with terms and outstanding positions as follows: ($M) Total facility amount Amount drawn Letters of credit outstanding Unutilized capacity As at Dec 31, 2023 1,600,000 — (18,116) 1,581,884 Dec 31, 2022 1,600,000 (147,666) (13,527) 1,438,807 During the year, the maturity date of the facility was extended to May 28, 2027 (previously May 29, 2026) and the total facility amount of $1.6 billion was unchanged. As at December 31, 2023, there was no draw on the facility. As at December 31, 2023, the revolving credit facility was subject to the following financial covenants: Financial covenant Consolidated total debt to consolidated EBITDA Consolidated total senior debt to consolidated EBITDA Consolidated EBITDA to consolidated interest expense Limit Dec 31, 2023 As at Less than 4.0 Less than 3.5 Greater than 2.5 0.65 — 17.33 Dec 31, 2022 0.51 0.07 27.10 total debt: Includes all amounts classified as “Long-term debt”, “Current portion of Our financial covenants include financial measures defined within our revolving credit facility agreement that are not defined under IFRS. These financial measures are defined by our revolving credit facility agreement as follows: • Consolidated long-term debt”, and “Lease obligations” (including the current portion included within "Accounts payable and accrued liabilities" but excluding operating leases as defined under IAS 17) on our consolidated balance sheet. Consolidated total senior debt: Consolidated total debt excluding unsecured and subordinated debt. Consolidated EBITDA: Consolidated net (loss) earnings before interest, income taxes, depreciation, accretion and certain other non-cash items, adjusted for the impact of the acquisition of a material subsidiary. Total interest expense: Includes all amounts classified as "Interest expense", but excludes interest on operating leases as defined under IAS 17. • • • In addition, our revolving credit facility has provisions relating to our liability management ratings in Alberta and Saskatchewan whereby if our security adjusted liability management ratings fall below specified limits in a province, a portion of the asset retirement obligations are included in the definitions of consolidated total debt and consolidated total senior debt. An event of default occurs if our security adjusted liability management ratings breach additional lower limits for a period greater than 90 days. As of December 31, 2023, Vermilion's liability management ratings were higher than the specified levels, and as such, no amounts relating to asset retirement obligations were included in the calculation of consolidated total debt and consolidated total senior debt. As at December 31, 2023 and December 31, 2022, Vermilion was in compliance with the above covenants. 2025 senior unsecured notes On March 13, 2017, Vermilion issued US $300.0 million of senior unsecured notes at par. The notes bear interest at a rate of 5.625% per annum, paid semi-annually on March 15 and September 15, and mature on March 15, 2025. As direct senior unsecured obligations of Vermilion, the notes rank equally in right of payment with existing and future senior indebtedness of the Company. The senior unsecured notes were recognized at amortized cost and include the transaction costs directly related to the issuance. Subsequent to March 15, 2023, Vermilion may redeem some or all of the senior unsecured notes at a 100.000% redemption price plus any accrued and unpaid interest. Vermilion Energy Inc. ■ Page 37 ■ 2023 Annual Report 2030 senior unsecured notes On April 26, 2022, Vermilion closed a private offering of US $400.0 million 8-year senior unsecured notes. The notes were priced at 99.241% of par, mature on May 1, 2030, and bear interest at a rate of 6.875% per annum. Interest is paid semi-annually on May 1 and November 1, commencing on November 1, 2022. The notes are senior unsecured obligations of Vermilion and rank equally with existing and future senior unsecured indebtedness. The senior unsecured notes were recognized at amortized cost and include the transaction costs directly related to the issuance. Vermilion may, at its option, redeem the notes prior to maturity as follows: • • • On or after May 1, 2025, Vermilion may redeem some or all of the senior unsecured notes at the redemption prices set forth below, together with accrued and unpaid interest. Prior to May 1, 2025, Vermilion may redeem up to 35% of the original principal amount of the notes with an amount of cash not greater than the net cash proceeds of certain equity offerings at a redemption price of 106.875% of the principal amount of the notes, together with accrued and unpaid interest. Prior to May 1, 2025, Vermilion may also redeem some or all of the notes at a price equal to 100% of the principal amount of the notes, plus a “make-whole premium,” together with applicable premium, accrued and unpaid interest. Year 2025 2026 2027 2028 and thereafter Shareholders' capital The following table outlines our dividend payment history: Date January 2003 to December 2007 January 2008 to December 2012 January 2013 to December 2013 January 2014 to March 2018 April 2018 to February 2020 March 2020 April 2022 to July 2022 August 2022 to March 2023 April 2023 onwards Redemption price 103.438 % 102.292 % 101.146 % 100.000 % Frequency Monthly Monthly Monthly Monthly Monthly Monthly Quarterly Quarterly Quarterly Dividend per unit or share $0.170 $0.190 $0.200 $0.215 $0.230 $0.115 $0.060 $0.080 $0.100 In December 2023, we announced our plan to increase the quarterly dividend by 20% to $0.12 per share effective for the planned Q1 2024 distribution. The following table reconciles the change in shareholders’ capital: Shareholders’ Capital Balance at January 1 Vesting of equity based awards Shares issued for equity based compensation Share-settled dividends on vested equity based awards Repurchase of shares Balance at December 31 Shares ('000s) 163,227 3,657 655 64 (5,332) 162,271 Amount 4,243,794 23,575 11,242 1,179 (137,224) 4,142,566 As at December 31, 2023, there were approximately 4.5 million equity based compensation awards outstanding. As at March 6, 2024, there were approximately 160.8 million common shares issued and outstanding. On July 10, 2023, the Toronto Stock Exchange approved our notice of intention to renew our normal course issuer bid ("the NCIB"). The NCIB renewal allows Vermilion to purchase up to 16,308,587 common shares (representing approximately 10% of outstanding common shares) beginning July 12, 2023 and ending July 11, 2024. Common shares purchased under the NCIB will be cancelled. Vermilion Energy Inc. ■ Page 38 ■ 2023 Annual Report In the fourth quarter of 2023, Vermilion purchased 1.7 million common shares under the NCIB for total consideration of $29.0 million. The common shares purchased under the NCIB were cancelled. Contractual Obligations and Commitments As at December 31, 2023, we had the following contractual obligations and commitments: ($M) Long-term debt (1) Lease obligations (2) Processing and transportation agreements Purchase obligations Drilling and service agreements Total contractual obligations and commitments (1) Less than 1 year 1 - 3 years 3 - 5 years After 5 years 58,690 58,034 42,127 32,087 18,572 209,510 480,682 80,281 54,205 13,519 49,784 678,471 72,743 53,839 27,493 2,374 — 156,449 583,597 43,907 151,777 105 — 779,386 Total 1,195,712 236,061 275,602 48,085 68,356 1,823,816 (2) (3) Includes interest on senior unsecured notes. Includes undiscounted IFRS 16 - Leases obligations of $59.7 million recognized in the financial statements as at December 31, 2023, future undiscounted IFRS 16 - Leases due to commence in 2024 of $117.5 million, and surface lease rental commitments of $56.5 million and other of $2.4 million that are not considered leases under IFRS 16 and are not represented on the balance sheet. Commitments denominated in foreign currencies have been translated using the related spot rates on December 31, 2023. Asset Retirement Obligations As at December 31, 2023, asset retirement obligations were $1,159.1 million compared to $1,087.8 million as at December 31, 2022. The increase in asset retirement obligations is primarily attributable to the Company's lower credit spread at December 31, 2023 compared to December 31, 2022 and the acquisition of an additional 36.5% working interest in our Corrib project, partially offset by the disposition of our southeast Saskatchewan assets. The credit spread decreased to 3.6% at December 31, 2023 compared to 4.5% at December 31, 2022 due to a lower expected cost of borrowing. The present value of the obligation is calculated using a credit-adjusted risk-free rate, calculated using a credit spread added to risk-free rates based on long-term, risk-free government bonds. Vermilion's credit spread is determined using the Company's expected cost of borrowing at the end of the reporting period. The risk-free rates and credit spread used as inputs to discount the obligations were as follows: Credit spread added to below noted risk-free rates Country specific risk-free rate Canada United States France Netherlands Germany Ireland Australia 12/31/2023 3.6 % 12/31/2022 4.5 % Change (0.9) % 3.0 % 4.2 % 3.0 % 2.1 % 2.3 % 2.7 % 4.0 % 3.3 % 4.1 % 3.4 % 2.7 % 2.5 % 3.2 % 4.2 % (0.3) % 0.1 % (0.4) % (0.6) % (0.2) % (0.5) % (0.2) % Current cost estimates are inflated to the estimated time of abandonment using inflation rates of between 1.3% and 5.5% (as at December 31, 2022 - between 1.6% and 4.2%). Vermilion Energy Inc. ■ Page 39 ■ 2023 Annual Report Risks and Uncertainties Crude oil and natural gas exploration, production, acquisition and marketing operations involve a number of risks and uncertainties that have affected the financial statements and are reasonably likely to affect them in the future. These risks and uncertainties are discussed further below. Commodity prices Crude oil and natural gas prices have fluctuated significantly in recent years due to supply and demand factors. Changes in crude oil and natural gas prices affect the level of revenue we generate, the amount of proceeds we receive and payments we make on our commodity derivative instruments, and the level of taxes that we pay. In addition, lower crude oil and natural gas prices would reduce the recoverable amount of our capital assets and could result in impairments or impairment reversals. Exchange rates Exchange rate changes impact the Canadian dollar equivalent revenue and costs that we recognize. The majority of our crude oil and condensate revenue stream is priced in US dollars and as such an increase in the strength of the Canadian dollar relative to the US dollar would result in the receipt of fewer Canadian dollars for our revenue. We also incur expenses and capital costs in US dollars, Euros and Australian dollars and thus a decrease in strength of the Canadian dollar relative to those currencies may result in the payment of more Canadian dollars for our expenditures. In addition, exchange rate changes impact the Canadian equivalent carrying balances for our assets and liabilities. For foreign currency denominated monetary assets (such as cash and cash equivalents, long-term debt, and intercompany loans), the impact of changes in exchange rates is recorded in net (loss) earnings as a foreign exchange gain or loss. Production and sales volumes Our production and sales volumes affect the level of revenue we generate and correspondingly the royalties and taxes that we pay. In addition, significant declines in production or sales volumes due to unforeseen circumstances may also result in an indicator of impairment and potential impairment charges. Interest rates Changes in interest rates impact the amount of interest expense we pay on our variable rate debt and also our ability to obtain fixed rate financing in the future. Tax and royalty rates Changes in tax and royalty rates in the jurisdictions that we operate in would impact the amount of current taxes and royalties that we pay. In addition, changes to substantively enacted tax rates would impact the carrying balance of deferred tax assets and liabilities, potentially resulting in a deferred tax recovery or incremental deferred tax expense. Windfall taxes and royalties Vermilion is exposed to increased taxation and royalties due to windfall taxes on profits. Windfall taxes have been substantively enacted within the European Union for oil and gas companies for 2022 and/or 2023 at a minimum rate of 33% calculated on taxable profits above a 20% increase in the average yearly taxable profits as compared to 2018 to 2021. There is risk that windfall taxes or similar mechanisms will be re-enacted or similar legislation could be enacted in other jurisdictions that Vermilion operates in periods of extraordinary commodity prices. Ukraine war / Middle East conflict During 2022, Russian military forces invaded Ukraine resulting in a war between the two countries. The ongoing conflict between countries has impacted the supply of oil and gas from the region and has resulted in countries throughout the world imposing financial and trade sanctions against Russia which have had macroeconomic effects. The risks disclosed in our Annual Information Form for the year ended December 31, 2023 may be exacerbated as a result of the Ukraine war, including: market risks including volatility of oil and gas prices, volatility of foreign exchange rates, volatility of market price of common shares, hedging arrangements; regulatory and political risks including tax, royalty, and other government legislation; financing risks including additional financing, debt service, variations in interest rates and foreign exchange rates; acquisition and expansion risks including international operations and future geographical/industry expansion, acquisition assumptions, failure to realize anticipated benefits of prior acquisitions. In addition to the Ukraine war, hostilities in the Middle East could adversely affect the global economy and impact oil and gas prices. In addition to the above, we are exposed to risk factors that impact our company and business. For further information on these risk factors, please refer to our Annual Information Form, available on SEDAR+ at www.sedarplus.ca or on our website at www.vermilionenergy.com. Vermilion Energy Inc. ■ Page 40 ■ 2023 Annual Report   There has been no change in Vermilion’s internal control over financial reporting during the period covered by this MD&A that materially affected, or is reasonably likely to materially affect, its internal control over financial reporting. Financial Risk Management To mitigate the risks affecting our business whenever possible, we seek to hire personnel with experience in specific areas. In addition, we provide continued training and development to staff to further develop their skills. When appropriate, we use third party consultants with relevant experience to augment our internal capabilities with respect to certain risks. We consider our commodity price risk management program as a form of insurance that protects our cash flow and rate of return. The primary objective of the risk management program is to support our return of capital and internal capital development programs. The level of commodity price risk management that occurs is dependent on the amount of debt that is carried. When debt levels are higher, we will be more active in protecting our cash flow stream through our commodity price risk management strategy. When executing our commodity price risk management programs, we use derivative financial instruments encompassing over-the-counter financial structures as well as fixed and collar structures to economically hedge a part of our physical crude oil and natural gas production. We have strict controls and guidelines in relation to these activities and contract principally with counterparties that have investment grade credit ratings. Critical Accounting Estimates The preparation of financial statements in accordance with IFRS requires us to make estimates. Critical accounting estimates are those accounting estimates that require us to make assumptions about matters that are highly uncertain at the time the estimate is made and a different estimate could have been made in the current period or the estimate could change period-to-period. The carrying amount of asset retirement obligations The carrying amount of asset retirement obligations ($1,159.1 million as at December 31, 2023) is the present value of estimated future costs, discounted from the estimated abandonment date using a credit-adjusted risk-free rate. Estimated future costs are based on our assessment of regulatory requirements and the present condition of our assets. The estimated abandonment date is based on the reserve life of the associated assets. The credit-adjusted risk-free rate is based on prevailing interest rates for the appropriate term, risk-free government bonds adjusted for our estimated credit spread (determined by reference to the trading prices for debt issued by similarly rated independent oil and gas producers, including our own senior unsecured notes). Changes in these estimates would result in a change in the carrying amount of asset retirement obligations and capital assets and, to a significantly lesser degree, future accretion and depletion expense. The estimated abandonment date may change from period to period as the estimated abandonment date changes in response to new information, such as changes in reserve life assumptions or regulations. A one year increase or decrease in the estimated abandonment date would decrease or increase asset retirement obligations (with an offsetting increase to capital assets) by approximately $34.0 million. The estimated credit-adjusted risk-free rate may change from period to period in response to market conditions in Canada and the international jurisdictions that we operate in. A 0.5% increase or decrease in the credit-adjusted risk-free rate would decrease or increase asset retirement obligations by approximately $70.1 million. The fair value of capital assets acquired in business combinations In preparing the purchase price allocation for the business combinations completed in 2023, we estimate the fair value of assets acquired. Assets acquired in an acquisition primarily relates to the crude oil and natural gas reserves. The estimated fair value of the crude oil and natural gas reserves acquired is based on the present value of proved plus probable reserves and forecast commodity prices. Changes in these assumptions, including the discount rate used, would change the amount of capital assets recognized and as a result may cause rise to goodwill or gains recognized on the acquisition and future depletion and depreciation expense. The recognition of deferred tax assets The extent to which deferred tax assets are recognized are based on estimates of future profitability. These estimates are based on estimated future commodity prices and estimates of reserves. As at December 31, 2023, the deferred tax asset balance of $182.1 million relates to Ireland and Canada for $105.3 million and $76.8 million, respectively. In Ireland, we have $237.1 million of non-expiring tax loss pools where $59.3 million of deferred tax assets has not been recognized as there is uncertainty on our ability to fully use these losses based on estimated future taxable profits. Estimated future taxable profits are calculated using proved and probable reserves and forecast pricing. Vermilion Energy Inc. ■ Page 41 ■ 2023 Annual Report In Canada, we have $136.9 million of non-expiring oil and gas tax pools where $33.4 million of deferred tax assets has not been recognized as there is uncertainty on our ability to fully use these pools based on estimated future taxable profits. Estimated future taxable profits are calculated using proved and probable reserves and forecast pricing. Depletion and depreciation Capital assets are grouped into depletion units, which are groups of assets within a specific production area that have similar economic lives. Depletion units represent the lowest level of disaggregation for which costs are accumulated for the purposes of calculating depletion and depreciation. The net carrying value of each depletion unit is depleted using the unit of production method by reference to the ratio of production in the period to the total proved and probable reserves, taking into account the future development costs necessary to bring the applicable reserves into production. Key judgments that are made to reserve estimates such as revisions in reserves, changes in forecast commodity prices, foreign exchange rates, capital or operating costs would impact the amount of depletion and depreciation recorded in a period. The estimated recoverable amount of cash generating units Each reporting period, we assess our CGUs for indicators of impairment or impairment reversal. If an indicator of impairment or impairment reversal is identified, we estimate the recoverable amount of the CGU. Judgment is required when determining whether indicators of impairment or impairment reversal exist, as well as judgments made when determining the recoverable amount of a CGU. Changes in any of the key judgments, such as a revision in reserves, changes in forecast commodity prices, foreign exchange rates, capital or operating costs would impact the estimated recoverable amount. In the fourth quarter of 2023, indicators of impairment were present in our France CGU due to changes in forecasted cost assumptions and in our Saskatchewan and United States CGUs due to negative technical revisions. As a result of the indicators of impairment, the Company performed impairment calculations on the identified CGUs and the recoverable amounts were determined using fair value less costs to sell, which considered future after-tax cash flows from proved plus probable reserves and an after-tax discount rate of 13.0% for Saskatchewan and 15.0% for France and United States. Based on the results of the impairment tests completed, the Company recognized non-cash impairment charges of $1.0 billion. Inputs used in the measurement of capital assets are not based on observable market data and fall within level 3 of the fair value hierarchy. A 1% increase in the assumed after-tax discount rate would reduce the estimated recoverable amount of assets tested and result in a higher impairment of $80.1 million while a 5% decrease in revenues (due to a decrease in commodity price forecasts or reserve estimates) would reduce the estimated recoverable amount of assets tested and result in higher impairment of $187.8 million. Off Balance Sheet Arrangements We have not entered into any guarantee or off balance sheet arrangements that would materially impact our financial position or results of operations. Cybersecurity Vermilion has an information security training and compliance program that is completed at least annually. We have not experienced a cybersecurity breach in the last three years. Recently Adopted Accounting Pronouncements Vermilion did not adopt any new accounting pronouncements as at December 31, 2023. Regulatory Pronouncements Not Yet Adopted Issuance of IFRS Sustainability Standards - IFRS S1 "General Requirements for Disclosure of Sustainability-related Financial Information" and IFRS S2 "Climate-related Disclosures" In June 2023 the International Sustainability Standards Board (ISSB) issued its inaugural standards - IFRS S1 and IFRS S2. The ISSB was formed as a new standard-setting board within the IFRS Foundation to issue standards that deliver a comprehensive global baseline of sustainability-related financial disclosures, operating alongside the International Accounting Standards Board. IFRS S1 and IFRS S2 are effective for annual reporting periods beginning on or after January 1, 2024, with earlier application permitted, as long as both standards are applied. IFRS S1 provides a set of disclosure requirements designed to enable companies to communicate to investors about the sustainability-related risks and opportunities, while IFRS S2 sets out specific climate-related disclosures and is designed to be used in conjunction Vermilion Energy Inc. ■ Page 42 ■ 2023 Annual Report with IFRS S1. Canadian regulators have not yet mandated these standards; however, Vermilion is currently reviewing the impact of the standards on its financial reporting. Health, Safety and Environment We are committed to ensuring we conduct our activities in a manner that protects the health and safety of our employees, our contractors and the public. Our HSE Vision is to consistently apply our core values of Excellence, Trust, Respect and Responsibility. Our goal is to create a workplace free of incidents by ensuring our proactive culture and behaviours create a high-reliability organization where HSE is fully integrated into our business – it is our way of life. Our mantra is HSE: Everyone. Everywhere. Everyday. Vermilion seeks to maintain health, safety and environmental practices and procedures that comply with or exceed regulatory requirements and industry standards. All of our personnel are expected to work safely and in accordance with established regulations and procedures, and we seek to reduce impacts to land, water and air. During 2023 we: • • • Maintained clear priorities around 5 key focus areas of HSE Culture, Communication and Knowledge Management, Management Systems, Environmental & Operational Stewardship, and Health; Completed ongoing HSE performance monitoring through key performance indicator development, analysis and reporting; Continued comprehensive investigations of our incidents and near misses to ensure root causes were identified and corrective actions effectively implemented; • Worked towards fulfilling our updated 2030 HSE Strategy; • • • • Developed a 2023 Top Quartile HSE Performance Plan; Completed Business Unit implementation plans as part of our Process Safety Management System implementation; Continued reinforcement of the “Vermilion High 5”, an individual safety awareness initiative aimed at keeping front-line workers safe; Advanced our Energy Safety Canada and International Oil and Gas Producers Life-Saving Rules implementation and competency development; Submitted our CDP Climate and Water reports; Managed our waste products by reducing, recycling and recovering; Reduced long-term environmental liabilities through decommissioning, abandoning and reclaiming well leases and facilities; Continued the development of a robust hazard identification and risk mitigation program specific to environmentally sensitive areas; Performed auditing, management inspections and workforce observations to measure compliance and identify potential hazards and apply risk reduction measures; and Assessed the effectiveness of our performance management standards across multiple business units. • • • • • • We are a member of several organizations concerned with environment, health and safety, including numerous regional co-operatives and synergy groups. In the area of stakeholder relations, we work to build long-term relationships with environmental stakeholders and communities. Task Force on Climate-related Financial Disclosure (TCFD) Environmental, Social and Governance (ESG) As an international company, Vermilion responsibly produces essential energy while delivering long-term value to our stakeholders. We believe that integrating sustainability principles into our business increases shareholder returns, enhances development opportunities, reduces long-term risks, and supports the well-being of key stakeholders including the communities in which we operate. Vermilion has established a leadership position in sustainability performance and disclosure, launching our first CDP Climate submission and Sustainability Report in 2014, with data to 2012, aligned with the Global Reporting Initiative (GRI). We have since adopted recommendations from the Task Force on Climate-related Financial Disclosure (TCFD), the Sustainability Accounting Standards Board (SASB), and the International Sustainability Standards Board (ISSB). In particular, we have applied the TCFD framework in the management of climate- and other sustainability-related risks and opportunities. This recognizes the importance of climate-specific disclosure while reflecting its intersection with other environment-related risks and opportunities, social factors such as safety and community engagement, and governance issues. Our Index follows: • • • • • Governance Strategy Risk Management Metrics and Targets Consolidated Climate (TCFD) Report www.vermilionenergy.com/sustainability/reports/ Information Circular Annual Report MD&A Annual Report MD&A Annual Report MD&A Vermilion Energy Inc. ■ Page 43 ■ 2023 Annual Report Sustainability and Climate-Related Strategy Vermilion understands our stakeholders’ expectations that we deliver strong financial results in a responsible and ethical way. As a result, we align our strategic priorities in the following order: • • • the safety and health of our staff and those involved directly or indirectly in our operations; our responsibility to protect the environment. We follow the Precautionary Principle introduced in 1992 by the United Nations "Rio Declaration on Environment and Development" by using environmental risk as part of our development decision criteria, and by continually seeking improved environmental performance in our operations; and economic success through a focus on operational excellence across our business, which includes technical and process excellence, efficiency, expertise, stakeholder relations, and respectful and fair treatment of staff, contractors, partners and suppliers. Reflecting these priorities, we have positioned Vermilion purposefully within the energy transition. Our scenario analysis has consistently demonstrated that Vermilion can best contribute by focusing on producing energy responsibly: safely, reliably and cost-effectively. Our Sustainability Report provides further details at: www.vermilionenergy.com/sustainability. Description of Sustainability- and Climate-related Risks and Opportunities, and Impacts Given the intersection of environmental and social issues, and their impact over varying timeframes, we have identified climate-related risks and opportunities within short-term (0-3 years), medium-term (3-6 years) and long-term (6-50 years) horizons. We describe these below, along with their potential company and financial impact (assessed using processes such as scenario analysis, cost projections and our Emissions Long-Range Planning tool), and our resulting management approach, including operations such as equipment upgrade, and capital allocation. Our annual CDP Climate Change and Water Security submissions provide additional information, including where in the value chain these risks and opportunities occur: see www.vermilionenergy.com/sustainability/reports/. Category / Issue Policy and Legal: Increased Pricing of GHG Emissions e.g. Carbon Tax Description of Impacts Potential Financial Impact Management Approach Short-term Transition Risks (0-3 Years) Short-term impact is primarily in Canada and Ireland. Canadian Federal Greenhouse Gas Pollution Pricing Act has set carbon tax rates at $65 per tCO2e in 2023, rising to $170 by 2030, with provincial responses to keep pace with the federal system. Our Ireland operations are subject to the EU ETS and Ireland Carbon Tax systems. Longer-term impact rests on carbon pricing’s vulnerability to changes in government policy. With our recent northeast British Columbia acquisition, our Canadian carbon tax liability is forecast at approximately $1.6MM in the near term. Our Ireland EU ETS liability is forecast at approximately $2.6MM in 2025 and $3.5MM in 2030. The Ireland Carbon Tax liability is expected to be an additional approximately $0.1MM/year over this period. All estimates are net Vermilion. Our exposure is mitigated by provincial responses to the Act, including Alberta's Technology Innovation and Emissions Reduction (TIER) regulation and Output-Based Pricing Systems (OBPS) in Saskatchewan and forthcoming in British Columbia. Our ongoing efforts to reduce the energy and emissions intensity of our operations are integral to managing this risk, including our emission reduction targets. Vermilion continues to monitor and comply with taxation requirements. Policy and Legal: Enhanced Emissions & Other ESG Reporting Obligations Climate and other ESG reporting obligations are evolving rapidly, with Vermilion potentially subject to the IFRS Sustainability Standards (2025) and European Sustainability Reporting Standards (2028), U.S. Securities and Exchange Commission and Canadian Securities Administrators Climate-Related Disclosure Rules, and Canada's Modern Slavery Act. Although Vermilion's existing sustainability- related disclosure provides a sound foundation for compliance, there are costs to implement these, particularly potential requirements for increased levels of audit. The impact to Vermilion would be a decreased netback per BOE, due to increased expenses for staff time and system development and implementation. The financial impact is an increase in operational cost associated with the management and quantification of emissions to meet new reporting requirements, and the administrative costs associated with reporting and audit obligations. This is estimated at $0.8MM annually. Regulations in all of our business units are monitored on an ongoing basis, and assumptions/ scenario planning is used annually to assess risk. In Canada, we implemented an external emission data gathering software in 2021 to support the evolving regulatory landscape. Vermilion also engages stakeholders relating to emissions reporting obligations. Management of this risk is built into Vermilion's operations and our ERM. In addition, we expect to automate our emissions data gathering, aggregation and calculation processes in 2024, while ensuring audit-ready processes for all ESG data points to align with proposed regulatory requirements. Vermilion Energy Inc. ■ Page 44 ■ 2023 Annual Report Vermilion is closely monitoring regulatory and market changes to ensure its approach to resilience under evolving conditions remains appropriate. We provide feedback to governments on proposed regulations, as per our lobbying disclosures, and allocate resources, including staff and capital, to ensure that required operational changes can be effectively actioned. In the short term, tying in vented equipment to flaring infrastructure in Canada is an example of projects to address this risk; in Netherlands we have used NOx scrubbers and purchased NOx certificates to comply with new regulations. Our ongoing efforts to proactively reduce the energy and emissions intensity of our operations are integral to managing this risk, including our announcement of two emission reduction targets in 2021, and our work in 2023 to establish a net zero transition plan and 2030 emissions reduction target, which we expect to release in 2024. We are also working with external partners to further implement and develop emission reduction technologies that are economic to the Company, in part due to the potential generation of carbon credits. Based on stakeholder engagement, Vermilion believes that independent assessments of our operations by third parties are an important tool to demonstrate our responsible approach to production of essential energy. As a result, we have sought and achieved Equitable Origin responsible gas producer certification for 4 of our Canadian sites, the AFNOR CSR Committed label in France, and the Business Working Responsibly mark in Ireland. In addition to our net zero transition plan development, we have set public targets to reduce ARO liabilities and internal targets to maintain freshwater intensity performance via water management plans where higher-intensity freshwater use is, or could become, an issue. We are also prioritizing compliance with incoming sustainability reporting requirements, which are largely investor- and financial institution-driven, and are actively engaging with investors to understand and respond to their concerns. We implemented our Non-technical Risk Management Policy and framework in 2023, providing guidelines for community/social impact assessments, along with our well-established strategic community investment program, Ways of Caring. We also implemented our Lobbying policy in 2023, guiding our engagement with governments, including on specific issues such as windfall tax. Description of Impacts Potential Financial Impact Management Approach Category / Issue Policy and Legal: Changes in Mandates/ Regulations re Products - Existing Production or Acquisition Impaired by Regulatory or Political Changes Operational changes to comply with existing methane reduction regulations are expected at approx. $1.5MM in the short term, with those associated with eliminating routine flaring in France subject to continuing review in 2024. The cost of compliance with proposed regulations, such as Canada's proposed regulatory framework for reducing oil and gas methane emissions to achieve a 75% reduction by 2030 is not yet established, and will depend on the final version of the framework. Vermilion's operations are subject to regional regulatory changes that result in changes to equipment requirements such as engineering and equipment modifications to reduce carbon emissions and / or emissions of criteria air contaminants. The most likely short-term impact is regulations in Canada to reduce methane emissions, in France to reduce flaring and in Netherlands to reduce NOx. From a macro perspective, geopolitical impacts (e.g. war in Ukraine) have escalated diverging government and consumer viewpoints on the need for energy security vs energy transition. We expect demand for oil and natural gas to remain strong in the short term, while safety and environmental regulations governing its production will increase. We have identified these risks as interconnected and existing in the short-term; however, they should be seen as medium- to long-term risks as well. Reputation: Shareholder Divestment Investors are raising concerns regarding risks related to emissions, environmental and biodiversity protection, water stewardship, and abandonment and reclamation liabilities. Impact of divestment is estimated to be equal to 0.25X of 2023E FFO reducing market capitalization by $286MM. This estimate covers all significant sustainability risk scenarios including but not limited to water stewardship, biodiversity, modern slavery, and community relations. Reputation: Changes in Customer Behaviour and Legal Challenges Government and community relationships are strongly linked to both social and regulatory licenses to operate. Communities where we operate also bear potential impacts, including noise, dust, lights, traffic, etc. Legal challenges against oil and gas industry are increasing, while adoption of EVs and opposition to fossil fuels reflects customer sentiment in some areas. Windfall tax/solidarity contributions are possible during times of particularly high commodity prices. The impact of delays or shutdowns would be measured in terms of production per day, impacting revenues. The impact of the 2022-2023 EU windfall tax is already decreasing, to $78MM in 2023 under lower commodity pricing, with the EU signalling that it will not be extended. Medium-term Transition Risks (3-6 Years) Technology Our emission reduction projects and net zero transition plan rely on technologies that are rapidly evolving, but in many cases unproven at larger scales and uneconomic for dispersed assets that are not, for example, near an electrical grid or pipeline gathering system. Assumptions by those outside the industry that broad generalizations on methane reduction are economical for all assets may be proven false. Some technology projects will fail; others will prove uneconomic. Based on the capital and/or operating spend required to reduce our near-term carbon tax liability through emission reduction projects, this will be calculated as part of the net zero transition plan. We are mitigating this risk through a careful and deliberate approach to new technology adoption. We have established sustainability project criteria that need to be met in order to move into the Vermilion Opportunity Development Process, providing various stage gates and off-ramps. Vermilion Energy Inc. ■ Page 45 ■ 2023 Annual Report Category / Issue Market: Increased costs related to capital and financing Description of Impacts Potential Financial Impact Management Approach Pressure from stakeholders to limit access to, or increase the cost of, debt, capital or insurance without the use of sustainability-linked financing arrangements A 100 bps increase to total debt would represent $10MM We have established 2 emission reduction targets and 1 ARO target, and are developing our net zero transition plan and 2030 emission reduction target, which establish the foundation for sustainability- linked financing should it be required. Vermilion maintains insurance as a mitigative measure to reduce the financial impact associated with damage to our assets due to severe weather events. We also have a robust asset integrity program that maintains our offshore facilities to their original design specifications of CAT 5 hurricane force. We also have protocols for monitoring and preparing for cyclones, and have invested in our emergency response capabilities in the event of damage to our assets due to severe weather. Based on our scenario analysis, we identified the need to explore new and evolving technologies and processes to identify synergistic fits for our business in both traditional and renewable energy production. We are pursuing this via our established track record in geothermal energy from produced water, for which our internal expertise in engineering, geoscience and drilling is particularly well suited. We are also investing in early R&D in other areas, such as biogas and the conversion of traditional oil and gas assets to geothermal and hydrogen production, to better understand the long-term potential. Each of our assets is assessed for potential risks and hazards, including those associated with weather events, from lightning to flooding to wild fires. These risks are reviewed at least annually on a case-by-case basis as part of our Enterprise Risk Management system. Mitigation approaches such as clearance of vegetation around facilities, and physical barriers to flooding, are implemented as per our HSE Management System, to protect the health and safety of our workers, contractors and the public, and to protect the environment. Medium-term Physical Risks (3-6 Years) Acute: Increased Severity of Extreme Weather Events such as Cyclones and Floods Vermilion's Wandoo field off northwestern Australia, Corrib project off the Irish coast and oil fields in the coastal area of SW France can be impacted by extreme weather events such as cyclones, resulting in down time or damage to infrastructure. Such events can also impact the downstream handling capacity of our partners, resulting in a limitation to the distribution and sale of our products. Based on the value of the Wandoo Platform and a 1- in-10,000-year cyclonic event, the financial implications associated with damage due to a severe weather event is estimated at $274MM (total impact before insurance). The third-party costs associated with potential damages from extreme weather events are not tracked. Long-term Transition Risks (6-50 Years) Technology: Substitution of existing products and services with lower emissions options, including market supply and demand Although we see demand for oil and natural gas remaining robust in the short- to mid-term, it is likely that demand for oil and, to a lesser degree, natural gas will eventually fall as the energy transition evolves and various alternatives for renewable energy options become technologically and economically available. This could impact the need for our products in the longer term, post 2030 for oil and even further out for natural gas. As the past several years have demonstrated, it will be critical to maintain adequate supplies of both oil and natural gas during the energy transition, to provide both accessibility and affordability. Given the uncertain timeline and progression of the energy transition, and supply-demand dynamics, we are not using a financial forecast for impact. We are, however, using our scenario analysis to identify potential opportunities that would mitigate the risk to our products. Long-term Physical Risks (6-50 Years) The financial implications of a single time event (i.e. wildfire) have been assessed on a case-specific basis. Vermilion maintains insurance to mitigate the potential impact of precipitation-related extreme events (i.e. Wild fire, Flooding) Chronic: Changes in Temperature Extremes, Including Rising Mean Temperatures; Changes In Precipitation Patterns and Extreme Variability in Weather Patterns Chronic Physical: Based on RCP4.5, which limits warming to 3C (overshooting 1.5-2C), our assets and operations could experience climate changes between 2041 and 2070 such as: North America: 2-3C increase, 12-14% increased precipitation, 7-8% increased aridity, >10 fewer frost days and <25% decrease in number of dry spells. Europe: 1-2C increase, 0-5% increased precipitation, 4-12% increased aridity, generally decreased frost days, with several areas seeing <25% increase in number of dry spells. Australia: 1C increase; 8% increased precipitation (SMHI, Climate Information, https:// climateinformation.org/, last accessed: 9 July 2023). Overall warming temperatures, greater precipitation and generally drier conditions (due to increased evaporation) may increase capital costs for drilling, completion and workover operations due to increased timelines, equipment breakdown and restricted access in North America (fewer frost days). They may also impact the health and safety of workers, and create variability and potentially more severe weather events such as flooding, drought and wild fires. Flooding could result in limited access to locations; droughts could impact the availability of surface and / or groundwater required for drilling and completion. This could negatively impact growth by increasing timelines and capital costs to bring on new production. Chronic: Rising Sea Levels Chronic Physical: Potential rising sea levels could impact our Netherlands assets and operations due to issues such as flooding, transportation difficulties, supply chain interruptions and salinization of groundwater. We have estimated that a rise in sea level could have a financial impact of $571MM before insurance at our main gas processing facility Garijp (GTC) in the Netherlands, caused by an extreme 1-in-10000- years tide/extreme wind event. Physical measures such as conventional berms may not provide complete protection. Based on Vermilion's assessment of less than 0.05% probability over the next 5 years we have accepted this level of risk, reviewing it annually. Vermilion Energy Inc. ■ Page 46 ■ 2023 Annual Report Category / Issue Products and Services, and Resilience: Development of New Products and Services through R&D and Innovation; participation in renewable energy programs Products and Services: Access to New Markets Products and Services: Ability to Diversify Business Activities; Shift in Consumer Preferences Description of Impacts Potential Financial Impact Management Approach Short-term Opportunities (0-3 Years) Directly related to the long-term transitional risk associated with the substitution of low-carbon products, we have the opportunity to participate in the development of those products. This has the potential to reuse our current infrastructure to provide alternative products, such as biogas or hydrogen, or to develop new products such as geothermal energy, creating new revenue streams. As this opportunity is in the early stage of assessment, it is difficult to quantify the financial impact, but it is estimated at up to $2.0MM per year in revenue and returns on investment. Potential also exists for significant cost adjustments, as assets slated for abandonment would be repurposed to enable them to continue to generate energy. More stringent global measures to reduce emissions from individual ships by 30% by 2030, established through amendments to MARPOL Annex VI, came into force on Jan 1 2020, limiting the sulphur content of bunker fuel to a maximum of 0.5%. Vermilion’s Australian Wandoo facility produces 4500 bbl/d of low sulphur crude oil that meets the needs of refineries in the short term to meet IMO regulations. Vermilion conservatively foresees achieving a premium of $10/bbl for its Wandoo production over the next three years for cumulative incremental revenue of $49.3MM. Medium-term Opportunities (3-6 Years) We are leveraging our technical experts and partnerships to provide input into alternative and renewable energy projects as they are identified. An example of the development of low emission goods/ services is our France-based industry partnership with Avenia to expand the use of geothermal energy production in oil production, and a geothermal association in Germany. We have also developed criteria for approving the move of these ideas into our Vermilion Opportunity Development Process, which provides clear gates and criteria for considering and implementing such projects. Vermilion continues to access local markets for our low sulphur production, while exploring regions to expand our operations. Our Marketing group ensures that Vermilion meets its contractual obligation with our buyers in terms of volumes, delivery dates and crude quality. Vermilion maintains a diverse, stable global portfolio of oil and gas assets. Our strong record of safe and socially conscious development of energy resources has provided opportunities to access and develop these resources. We see our commitment to sustainability as core to our business, which has provided important organizational focus on emissions quantification and management. As consumers become more aware of and involved in the selection of their energy sources and associated carbon intensity, we believe that Vermilion will continue to be a top quartile choice, providing us with opportunities not available to peer organizations. The financial impact of changing consumer preferences in difficult to quantify. We foresee revenue opportunities in two distinct areas. (1) In consumers selecting premium energy products, with these products demanding a higher price than other energy sources on the market; commodity pricing volatility now makes this difficult to estimate (2) Access to more stringent markets, supported by our environmental and sustainability performance. Vermilion has entered into German, Hungarian, Croatian and Slovak oil and gas operations, which our sustainability performance has supported. Based on stakeholder engagement, Vermilion believes that independent assessments of our operations by third parties are an important tool to demonstrate our responsible approach to production of essential energy, and generate premium. As a result, we have sought and achieved Equitable Origin responsible gas producer certification for 4 of our Canadian sites, the AFNOR CSR Committed label in France, and the Business Working Responsibly Mark in Ireland. We are currently assessing the potential to expand these certifications. Long-term Opportunities (6-50 Years) Products and Services: Shift in Consumer Preferences Under the Canadian Environmental Protection Act and based on commitments made by the Canadian and Alberta governments and energy utilities relating to COP21, there is a commitment to reduce emissions for coal-fired power generation. Based on this and with a number of power generating facilities in Alberta nearing the end of their service life, the demand for natural gas is likely to increase due to increased use of combined cycle gas turbine (CCGT) power generation. The short term impact of this regulatory change on gas pricing is anticipated to be low and increase to medium in the mid- to long-term. As a natural gas and oil producer, Vermilion would benefit from an increase in marketable prices for natural gas in our Canadian operations. Energy Source: Shift Toward Decentralized Energy Generation The carbon intensity of energy used around the world has a direct relationship to where the energy product was generated. Vermilion’s business unit structure supports production and distribution of energy products into local markets. This strategy results in the significant reduction of the carbon footprint of our energy when compared to non-local sources. The long-term financial impact of decentralized energy generation will depend on the speed of the energy transition balanced against the need for energy security. As such, we believe it is not possible to predict the financial impact at this time. As we move further into the energy transition, we foresee natural gas playing an impactful role as a less carbon intense fuel than other options (i.e. coal). Vermilion continues to focus on the identification of resources and assets where we have the opportunity to apply our industry leading expertise to optimize production while reducing emissions. An example of our strategy to realize this opportunity is our asset base in Alberta, which currently includes a large liquids rich gas play, and our entry into the Montney in northeast British Columbia. Vermilion's marketing team is also actively pursuing options for our natural gas production that will enable Vermilion to achieve the best netbacks on production. Vermilion continues to assess where we can access local markets for our production, while exploring regions to expand our operations. The actions taken in the past several years to realize this opportunity include alterations to our structure, our strategic objectives and our operational development plans to support Vermilion as a distributed energy provider, and exploration and development programs in regions with relatively low energy production as compared to consumption. Resilience of the Company’s Strategy Countries in all of our operating regions are implementing policies to create a low-carbon future for the world’s economy, consistent with a 1.5-2C or lower scenario. As a global energy producer, we contribute to the supply of safe, reliable and affordable energy during this transition. The Board of Directors and senior leadership therefore responded to our risk and opportunity identification using a robust scenario analysis. Vermilion Energy Inc. ■ Page 47 ■ 2023 Annual Report Vermilion initially examined two energy transition scenarios from the World Economic Forum. These compared a Gradual versus Rapid low-carbon transition based on inputs that included the International Energy Agency’s New Policies Scenario (Gradual) and Sustainable Development Scenario (Rapid), which meets the Paris Agreement’s goal to limit global temperature increases to 1.5 to 2ºC. Vermilion examined key factors impacting the speed of the transition – including the influence of new energy technologies; potential speed of their adoption; anticipated changes in policy and regulation; and emerging market pathways such as India – and resulting factors that could impact the company, including economics (demand, supply, consumer behaviour, and costs of energy); technological advancement; capital availability; government policy; and Company reputation. Among these, government policy was seen as most influential in the near to mid-term. We applied these findings to Vermilion’s strategy to 2050 and beyond, described below. In particular, the scenario analysis led us to develop two emission-related targets that were announced in 2021: an aspirational commitment to net zero emissions in our own operations, including Scope 1 and Scope 2 emissions, by 2050, and a near-term target to reduce Scope 1 emissions intensity from our operations by 15 to 20% by 2025, using a baseline year of 2019. See Metrics and Targets, below, for more information. In 2023, we augmented this work with a new analysis of both climate-related transition risks and physical risks. It should be noted that these scenarios are neither predictions nor forecasts; while they rely on the work of credible third-party organizations, they are constructions based on circumstances and assumptions that are highly vulnerable to macroeconomic and geopolitical changes. We have used them to inform our discussions on short, mid- and long-term business strategy, along with risk identification and management. In our scenario analysis, our Executive Committee and Board of Directors reviewed an internally developed comparison of a diverse range of climate-related transition scenarios. We focused on changes in demand for oil and for natural gas based on a Reference (business as usual) case and a Climate Policy (government support for reduced greenhouse gas emissions) case for Global, Advanced Economy and Emerging Economy scenarios. Specific scenarios included the International Energy Agency (Stated Policy, Announced Pledges and Net Zero), Equinor (Walls, Bridges), and BP (New Momentum, Accelerated), with reference cases from Exxon, OPEC and the Energy Information Administration. The analysis showed the potential for energy demand declines over a 5- to 15-year horizon, but also showed greater impacts on specific assets based on government policies, location and logistics (landlocked vs waterborne), and proximity to petrochemical or carbon capture and sequestration capacities. For example, our analysis for the Reference case in advanced economies points to strong policy uptake in Europe and Industrialized Asia, as well as energy efficiency improvements in the residential and commercial sectors. Oil demand declines as energy transition policy momentum pushes road transport towards electrification, which is further displaced by biofuels after 2030. Efficiency gains reduce consumption, while demographic trends work against oil demand. Climate Policy scenarios see advanced economies driving a rapid uptake of renewables to a near full phase-out of combustible natural gas use, leading to a finale in the role of natural gas as a transition fuel. Natural gas use in 2050 is mostly consumed by the petrochemical sector and for hydrogen production. Both scenarios rely on assumptions such as a continued improvement in advanced technology development for renewables (for example, battery improvement); and the addressing of supply chain human rights and environmental issues for critical minerals. We also assessed the physical climate-related risks in each of our major operating regions using the International Panel on Climate Change’s Representative Concentration Pathway (RCP) 4.5 scenario. We selected RCP 4.5 because it reflects the physical risks our operations would face if CO2 emissions do not start declining until approximately 2045, reaching approximately half of 2050 levels by the end of the century. This is more likely than not to result in rising global temperatures above 2C; specific geographic scenarios are summarized above in the Risks table. While we have set emission reduction targets that are significantly more ambitious than this, using RCP 4.5 enabled us to identify impacts to operations such as rising temperatures, aridity and dry spells in many areas, rising precipitation in some areas, and rising sea levels. Since climate volatility would also increase, RCP 4.5 highlights the need to consider adaptation and mitigation tactics including changing work schedules for daily heat cycles, along with greater wind, storm and wildfire protection for our assets. We note that RCP 2.6 (which requires CO2 emissions to have started declining by 2020) relies not only on reducing emissions, but also on removing significant amounts of greenhouse gases from the atmosphere, and reflects similar physical risks as 4.5 in the next 10-15 years, with lesser effects in the period 2050-2100. We incorporated the results of the discussions around these scenarios into our business strategy work in 2023, including working on our net zero transition plan (see Targets and Metric section) and our Risk identification and management process. Vermilion Energy Inc. ■ Page 48 ■ 2023 Annual Report Overall, our strategy to ensure our resilience under various scenarios continues to rest on three strategic activities: • Focusing on efficient and responsible production of oil and natural gas, viewing emissions as potential energy sources: ◦ ◦ ◦ Lower carbon fuels. Since 2012, we have shifted our production mix towards natural gas as a cleaner burning fuel than other fossil fuels. We also sell our fuels within the country of production wherever possible, reducing the carbon footprint associated with transportation of the fuel to consumers while increasing national energy security. Socially responsible fuels. We are committed to ensuring that our products are produced in an environmentally and socially responsible manner, respecting worker rights and community engagement. We operate in regions noted for their stable, well- developed fiscal and regulatory policies related to oil and gas exploration and development, and for their robust health, safety, environmental and human rights legislation. Transparency and reporting. We have established a strong record of reporting on greenhouse gas emissions, energy usage and other key environmental metrics, which has supported our emission reduction targets. • • Implementing technically and economically feasible options for emission reduction, covering combustion, flaring, venting and fugitive emissions: ◦ ◦ Greater energy efficiency. Many energy and operational efficiency initiatives go hand-in-hand, which in turn helps us minimize our carbon footprint and reduce greenhouse gas emissions. Lower greenhouse gas emission intensity. We are committed to reducing the greenhouse gas emissions associated with our production, with particular focus on methane. Exploring new and evolving technologies and processes to identify synergistic fits for our business in both traditional and renewable energy production: ◦ Alternative energy. We are continuing to develop our knowledge and use of alternative energy sources, including geothermal energy, for which our internal expertise in engineering, geoscience and drilling is particularly well suited. This work has begun with the geothermal potential of our produced water, supporting a circular economy model that conserves, reuses and recycles resources to better protect our environment. It is also expanding into areas such as biogas and the conversion of traditional oil and gas assets to geothermal and hydrogen production. In addition, we identified two further pillars of our sustainability strategy that are integral to managing sustainability- and climate-related issues: Conservation We are committed to reducing the impact our operations have, beginning with regulatory compliance across all business units. Our conservation efforts are further focused in three areas: • Water: We recognize water as a basic human right, and as a vital resource that is shared among many stakeholders in our communities. We are therefore committed to protecting both the supply and the quality of water sources in our areas of operation by: ◦ ◦ ◦ Proactively preventing harm and supporting healthy surface and groundwater bodies Reducing potable and freshwater usage to the lowest level practical, and Taking a lifecycle and circular economy approach to water, exploring opportunities to reuse and recycle products such as produced water • • Asset Retirement Obligations: We are adapting our long-term Asset Retirement Obligation management to include revitalizing or reusing assets to benefit our environment and our communities. Biodiversity: We are focusing on protecting the species and habitats around us by proactively identifying biodiversity risks and opportunities, and implementing associated plans. Community Our communities comprise a wide diversity of people and organizations, but they have one key thing in common: they care deeply about the safety, environmental stewardship and corporate citizenship that we bring to our local operations. In addition, our people care deeply about their communities - whether we work there or live there, these are the places we call home. We therefore steward our operations and relationships to demonstrate our commitment to being a responsible producer and a valued and trusted neighbor and business partner, including: • • • Transparency with respect to safe and environmentally responsible operations, including our potential impacts on local communities Maintaining strong, genuine relationships with our communities, with engagement based on respect, listening and openness, and Creating a shared value focused on local economic and social development Vermilion Energy Inc. ■ Page 49 ■ 2023 Annual Report Sustainability and Climate-Related Risk Management Process for Identifying, Assessing and Managing Sustainability- and Climate-related Risks, and Integration into the Company’s Enterprise Risk Management (ERM) System Sustainability-related risks and opportunities, including those related to climate, are integrated into multi-disciplinary Company-wide risk identification, assessment, and management processes as part of our ERM system, based on the Committee of Sponsoring Organizations of the Treadway Commission (COSO) framework. This provides an integrated approach to managing risk as it impacts strategy and performance, and includes Operational, Market & Financial, Credit, Organizational, Political, Regulatory Compliance, Strategic and Reputational, and Sustainability categories. Risk management is the responsibility of the Board and the Executive Committee based on a Top-Down, Bottom-Up approach to engage all staff. Top-Down begins with our Board and its committees with clear terms of reference, including oversight for identification and management of specific allocations of risk type. This is translated into action by our Executive Committee, which reviews and manages the ERM process through implementation of associated policies and procedures. Within our Executive Committee, the Vice President International and HSE and the Vice President North America have risk management responsibility on an operational level, while the Chief Financial Officer is responsible for overseeing risk management performance. Our staff help develop systems, standards and procedures. Bottom-Up is how staff implement, maintain and improve risk management processes, applying the hazard-risk-mitigation process in every part of our business. Risks are identified by key staff across our Company, including our Operations, Finance, Health, Safety and Environment, Economics, Government and Public Relations, and Sustainability teams at corporate, business unit and asset levels. These employees have significant experience, and use a wide array of inputs, including operational and facility assessments, technical and research reports, external stakeholder organizations, government policy and regulation changes, industry initiatives, communities and landowners, and non-governmental entities. The results are incorporated into our Corporate Risk Register, which provides a consistent framework to ensure the effective tracking and communication of our material risks. Using our Risk Matrix as a prioritization tool, teams assess severity, likelihood, speed of onset, and vulnerability using scales from 1 to 5 for each factor, described in terms of human, environment, financial, social license and cybersecurity impacts. In addition, risks such as commodity pricing, production and carbon taxes are stress-tested to identify the impact of changes over time. Our sustainability materiality analysis, which assesses issues with impact for both the Company and our key stakeholders, is integrated into our ERM system using the Corporate Risk Register through a collaboration between Finance, HSE, Operations and Sustainability teams. Every risk case includes whether climate-related risk is a contributing factor. The results are reviewed annually at minimum by the responsible teams, and provided to the Executive Committee and the Board and its Committees as appropriate, who further review and assess the risks including interdependencies based on the company’s risk tolerance. Our risk management approach focuses on reducing the risk to a level as low as reasonably practicable, accepting the risk, and/or controlling it (such as insuring it). For example, if direct mitigation is not possible (e.g. changes in temperature extremes), we would adapt our business processes to reduce the potential impact (e.g. changing work hours to avoid extreme mid-day heat). In other situations (e.g. increasing risk of flood), we may take measures to protect against the risk (e.g. flood controls) while also insuring our operations. Financial impact is deemed substantive if it could cause a business loss of more than $10 million CAD (unrisked and before mitigation/recovery instruments). To support climate risk identification and management, we use our internally developed Emissions Long-Range Planning Tool. This is based on our long-range planning tool for production, and allows us to forecast emissions, carbon taxes and the impact of various emission reduction projects. This supports our decision-making on production, capital allocation, budgeting, target setting, and merger, acquisition and divestment decisions. Sustainability and Climate-Related Metrics and Targets Metrics Used to Assess Sustainability- and Climate-Related Risks and Opportunities Our sustainability reporting (www.vermilionenergy.com/sustainability) describes significant economic, environmental, social and governance measures, which are reported with reference to TCFD, SASB and GRI. These include but are not limited to: • • • • Climate: energy consumption and intensity; investment in and generation of renewable energy; greenhouse gas emission and intensity, including flaring and venting, and avoided emissions; and water withdrawal, including from areas of high baseline water stress, and discharge. Environment: Waste generation and management; Asset integrity and spills; and Environmental investment Social: Health and Safety; People; and Community investment Governance: Ethics Vermilion Energy Inc. ■ Page 50 ■ 2023 Annual Report These metrics contribute to a sustainability contribution of 10% of the Corporate Performance Scorecard for our Long-term Incentive Plan, comprised of progress towards our 2025 emission intensity reduction target (5%) and 2027 ARO liability reduction target (3%), along with select ESG rating agency scores (2%). We also track carbon pricing, and have identified actual and likely pricing scenarios for all of our operations based on current government policies and published research relating to the Paris Agreement. For example, in Canada, the 2023 carbon tax was $65 per tCO2e, and in Ireland, carbon pricing was 56.00€ per tCO2e. Further information is available in our CDP Climate submission, available at vermilionenergy.com/sustainability/ reports/. In addition, we benchmark our performance via third-party ESG rating agencies, including: • • • • CDP Climate Change and Water Security: Note that while we continue to submit these questionnaires, as of 2023 we no longer participate in the scoring process. In 2022, we received a Climate Score of A- and Water score of “B”. ISS ESG QualityScore: Decile rating of “1” for Environmental and "2" for Social practices as of March 2024. MSCI ESG Rating: AAA in 2023. S&P Global Corporate Sustainability Assessment: Top of our peer group in 2023. Scope 1, 2 and 3 GHG Emissions Disclosure We report Scopes 1, 2 and 3 emissions, which are externally verified under ISO 14064-3. Historical, corporate and business unit data can be found in the Energy and Emissions Performance Metric document available at www.vermilionenergy.com/sustainability/, summarized in the charts below. The 2018 increase in emissions was associated with the acquisition of southeast Saskatchewan assets. Our Scope 1 and 2 emissions intensity and methane emissions intensity decreased in 2019 and 2020, primarily related to our first full year of operatorship for the Corrib gas asset in Ireland, and our focus on reducing post-acquisition emissions over time through superior operations, as we did in 2014 to 2017 following the acquisition of previous Saskatchewan assets. This has been achieved through a variety of gas conservation and recovery initiatives including construction of new infrastructure, operational changes and increased infrastructure runtimes. Additional decreases have been achieved through improved measurement and methodologies, projects such as replacing diesel or propane with compressed natural gas for boilers and water heating for the drilling program in Alberta, converting pneumatic devices from high- to low-bleed, installing solar-powered chemical injection pumps, and the purchase of renewable energy certificates for electricity use in Netherlands and Ireland. Emissions intensity flattened and methane intensity increased in 2022 as a result of lower production; however, our Scope 1 emissions intensity continued to decrease in 2022, to 0.017 t/CO2e, reflecting a 10% decrease from our 2019 baseline of 0.019 t/CO2e and on track to our 2025 target (see below). Related Targets and Performance Vermilion has set two emission-related targets: • • Net zero emissions in our own operations, including Scope 1 and Scope 2 emissions, by 2050. We are transparent that this is an aspirational goal, and that we will build the plan to achieve this target over time. As a first step, we set a near-term target to reduce Scope 1 emissions intensity from our operations by 15 to 20% by 2025, using a baseline year of 2019. We intend to set new targets every five years at minimum, building on this foundation while exploring broader options, including the potential to reduce Scope 3 emissions. We developed, and the Board approved, these targets following our climate scenario analysis and extensive internal assessment. There are significant inherent uncertainties in how the energy transition will accelerate over the next three decades. Our intention is to manage these by focusing on responsible production of essential oil and natural gas for as long as these forms of energy are needed, while developing opportunities in other areas that are an economic and synergistic fit for our business. Vermilion Energy Inc. ■ Page 51 ■ 2023 Annual Report tCO2e per BOEEmissions Intensity Scope 1&2 tCO2e per BOE2014201520162017201820192020202120220.0150.0200.0250.0300.035tCO2e per BOEMethane Intensity tCO2e per BOE2014201520162017201820192020202120220.0000.0020.0040.0060.0080.0100.012 Committing to an aspirational net zero target was important, but setting a company-wide nearer term target as the first step in creating a clear pathway was even more so. We looked at our own operations – from how we manage emissions data to options for emission reduction – and at how our peers and the majors are approaching this. From this, we identified emissions intensities and opportunities for reduction within our business units, and set our 2025 target. This is being achieved, starting with our business units with higher emissions intensities, with an initial focus on efficiency, including process changes, venting reductions, instrumentation upgrades from gas to air and power efficiency options, along with improved metering and field measurements. All of these factors are also being considered as we worked on our Net Zero Transition Plan through 2023. Based on our scenario analyses, we have identified four key pillars to support both a Net Zero by 2050 target for Scope 1 and 2 emissions, and the establishment of our mid-term 2030 Scope and 2 emission intensity reduction target: • • • • Reduce emissions, with methane a priority, by reducing flaring, venting and fugitive emissions; driving operational and energy efficiencies; electrifying operations where grids are low-intensity; and assessing new technologies as they become viable. Convert higher emitting elements of our portfolio to lower intensity production, considering both divestment and end-of-life fields. Adapt our portfolio to new energy, considering carbon capture and storage, renewable energy associated with our core operations such as biogas, hydrogen and geothermal production, and other new technologies. Offset as a solution for the emissions that cannot be eliminated. We anticipate that our plan will be complete in 2024, and that it will constitute a living document - one that will be updated as economic, technological and regulatory landscapes evolve. For more information on our sustainability- and climate-related performance, please see our 2023 Proxy Statement and Information Circular, online sustainability reporting, particularly the Index and Performance Metrics sections, and 2022 CDP Responses. Corporate Governance We are committed to a high standard of corporate governance practices, a dedication that begins at the Board level and extends throughout the Company. We believe good corporate governance is in the best interest of our shareholders, and that successful companies are those that deliver growth and a competitive return along with a commitment to the environment, to the communities where they operate, and to their employees. We comply with the objectives and guidelines relating to corporate governance adopted by the Canadian Securities Administrators and the Toronto Stock Exchange ("TSX"). In addition, the Board monitors and considers the implementation of corporate governance standards proposed by various regulatory and non-regulatory authorities in Canada. A discussion of corporate governance policies is included each year in our proxy materials for our annual general meeting of shareholders, copies of which are available on SEDAR+ (www.sedarplus.ca). As a Canadian reporting issuer with securities listed on the TSX and the New York Stock Exchange (“NYSE”), Vermilion is required to comply with all applicable Canadian requirements adopted by the Canadian Securities Administrators and the TSX, and applicable rules for foreign private issuers adopted by the U.S. Securities and Exchange Commission that give effect to the provisions of the Sarbanes-Oxley Act of 2002. Our corporate governance practices also incorporate many “best practices” derived from those required to be followed by US domestic companies under the NYSE listing standards. We are required by Section 303A.11 of the NYSE Listed Company Manual to identify any significant ways in which our corporate governance practices differ from those required to be followed by US domestic companies under NYSE listing standards. We believe that there are no such significant differences in our corporate governance practices, except as follows: • Shareholder Approval of Equity Compensation Plans. Section 303A.8 of the NYSE Listed Company Manual requires shareholder approval of all “equity compensation plans” and material revisions to those plans. The definition of “equity compensation plans” covers plans that provide for the delivery of newly issued securities, and also plans which rely on securities reacquired on the market by the issuing company for the purpose of redistribution to employees and directors. The TSX rules provide that equity compensation plans and material amendments thereto require shareholder approval only if they involve newly issued securities and the amendments are not otherwise addressed in the plan’s amendment procedures. In addition, the TSX rules require that every three years after institution, all unallocated options, rights or other entitlements under equity compensation plans which do not have a fixed maximum aggregate of securities issuable must be approved by shareholders. Vermilion follows the TSX rules with respect to equity compensation plan shareholder approval requirements. Vermilion Energy Inc. ■ Page 52 ■ 2023 Annual Report Disclosure Controls and Procedures Our officers have established and maintained disclosure controls and procedures and evaluated the effectiveness of these controls in conjunction with our filings. As of December 31, 2023, we have evaluated the effectiveness of the design and operation of our disclosure controls and procedures. Based on this evaluation, the Chief Executive Officer and the Chief Financial Officer have concluded and certified that our disclosure controls and procedures are effective. Internal Control Over Financial Reporting A company's internal control over financial reporting is a process to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements. The Chief Executive Officer and the Chief Financial Officer of Vermilion have assessed the effectiveness of Vermilion’s internal control over financial reporting as defined in Rule 13a-15 under the US Securities Exchange Act of 1934 and as defined in Canada by National Instrument 52-109, Certification of Disclosure in Issuers’ Annual and Interim Filings. The assessment was based on the framework in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Chief Executive Officer and the Chief Financial Officer of Vermilion have concluded that Vermilion’s internal control over financial reporting was effective as of December 31, 2023. The effectiveness of Vermilion’s internal control over financial reporting as of December 31, 2023 has been audited by Deloitte LLP, as reflected in their report included in the 2023 audited annual financial statements filed with the US Securities and Exchange Commission. No changes were made to Vermilion’s internal control over financial reporting during the year ended December 31, 2023, that have materially affected, or are reasonably likely to materially affect, the internal controls over financial reporting. Vermilion has limited the scope of design controls and procedures ("DC&P") and internal controls over financial reporting to exclude controls, policies and procedures of Equinor Energy Ireland Limited, which was acquired on March 31, 2023. The scope limitation is in accordance with section 3.3(1)(b) of NI 52-109 which allows an issuer to limit the design of DC&P and ICFR to exclude controls, policies, and procedures of a business that the issuer acquired not more than 365 days before the end of the fiscal period. The tables below present the summary financial information of Equinor Energy Ireland Limited included in Vermilion's financial statements as at and for the year ended December 31, 2023: ($M) Non-current assets Non-current liabilities Net assets ($M) Revenue net of royalties Net earnings As at Dec 31, 2023 705,276 91,954 552,688 Year Ended Dec 31, 2023 161,663 43,581 Vermilion Energy Inc. ■ Page 53 ■ 2023 Annual Report Supplemental Table 1: Netbacks The following table includes financial statement information on a per unit basis by business unit. Liquids includes crude oil, condensate, and NGLs. Natural gas sales volumes have been converted on a basis of six thousand cubic feet of natural gas to one barrel of oil equivalent. Canada Sales Royalties Transportation Operating Operating netback General and administration Fund flows from operations ($/boe) United States Sales Royalties Transportation Operating Operating netback General and administration Fund flows from operations ($/boe) France Sales Royalties Transportation Operating Operating netback General and administration Current income taxes Fund flows from operations ($/boe) Netherlands Sales Royalties Transportation Operating Operating netback General and administration Current income taxes Fund flows from operations ($/boe) Germany Sales Royalties Transportation Operating Operating netback General and administration Current income taxes Fund flows from operations ($/boe) Liquids $/bbl 79.86 (12.93) (4.28) (20.41) 42.24 88.71 (25.00) (1.13) (15.01) 47.57 116.92 (15.93) (12.80) (37.93) 50.26 106.81 — — (18.90) 87.91 110.62 3.33 (14.56) (20.63) 78.76 Q4 2023 Natural Gas $/mcf 2.65 0.02 (0.21) (0.68) 1.78 2.04 (0.63) — (0.35) 1.06 — — — — — 17.12 (0.23) — (3.03) 13.86 16.16 (0.66) (0.84) (3.01) 11.65 Total $/boe 44.73 (5.76) (2.62) (11.43) 24.92 (5.65) 19.27 71.65 (20.27) (0.87) (12.13) 38.38 (5.26) 33.12 116.92 (15.93) (12.80) (37.93) 50.26 (13.91) (13.12) 23.23 102.80 (1.38) — (18.19) 83.23 (1.15) (37.33) 44.75 101.18 (1.69) (7.99) (18.87) 72.63 (9.16) 5.78 69.25 Liquids $/bbl 79.92 (12.06) (3.57) (21.66) 42.63 87.49 (23.80) (0.45) (13.56) 49.68 109.47 (14.34) (9.39) (30.71) 55.03 83.23 — — (17.44) 65.79 106.03 (2.34) (14.39) (23.79) 65.51 2023 Natural Gas $/mcf 2.91 0.01 (0.21) (0.79) 1.92 2.31 (0.77) — (0.36) 1.18 — — — — — 17.96 (0.15) — (3.76) 14.05 17.26 (0.59) (0.69) (3.87) 12.11 Total $/boe 46.73 (5.62) (2.34) (12.66) 26.11 (5.22) 20.89 71.97 (19.75) (0.36) (11.15) 40.71 (4.63) 36.08 109.47 (14.34) (9.39) (30.71) 55.03 (7.91) (5.49) 41.63 107.38 (0.90) — (22.50) 83.98 (4.78) (27.78) 51.42 104.26 (3.20) (7.11) (23.39) 70.56 (6.99) (15.22) 48.35 Q4 2022 Total $/boe 2022 Total $/boe 65.13 (7.99) (2.66) (13.05) 41.43 (1.37) 40.06 83.51 (22.94) (0.18) (17.66) 42.73 (4.28) 38.45 70.33 (10.26) (2.35) (12.60) 45.12 (1.50) 43.62 87.46 (23.38) (0.33) (14.40) 49.35 (3.08) 46.27 119.68 132.90 (14.28) (7.05) (19.41) 78.94 (7.73) (7.69) 63.52 281.75 (1.21) — (26.44) 254.10 (4.75) (86.02) 163.33 218.13 (11.54) (6.53) (23.96) 176.10 (5.36) (3.53) 167.21 (14.68) (7.31) (20.94) 89.97 (5.98) (10.87) 73.12 279.87 (0.25) — (22.82) 256.80 (2.12) (74.91) 179.77 231.34 (10.21) (4.69) (19.96) 196.48 (3.34) (15.15) 177.99 Vermilion Energy Inc. ■ Page 54 ■ 2023 Annual Report   Ireland Sales Transportation Operating Operating netback General and administration Current income taxes Fund flows from operations ($/boe) Australia Sales Operating PRRT (2) Operating netback General and administration Current income taxes Fund flows from operations ($/boe) Total Company Sales Realized hedging gain (loss) Royalties Transportation Operating PRRT (2) Operating netback General and administration Interest expense Realized foreign exchange gain (loss) Other (expense) income Corporate income taxes Windfall taxes Fund flows from operations ($/boe) Liquids $/bbl — — — — 143.69 (42.17) 82.39 183.91 92.51 0.78 (13.08) (5.16) (20.69) 6.39 60.75 Q4 2023 Natural Gas $/mcf 17.05 (0.18) (2.37) 14.50 — — — — 8.46 2.92 (0.09) (0.21) (1.89) — 9.19 Total $/boe 102.28 (1.08) (14.20) 87.00 (9.25) (0.33) 77.42 143.69 (42.17) 82.39 183.91 (9.91) 7.60 181.60 68.64 10.33 (5.93) (2.95) (15.35) 2.74 57.48 (2.60) (3.01) (0.73) 0.26 (2.54) (0.03) 48.83 Liquids $/bbl — — — — 2023 Natural Gas $/mcf 16.21 (0.38) (2.11) 13.72 143.69 (206.80) 82.39 19.28 — — — — 88.62 0.48 (13.28) (4.66) (22.49) 1.52 50.19 8.18 2.31 (0.09) (0.25) (2.08) — 8.07 Total $/boe 97.24 (2.28) (12.69) 82.27 (6.13) (0.23) 75.91 143.69 (206.80) 82.39 19.28 (32.32) 0.05 (12.99) 67.10 7.77 (6.36) (2.95) (17.03) 0.69 49.22 (2.68) (2.83) (0.15) (0.01) (3.05) (2.60) 37.90 Q4 2022 Total $/boe 2022 Total $/boe 162.16 194.05 (1.88) (11.74) (2.14) (9.92) 148.54 181.99 (0.78) — 0.07 — 147.76 182.06 139.95 (31.23) (7.40) 101.32 (2.93) 3.47 101.86 103.99 (5.42) (8.43) (2.71) (16.81) (0.62) 70.00 (1.65) (2.78) 2.33 (0.14) (5.18) (27.50) 35.08 148.15 (38.50) (12.27) 97.38 (3.32) 3.36 97.42 111.95 (13.07) (9.85) (2.54) (15.75) (0.59) 70.15 (1.86) (2.67) 0.49 0.42 (6.70) (7.18) 52.65 (1) Vermilion considers Australian PRRT to be an operating item and, accordingly, has included PRRT in the calculation of operating netbacks. Current income taxes presented above excludes PRRT. Vermilion Energy Inc. ■ Page 55 ■ 2023 Annual Report Supplemental Table 2: Hedges The prices in these tables may represent the weighted averages for several contracts with foreign currency amounts translated to the disclosure currency using forward rates as at the month-end date. The weighted average price for the portfolio of options listed below may not have the same payoff profile as the individual contracts. As such, the presentation of the weighted average prices is purely for indicative purposes. The following tables outline Vermilion’s outstanding risk management positions as at December 31, 2023: Daily Bought Put Volume Weighted Average Bought Put Price Daily Sold Call Volume Weighted Average Sold Call Price Daily Sold Put Volume Weighted Average Sold Put Price Daily Sold Swap Volume Weighted Average Sold Swap Price Daily Bought Swap Volume Weighted Average Bought Swap Price Unit Currency bbl bbl bbl mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf USD USD USD CAD CAD CAD CAD CAD CAD CAD CAD CAD CAD CAD CAD USD USD USD USD USD USD USD USD USD USD USD USD — — — 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 20,000 20,000 20,000 20,000 24,000 24,000 24,000 24,000 24,000 24,000 24,000 24,000 — — — 3.17 3.17 3.17 3.17 3.17 3.17 3.17 3.17 3.17 3.17 3.17 3.17 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 — — — 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 20,000 20,000 20,000 20,000 24,000 24,000 24,000 24,000 24,000 24,000 24,000 24,000 — — — 4.22 4.22 4.22 4.22 4.22 4.22 4.22 4.22 4.22 4.22 4.22 4.22 4.45 4.45 4.45 4.45 4.49 4.49 4.49 4.49 4.49 4.49 4.49 4.49 — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — 12,500 9,500 9,500 4,739 19,904 19,904 9,849 23,695 23,695 23,695 23,695 23,695 23,695 23,695 23,695 4,000 4,000 4,000 4,000 — — — — — — — — 79.00 80.11 80.11 3.69 3.14 3.14 3.31 3.89 3.89 3.89 3.89 3.89 3.89 3.89 3.89 3.51 3.51 3.51 3.51 — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — WTI Q1 2024 Q2 2024 Q3 2024 AECO Q1 2024 Q2 2024 Q3 2024 Q4 2024 Q1 2025 Q2 2025 Q3 2025 Q4 2025 Q1 2026 Q2 2026 Q3 2026 Q4 2026 NYMEX Henry Hub Q1 2024 Q2 2024 Q3 2024 Q4 2024 Q1 2025 Q2 2025 Q3 2025 Q4 2025 Q1 2026 Q2 2026 Q3 2026 Q4 2026 Vermilion Energy Inc. ■ Page 56 ■ 2023 Annual Report Daily Bought Put Volume Weighted Average Bought Put Price Daily Sold Call Volume Weighted Average Sold Call Price Daily Sold Put Volume Weighted Average Sold Put Price Daily Sold Swap Volume Weighted Average Sold Swap Price Daily Bought Swap Volume Weighted Average Bought Swap Price Unit Currency mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf EUR EUR EUR EUR EUR EUR EUR EUR EUR EUR EUR EUR EUR EUR mcf EUR mcf mcf mcf mcf EUR EUR EUR EUR 4,913 41.03 4,913 84.26 — — 35,623 7,278 7,278 4,913 4,913 — — — — — — — — — — — — — 37.85 25.96 25.96 13.19 13.19 — — — — — — — — — — — — — 35,623 7,278 7,278 4,913 4,913 — — — — — — — — — — — — — 71.90 45.76 45.76 18.32 18.32 — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — 2,457 2,457 7,370 30,709 30,709 34,394 34,394 17,197 17,197 12,284 12,284 9,827 9,827 — 14.65 14.65 41.19 14.08 14.08 15.13 15.13 14.40 14.40 13.51 13.51 9.67 9.67 — 22,111 (0.26) — — — — 2,457 2,457 2,457 2,457 14.95 14.95 14.95 14.95 — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — Jan 2020 - Apr 2025 Jan 2020 - Jul 2025 Initial Share Price Share Volume 20.9788 CAD 22.4587 CAD 2,250,000 1,500,000 NBP Q1 2024 Q2 2024 Q3 2024 TTF Q1 2024 Q2 2024 Q3 2024 Q4 2024 Q1 2025 Q2 2025 Q3 2025 Q4 2025 Q1 2026 Q2 2026 Q3 2026 Buy TTF, Sell NBP Basis Q1 2024 THE Q4 2024 Q1 2025 Q2 2025 Q3 2025 VET Equity Swaps Swap Swap Foreign Exchange Collar Forward Monthly Bought Put Amount Weighted Average Bought Put Price Monthly Sold Call Amount Weighted Average Sold Call Price Monthly Sold Swap Amount Weighted Average Sold Swap Price Jan 2024 - Dec 2024 4,000,000 USD 1.3600 4,000,000 USD 1.3963 — Jan 2024 - Dec 2024 — — — — 4,000,000 USD — 1.3531 The following sold option instruments allow the counterparties, at the specified date, to enter into a derivative instrument contract with Vermilion at the detailed terms: Period if Option Exercised Unit Currency WTI Option Expiration Date Daily Bought Put Volume Weighted Average Bought Put Price Daily Sold Call Volume Weighted Average Sold Call Price Daily Sold Put Volume Weighted Average Sold Put Price Daily Sold Swap Volume Weighted Average Sold Swap Price Oct 2024 - Sep 2025 bbl USD 29-Mar-2024 — — — — — — 1,000 80.00 Vermilion Energy Inc. ■ Page 57 ■ 2023 Annual Report Supplemental Table 3: Capital Expenditures and Acquisitions By classification ($M) Drilling and development Exploration and evaluation Capital expenditures Acquisitions, net of cash acquired Acquisition of securities Acquired working capital deficit Acquisitions Dispositions ($M) Canada United States Total dispositions By category ($M) Drilling, completion, new well equip and tie-in, workovers and recompletions Production equipment and facilities Seismic, studies, land and other Capital expenditures Acquisitions Total capital expenditures and acquisitions Capital expenditures by country ($M) Canada United States France Netherlands Germany Ireland Australia Central and Eastern Europe Total capital expenditures Acquisitions by country ($M) Canada United States Netherlands Germany Ireland Acquisitions Q4 2023 132,308 10,579 142,887 Q4 2022 157,849 11,456 169,305 2023 569,110 21,081 590,191 2022 528,056 23,761 551,817 2,669 17,448 5,607 25,724 3,594 964 — 4,558 142,281 21,603 109,134 273,018 510,309 23,282 6,122 539,713 Q4 2023 Q4 2022 — 14,855 14,855 Q4 2023 68,285 76,937 (2,335) 142,887 25,724 168,611 Q4 2023 53,791 4,913 11,217 10,787 33,046 11,850 9,331 7,952 142,887 — — Q4 2022 112,755 49,286 7,264 169,305 4,558 173,863 Q4 2022 111,483 2,409 15,704 14,232 10,089 1,323 5,753 8,312 169,305 Q4 2023 Q4 2022 20,117 — — — 5,607 25,724 1,985 — — (11) 2,584 4,558 2023 182,152 14,855 197,007 2022 — — 2022 2023 418,284 373,304 105,722 198,331 27,811 18,556 551,817 590,191 273,018 539,713 863,209 1,091,530 2023 288,223 91,977 48,297 44,147 59,711 20,283 26,005 11,548 590,191 2023 71,185 3,808 — — 198,025 273,018 2022 275,203 63,353 44,252 21,652 26,157 3,030 95,173 22,997 551,817 2022 531,348 1,075 707 3,857 2,726 539,713 Vermilion Energy Inc. ■ Page 58 ■ 2023 Annual Report Supplemental Table 4: Production Canada Light and medium crude oil (bbls/d) Condensate (1) (bbls/d) Other NGLs (1) (bbls/d) NGLs (bbls/d) Conventional natural gas (mmcf/d) Total (boe/d) United States Light and medium crude oil (bbls/d) Condensate (1) (bbls/d) Other NGLs (1) (bbls/d) NGLs (bbls/d) Conventional natural gas (mmcf/d) Total (boe/d) France Light and medium crude oil (bbls/d) Total (boe/d) Netherlands Light and medium crude oil (bbls/d) Condensate (1) (bbls/d) NGLs (bbls/d) Conventional natural gas (mmcf/d) Total (boe/d) Germany Light and medium crude oil (bbls/d) Conventional natural gas (mmcf/d) Total (boe/d) Ireland Conventional natural gas (mmcf/d) Total (boe/d) Australia Central and Eastern Europe Conventional natural gas (mmcf/d) Total (boe/d) Consolidated Light and medium crude oil (bbls/d) Condensate (1) (bbls/d) Other NGLs (1) (bbls/d) NGLs (bbls/d) Conventional natural gas (mmcf/d) Total (boe/d) Q4/23 Q3/23 Q2/23 Q1/23 Q4/22 Q3/22 Q2/22 Q1/22 Q4/21 Q3/21 Q2/21 Q1/21 11,614 12,054 12,901 16,674 17,448 16,835 17,042 15,980 16,388 16,809 16,868 17,767 4,034 6,281 10,315 160.16 48,623 4,410 6,219 10,629 163.94 50,007 3,506 5,513 9,019 159.26 48,464 4,719 6,875 11,594 160.34 54,991 4,525 6,279 10,804 146.81 52,720 4,204 6,870 4,873 7,155 4,892 7,286 4,785 7,073 4,426 6,862 5,558 7,767 4,556 7,016 11,074 12,028 12,178 11,858 11,288 13,325 11,572 145.04 143.94 140.55 128.85 138.42 146.55 138.41 52,080 53,060 51,584 49,720 51,168 54,618 52,407 3,187 4,404 3,349 2,824 3,282 2,824 2,846 2,675 2,647 3,520 1,888 2,322 27 1,131 1,158 7.49 5,593 7,395 7,395 — 119 119 32.06 5,462 1,775 19.62 5,046 15 1,124 1,139 7.25 6,751 7,578 7,578 — 39 39 24.32 4,091 1,713 20.29 5,095 22 1,025 1,047 7.23 5,601 7,788 7,788 — 61 61 27.28 4,607 1,715 22.05 5,391 64.04 10,673 47.96 7,993 67.51 11,251 — — 0.30 50 0.54 90 0.05 8 20 1,020 1,040 7.14 5,055 7,578 7,578 — 66 66 29.07 4,910 1,410 25.85 5,717 24.58 4,096 — — 0.64 107 36 1,218 1,254 7.45 5,779 7,247 7,247 — 49 49 27.41 4,617 1,481 25.86 5,791 26.04 4,340 4,847 4,847 0.67 111 35 1,031 1,066 7.03 40 958 998 6.74 24 26 2 1,056 1,388 1,206 1,080 1,414 1,208 7.56 9.09 6.75 2 928 930 5.51 — 1,058 1,058 5.95 5,062 4,967 5,014 5,575 5,854 3,736 4,373 6,818 8,126 8,389 8,453 8,677 9,013 9,062 6,818 8,126 8,389 8,453 8,677 9,013 9,062 — 74 74 1 60 60 1 83 83 — 97 97 6 104 104 1 95 95 6 92 92 29.15 35.22 39.03 51.98 42.48 37.59 41.45 4,933 5,930 6,589 8,761 7,190 6,362 7,006 1,764 1,331 1,158 1,127 1,043 1,093 911 26.54 25.36 26.95 18.00 16.19 15.60 13.40 6,187 5,558 5,650 4,127 3,741 3,694 3,144 25.74 27.93 30.26 30.12 22.67 30.19 34.14 4,290 4,655 5,043 5,020 3,778 5,031 5,690 4,763 2,465 3,888 2,742 4,190 3,835 4,489 4,763 2,465 3,888 2,742 4,190 3,835 4,489 0.63 104 0.64 106 0.34 57 0.12 20 0.22 36 0.28 46 0.63 104 28,685 26,952 25,753 28,485 34,305 33,003 31,811 32,091 31,356 34,245 32,698 34,556 4,180 7,412 11,592 283.92 87,597 4,463 7,344 11,807 263.80 82,727 3,589 6,538 10,127 283.63 83,152 4,805 7,896 12,701 247.61 82,455 4,610 7,497 12,107 234.23 85,450 4,312 4,973 4,999 4,908 4,532 5,656 4,648 7,901 8,113 8,342 8,461 8,068 8,695 8,074 12,213 13,086 13,341 13,369 12,600 14,351 12,722 234.12 239.83 244.69 238.16 226.73 235.72 233.98 84,237 84,868 86,213 84,417 84,633 86,335 86,276 Vermilion Energy Inc. ■ Page 59 ■ 2023 Annual Report Light and medium crude oil (bbls/d) Total (boe/d) 4,715 4,715 1,204 1,204 Canada Light and medium crude oil (bbls/d) Condensate (1) (bbls/d) Other NGLs (1) (bbls/d) NGLs (bbls/d) Conventional natural gas (mmcf/d) Total (boe/d) United States Light and medium crude oil (bbls/d) Condensate (1) (bbls/d) Other NGLs (1) (bbls/d) NGLs (bbls/d) Conventional natural gas (mmcf/d) Total (boe/d) France Light and medium crude oil (bbls/d) Conventional natural gas (mmcf/d) Total (boe/d) Netherlands Light and medium crude oil (bbls/d) Condensate (1) (bbls/d) NGLs (bbls/d) Conventional natural gas (mmcf/d) Total (boe/d) Germany Light and medium crude oil (bbls/d) Conventional natural gas (mmcf/d) Total (boe/d) Ireland Conventional natural gas (mmcf/d) Total (boe/d) Australia Light and medium crude oil (bbls/d) Total (boe/d) Central and Eastern Europe Conventional natural gas (mmcf/d) Total (boe/d) Consolidated Light and medium crude oil (bbls/d) Condensate (1) (bbls/d) Other NGLs (1) (bbls/d) NGLs (bbls/d) Conventional natural gas (mmcf/d) Total (boe/d) 2023 2022 2021 2020 2019 2018 13,293 16,830 16,954 21,106 23,971 17,400 4,166 6,220 10,386 160.94 50,503 4,621 6,895 11,516 144.10 52,364 4,831 7,179 12,010 138.03 51,968 4,886 7,719 12,605 151.38 58,942 4,295 6,988 11,283 148.35 59,979 3,754 5,914 9,668 129.37 48,630 3,445 2,908 2,597 3,046 2,514 1,069 21 1,076 1,097 7.28 5,754 34 1,066 1,100 7.20 5,207 8 1,146 1,154 6.84 4,890 5 1,218 1,223 7.47 5,514 18 996 1,014 6.89 4,675 8 452 460 2.78 1,992 7,584 7,639 8,799 8,903 10,435 11,362 — — — — 0.19 0.21 7,584 7,639 8,799 8,903 10,467 11,396 — 71 71 28.18 4,768 1,654 21.93 5,310 51.12 8,520 1,492 1,492 0.38 63 — 66 66 32.66 5,510 1,435 26.18 5,798 27.48 4,579 3,995 3,995 0.57 95 3 97 97 43.40 7,334 1,044 15.81 3,679 29.25 4,875 3,810 3,810 0.31 51 1 88 88 46.16 7,782 968 12.65 3,076 37.44 6,240 4,416 4,416 1.90 317 3 88 88 49.10 8,274 917 15.31 3,468 46.57 7,762 5,662 5,662 0.42 70 — 90 90 46.13 7,779 1,004 15.66 3,614 55.17 9,195 4,494 4,494 1.02 169 27,469 32,809 33,208 38,441 43,502 35,329 4,258 7,296 11,554 269.84 83,994 4,721 7,961 12,682 238.18 85,187 4,936 8,325 13,261 233.64 85,408 4,980 8,937 13,917 256.99 4,400 7,984 12,384 266.82 95,190 100,357 3,853 6,366 10,219 250.33 87,270 (1) Under National Instrument 51-101 "Standards of Disclosure for Oil and Gas Activities", disclosure of production volumes should include segmentation by product type as defined in the instrument. This table provides a reconciliation from "crude oil and condensate", "NGLs" and "natural gas" to the product types. In this report, references to "crude oil" and "light and medium crude oil" mean "light crude oil and medium crude oil" and references to "natural gas" mean "conventional natural gas". Production volumes reported are based on quantities as measured at the first point of sale. Vermilion Energy Inc. ■ Page 60 ■ 2023 Annual Report Supplemental Table 5: Segmented Financial Results Three Months Ended December 31, 2023 ($M) Drilling and development Exploration and evaluation Canada 53,791 — USA 4,913 — 11,217 10,788 — (1) France Netherlands Germany Australia Corporate Crude oil and condensate sales 142,924 30,892 52,472 NGL sales Natural gas sales Sales of purchased commodities Royalties 18,196 38,982 — 4,567 1,408 — — — — (25,759) (10,427) (7,150) 1,073 — 50,588 — (692) Transportation Operating General and administration PRRT Corporate income taxes Windfall taxes Interest expense Realized gain on derivative instruments Realized foreign exchange loss Realized other income (11,701) (51,129) (25,259) — (53) — — — — — — — (450) (5,745) (6,239) (2,706) — — — — — — — (17,021) (9,143) (6,245) — (578) — (5,888) (18,758) — — — — — — — — — — 30,018 3,028 15,028 — Ireland 11,850 — 42 — 29,122 100,388 — (736) — — 9,331 — 36,381 — — — — 400 7,552 — — 906 38,458 Total 132,308 10,579 278,812 22,763 221,394 38,458 (384) (45,148) — (3,486) (8,233) (3,999) — 2,523 — (1,059) — — (38,458) (38,458) — (22,441) (13,948) (10,677) (547) (116,937) (9,085) (2,508) 30,570 — (325) 20,860 1,925 — 1,202 (19,810) 20,860 (19,374) — — — — — — — — — — — — — — — (249) (249) (22,909) (22,909) 78,737 (5,529) 1,948 83,745 78,737 (5,529) 1,948 372,117 Revenue from external customers 174,343 26,440 45,322 50,969 43,414 100,430 36,381 38,980 516,279 Purchased commodities — — — Fund flows from operations 86,201 17,045 10,423 22,490 30,219 76,013 45,981 ($M) Total assets Drilling and development Exploration and evaluation Crude oil and condensate sales NGL sales Natural gas sales Sales of purchased commodities Canada 1,805,049 288,223 — 621,985 68,753 170,653 254,884 91,977 — 587,824 48,297 — 129,775 285,626 15,240 6,143 — — — — USA France Netherlands Germany Ireland Australia Corporate Total Year Ended December 31, 2023 425,532 1,137,648 280,532 1,507,026 6,235,821 237,326 44,147 — 2,306 — 48,463 11,248 57,464 — 184,548 138,017 302,330 — — 20,283 26,005 — 74 — — — — 36,381 — — — — 1,715 9,833 569,110 21,081 — — 3,260 177,000 1,133,611 83,993 804,951 177,000 (1,711) (191,694) Royalties (103,511) (41,487) (37,425) (1,567) (5,993) Revenue from external customers 757,880 109,671 248,201 185,287 189,488 302,404 36,381 178,549 2,007,861 Purchased commodities Transportation Operating — — (43,163) (751) (24,511) — — — — (13,333) (7,098) — — (177,000) (177,000) — (88,856) (233,417) (23,424) (80,134) (39,157) (43,857) (39,464) (52,360) (1,568) (513,381) General and administration (96,296) (9,734) (20,642) (8,317) (13,104) (19,054) (8,182) 94,613 PRRT Corporate income taxes Windfall taxes Interest expense Realized gain on derivative instruments Realized foreign exchange loss Realized other expense — (53) — — — — — — — — — — — — — — — — 20,860 (14,313) (48,349) (28,533) (715) — — — — — — — — — — — — — — — — — — — — 13 — — — — — (80,716) 20,860 (91,932) — 18 (78,426) (78,426) (85,212) (85,212) 234,365 234,365 (4,532) (420) (4,532) (420) Fund flows from operations 384,951 75,762 108,601 89,464 90,661 236,073 (3,288) 160,387 1,142,611 Vermilion Energy Inc. ■ Page 61 ■ 2023 Annual Report Supplemental Table 6: Operational and Financial Data by Core Region Production volumes (1) North America Crude oil and condensate (bbls/d) 18,862 20,883 19,778 24,237 25,291 23,898 24,801 23,571 23,846 24,757 24,316 24,645 Q4/23 Q3/23 Q2/23 Q1/23 Q4/22 Q3/22 Q2/22 Q1/22 Q4/21 Q3/21 Q2/21 Q1/21 NGLs (bbls/d) Natural gas (mmcf/d) Total (boe/d) International 7,412 7,344 6,538 7,895 7,497 7,901 8,113 8,342 8,461 8,068 8,695 8,074 167.65 171.19 166.49 167.48 154.26 152.07 150.68 148.11 137.93 145.18 152.06 144.36 54,216 56,758 54,065 60,046 58,499 57,142 58,027 56,598 55,295 57,022 58,354 56,780 Crude oil and condensate (bbls/d) 14,004 10,534 9,564 9,054 13,624 13,419 11,983 13,519 12,419 14,020 14,037 14,560 Natural gas (mmcf/d) Total (boe/d) Consolidated 116.27 92.61 117.14 80.13 79.97 82.05 89.15 96.58 100.22 81.55 83.66 89.62 33,381 25,969 29,087 22,408 26,953 27,095 26,840 29,616 29,123 27,612 27,981 29,495 Crude oil and condensate (bbls/d) 32,866 31,416 29,341 33,290 38,915 37,315 36,784 37,090 36,264 38,777 38,354 39,204 NGLs (bbls/d) Natural gas (mmcf/d) Total (boe/d) 7,412 7,344 6,538 7,896 7,497 7,901 8,113 8,342 8,461 8,068 8,695 8,074 283.92 263.80 283.63 247.61 234.23 234.12 239.83 244.69 238.16 226.73 235.72 233.98 87,597 82,727 83,152 82,455 85,450 84,237 84,868 86,213 84,417 84,633 86,335 86,276 (1) Please refer to Supplemental Table 4 "Production" for disclosure by product type. Sales volumes North America Q4/23 Q3/23 Q2/23 Q1/23 Q4/22 Q3/22 Q2/22 Q1/22 Q4/21 Q3/21 Q2/21 Q1/21 Crude oil and condensate (bbls/d) 18,862 20,883 19,778 24,237 25,291 23,897 24,801 23,571 23,845 24,757 24,316 24,645 NGLs (bbls/d) Natural gas (mmcf/d) Total (boe/d) International 7,412 7,344 6,538 7,895 7,497 7,901 8,113 8,342 8,461 8,068 8,695 8,074 167.65 171.19 166.49 167.48 154.26 152.07 150.68 148.11 137.93 145.18 152.06 144.36 54,216 56,758 54,065 60,046 58,499 57,142 58,027 56,598 55,295 57,022 58,354 56,780 Crude oil and condensate (bbls/d) 9,221 9,950 10,302 8,087 16,257 11,493 11,720 12,615 13,985 15,227 13,859 11,421 Natural gas (mmcf/d) Total (boe/d) Consolidated 116.27 92.61 117.14 80.13 79.97 82.05 89.15 96.58 100.22 81.55 83.66 89.62 28,598 25,386 29,824 21,442 29,585 25,169 26,578 28,712 30,689 28,820 27,802 26,357 Crude oil and condensate (bbls/d) 28,083 30,833 30,080 32,324 41,547 35,391 36,522 36,186 37,830 39,985 38,174 36,066 NGLs (bbls/d) Natural gas (mmcf/d) Total (boe/d) 7,412 7,344 6,538 7,896 7,497 7,901 8,113 8,342 8,461 8,068 8,695 8,074 283.92 263.80 283.63 247.61 234.23 234.12 239.83 244.69 238.16 226.73 235.72 233.98 82,814 82,144 83,889 81,489 88,083 82,312 84,607 85,310 85,984 85,841 86,156 83,138 Vermilion Energy Inc. ■ Page 62 ■ 2023 Annual Report Financial results North America Q4/23 Q3/23 Q2/23 Q1/23 Q4/22 Q3/22 Q2/22 Q1/22 Q4/21 Q3/21 Q2/21 Q1/21 Crude oil and condensate sales ($/bbl) 100.16 103.46 NGL sales ($/bbl) Natural gas sales ($/mcf) Sales ($/boe) Royalties ($/boe) Transportation ($/boe) Operating ($/boe) 33.38 2.62 47.51 27.77 2.52 49.26 94.78 28.11 2.29 45.12 95.63 106.66 114.82 134.72 111.42 36.24 4.11 54.84 39.93 5.96 66.95 44.64 6.41 71.24 51.86 7.13 83.34 46.94 4.80 65.88 92.99 47.26 5.07 59.97 82.23 35.55 3.80 50.40 75.43 25.43 2.72 42.30 (7.25) (2.44) (7.75) (2.08) (5.45) (1.57) (7.68) (2.44) (9.47) (12.58) (12.51) (11.24) (2.42) (2.16) (2.15) (1.91) (9.26) (1.86) (7.14) (1.92) (5.98) (1.90) 66.31 29.39 3.98 43.08 (5.49) (2.05) (11.50) (12.09) (12.22) (14.10) (13.51) (14.00) (11.58) (11.95) (11.68) (11.02) (10.89) (11.21) General and administration ($/boe) Corporate income taxes ($/boe) 0.87 0.23 (0.72) (0.01) 0.10 (0.10) (0.99) (0.12) 0.10 (0.13) (1.27) (0.03) (1.52) — (1.26) (0.02) Fund flows from operations ($/boe) 27.42 26.61 25.88 29.51 41.52 41.20 55.58 39.50 (2.01) 0.42 35.58 (1.14) (0.05) (0.91) (0.04) 29.13 22.58 (1.34) (0.04) 22.95 Fund flows from operations Drilling and development Free cash flow International 136,766 138,958 127,346 159,435 223,443 216,579 293,470 201,193 180,979 152,764 119,916 117,227 (58,704) (69,703) (135,723) (116,070) (113,892) (112,238) (54,913) (57,513) (89,643) (35,179) (38,847) (59,113) 78,062 69,255 (8,377) 43,365 109,551 104,341 238,557 143,680 91,336 117,585 81,069 58,114 Crude oil and condensate sales ($/bbl) 123.77 114.26 100.23 107.57 128.02 140.09 146.67 136.69 103.53 16.92 108.70 (3.41) (3.91) 13.34 93.46 3.55 14.58 24.69 39.54 58.55 32.33 36.75 35.54 91.89 132.84 177.23 254.86 173.14 183.66 163.23 103.39 94.91 18.82 85.41 9.83 72.16 (7.43) (13.39) (4.53) (5.23) (5.11) (6.38) (3.29) (7.21) (3.51) (7.23) (3.64) (5.43) (2.91) (4.13) (3.40) (4.52) (3.47) (3.83) (4.64) (22.64) (25.58) (28.24) (31.41) (23.35) (22.63) (22.11) (19.86) (18.86) (17.55) (16.56) (16.42) Natural gas sales ($/mcf) Sales ($/boe) Royalties ($/boe) Transportation ($/boe) Operating ($/boe) General and administration ($/boe) (9.18) (7.37) (7.58) (7.52) (5.09) (3.34) (3.16) (3.02) (2.53) (2.40) Corporate income taxes ($/boe) (7.81) (13.42) (6.79) (11.20) (15.15) (21.97) (28.73) (17.63) (12.17) 0.64 PRRT ($/boe) Fund flows from operations ($/boe) 7.93 69.68 — — — (1.85) (1.96) (0.83) (2.60) (1.96) (2.74) 46.12 36.62 64.21 122.12 194.24 107.44 132.21 120.18 73.35 43.75 (2.61) (0.19) (0.58) 81.40 7.98 62.39 (3.53) (2.76) (2.06) 0.66 (0.60) 37.68 Fund flows from operations Drilling and development Exploration and evaluation Free cash flow Consolidated 183,353 107,704 99,377 123,893 332,377 449,771 259,840 341,626 339,286 194,505 110,654 89,403 (73,604) (49,701) (28,347) (37,258) (43,957) (65,640) (54,575) (25,328) (29,359) (27,994) (38,856) (20,399) (10,579) (6,235) (2,775) (1,492) (11,456) (6,137) (3,665) (2,503) (26,805) (3,277) (1,473) (3,851) 99,170 51,768 68,255 85,143 276,964 377,994 201,600 313,795 283,122 163,234 70,325 65,153 Q4/23 Q3/23 Q2/23 Q1/23 Q4/22 Q3/22 Q2/22 Q1/22 Q4/21 Q3/21 Q2/21 Q1/21 Crude oil and condensate sales ($/bbl) 107.91 106.94 NGL sales ($/bbl) Natural gas sales ($/mcf) Sales ($/boe) Royalties ($/boe) Transportation ($/boe) Operating ($/boe) General and administration ($/boe) Corporate income taxes ($/boe) Windfall taxes ($/boe) PRRT ($/boe) Interest ($/boe) 33.38 8.48 68.64 27.77 6.32 62.92 96.64 28.11 7.37 61.74 98.62 115.02 123.02 138.55 120.23 36.23 10.77 39.93 17.43 44.64 24.68 51.86 16.50 46.94 17.41 75.36 103.99 127.39 111.55 105.52 96.88 47.26 17.89 96.82 87.05 35.55 9.20 68.19 79.06 25.43 5.24 51.93 (5.93) (2.95) (4.26) (2.84) (6.16) (2.87) (9.18) (3.14) (8.43) (10.94) (10.85) (2.71) (2.57) (2.62) (9.29) (2.25) (7.43) (2.41) (6.26) (2.44) (5.29) (2.78) 71.09 29.39 5.51 49.20 (4.87) (2.27) (15.35) (16.26) (17.91) (18.66) (16.81) (16.64) (14.89) (14.61) (14.24) (13.21) (12.72) (12.86) (2.60) (2.54) (0.03) 2.74 (2.77) (4.15) (2.90) — (2.63) (2.48) (4.56) — (3.01) (2.68) (2.65) (2.98) (2.71) (3.04) (1.65) (5.18) (1.90) (6.74) (2.92) (27.50) — — (0.62) (2.78) (0.60) (3.23) (2.04) (9.03) — (0.26) (2.74) (1.85) (5.95) — (0.87) (1.93) (2.20) (4.07) — (0.70) (2.06) 1.95 (5.42) (18.22) (10.36) (18.78) (23.97) (1.56) 0.18 — (0.92) (2.37) (9.19) (0.65) 2.33 (0.28) (0.30) 0.49 34.52 (0.14) 35.08 0.80 67.07 0.36 58.82 0.10 0.70 50.79 (0.30) 1.29 40.73 0.37 0.48 33.27 (1.46) (0.09) — (0.19) (2.41) (5.05) (0.25) 0.35 22.04 (1.57) 0.18 — (0.19) (2.57) (3.43) (0.69) 0.73 21.66 Realized derivatives ($/boe) Realized foreign exchange ($/boe) Realized other ($/boe) Fund flows from operations ($/boe) 10.33 (0.73) 0.26 48.83 9.74 0.28 (1.32) 8.86 0.48 0.53 35.74 32.35 Fund flows from operations Drilling and development Exploration and evaluation Free cash flow 372,117 270,214 247,109 253,167 284,220 507,876 452,901 389,868 322,173 262,696 172,942 162,051 (132,308) (119,404) (164,070) (153,328) (157,849) (177,878) (109,488) (82,841) (119,002) (63,173) (77,703) (79,512) (10,579) (6,235) (2,775) (1,492) (11,456) (6,137) (3,665) (2,503) (26,805) (3,277) (1,473) (3,851) 229,230 144,575 80,264 98,347 114,915 323,861 339,748 304,524 176,366 196,246 93,766 78,688 Vermilion Energy Inc. ■ Page 63 ■ 2023 Annual Report Non-GAAP and Other Specified Financial Measures This MD&A includes references to certain financial measures which do not have standardized meanings and may not be comparable to similar measures presented by other issuers. These financial measures include fund flows from operations, a total of segments measure of profit or loss in accordance with IFRS 8 “Operating Segments” (please see Segmented Information in the Notes to the condensed Consolidated Financial Statements) and net debt, a capital management measure in accordance with IAS 1 “Presentation of Financial Statements” (please see Capital Disclosures in the Notes to the condensed Consolidated Financial Statements). In addition, this MD&A includes financial measures which are not specified, defined, or determined under IFRS and are therefore considered non- GAAP financial measures and may not be comparable to similar measures presented by other issuers. These non-GAAP financial measures include: Total of Segments Measure Fund flows from operations (FFO): Most directly comparable to net (loss) earnings, FFO is comprised of sales less royalties, transportation, operating, G&A, corporate income tax, PRRT, windfall taxes, interest expense, realized loss on derivatives, realized foreign exchange gain (loss), and realized other income. The measure is used to assess the contribution of each business unit to Vermilion's ability to generate income necessary to pay dividends, repay debt, fund asset retirement obligations and make capital investments. Reconciliation to the primary financial statement measures can be found below. Sales Royalties Transportation Operating General and administration Corporate income tax expense Windfall taxes PRRT Interest expense Realized gain (loss) on derivatives Realized foreign exchange gain (loss) Realized other (expense) income Fund flows from operations Equity based compensation Unrealized gain on derivative instruments (1) Unrealized foreign exchange gain (loss) (1) Accretion Depletion and depreciation Deferred tax recovery (expense) Gain on business combination Loss on disposition Impairment (expense) reversal Unrealized other income (expense) (1) Net (loss) earnings (1) Q4 2023 $M 522,969 (45,148) (22,441) (116,937) (19,810) (19,374) (249) 20,860 (22,909) 78,737 (5,529) 1,948 372,117 (7,871) $/boe 68.64 (5.93) (2.95) (15.35) (2.60) (2.54) (0.03) 2.74 (3.01) 10.33 (0.73) 0.26 48.83 141,126 4,834 (19,469) (259,012) 110,758 (5,607) (125,539) (1,016,094) 1,621 (803,136) Q4 2022 $M 842,693 (68,303) (21,976) (136,247) (13,344) (41,958) (222,859) (5,045) (22,506) (43,940) 18,845 (1,140) 284,220 (5,377) 549,693 (47,405) (16,501) (171,926) (196,733) — — — (563) 395,408 2023 $M $/boe 103.99 2,022,555 (191,694) (8.43) (88,856) (2.71) (513,381) (16.81) (80,716) (1.65) (91,932) (5.18) (78,426) (27.50) 20,860 (0.62) (85,212) (2.78) 234,365 (5.42) (4,532) 2.33 (0.14) (420) 35.08 1,142,611 (42,756) 2022 $M $/boe 67.10 3,476,394 (306,017) (6.36) (2.95) (78,896) (489,034) (17.03) (2.68) (57,677) (208,153) (3.05) (222,859) (2.60) (18,318) 0.69 (82,858) (2.83) (405,894) 7.77 15,195 (0.15) (0.01) 12,982 37.90 1,634,865 (44,390) $/boe 111.95 (9.85) (2.54) (15.75) (1.86) (6.70) (7.18) (0.59) (2.67) (13.07) 0.49 0.42 52.65 179,707 12,438 (78,187) (712,619) 190,193 439,487 (352,367) (1,016,094) — (237,587) 540,801 (84,464) (58,170) (577,134) (288,707) — — 192,094 (1,833) 1,313,062 Unrealized gain on derivative instruments, Unrealized foreign exchange gain (loss), and Unrealized other expense are line items from the respective Consolidated Statements of Cash Flows. Non-GAAP Financial Measures and Non-GAAP Ratios Free cash flow: Most directly comparable to cash flows from operating activities and is comprised of fund flows from operations less drilling and development costs and exploration and evaluation costs. The measure is used to determine the funding available for investing and financing activities including payment of dividends, repayment of long-term debt, reallocation into existing business units and deployment into new ventures. Reconciliation to the primary financial statement measures can be found in the following table. Vermilion Energy Inc. ■ Page 64 ■ 2023 Annual Report   ($M) Cash flows from operating activities Changes in non-cash operating working capital Asset retirement obligations settled Fund flows from operations Drilling and development Exploration and evaluation Free cash flow Q4 2023 343,831 (651) 28,937 372,117 (132,308) (10,579) 229,230 Q4 2022 495,195 (227,483) 16,508 284,220 (157,849) (11,456) 114,915 2023 1,024,528 61,117 56,966 1,142,611 (569,110) (21,081) 552,420 2022 1,814,220 (216,869) 37,514 1,634,865 (528,056) (23,761) 1,083,048 Capital expenditures: Calculated as the sum of drilling and development costs and exploration and evaluation costs from the Consolidated Statements of Cash Flows that is most directly comparable to cash flows used in investing activities. We consider capital expenditures to be a useful measure of our investment in our existing asset base. Capital expenditures are also referred to as E&D capital. Reconciliation to the primary financial statement measures can be found below. ($M) Drilling and development Exploration and evaluation Capital expenditures Q4 2023 132,308 10,579 142,887 Q4 2022 157,849 11,456 169,305 2023 569,110 21,081 590,191 2022 528,056 23,761 551,817 Payout and payout % of FFO: A non-GAAP financial measure and non-GAAP ratio respectively, most directly comparable to dividends declared. Payout is comprised of dividends declared plus drilling and development costs, exploration and evaluation costs, and asset retirement obligations settled, and payout % of FFO is calculated as payout over FFO (total of segments measure). The measure is used to assess the amount of cash distributed back to shareholders and reinvested in the business for maintaining production and organic growth. The reconciliation of the measure to the primary financial statement measure can be found below. ($M) Dividends declared Drilling and development Exploration and evaluation Asset retirement obligations settled Payout % of fund flows from operations Q4 2023 16,227 132,308 10,579 28,937 188,051 Q4 2022 13,058 157,849 11,456 16,508 198,871 2023 2022 65,248 569,110 21,081 56,966 712,405 45,769 528,056 23,761 37,514 635,100 51 % 70 % 62 % 39 % Return on capital employed (ROCE): A non-GAAP ratio, ROCE is a measure that we use to analyze our profitability and the efficiency of our capital allocation process; the comparable primary financial statement measure is earnings before income taxes. ROCE is calculated by dividing net (loss) earnings before interest and taxes ("EBIT") by average capital employed over the preceding twelve months. Capital employed is calculated as total assets less current liabilities while average capital employed is calculated using the balance sheets at the beginning and end of the twelve- month period. ($M) Net (loss) earnings Taxes Interest expense EBIT Average capital employed Return on capital employed Twelve Months Ended Dec 31, 2023 (237,587) (40,695) 85,212 (193,070) 5,819,380 (3) % Dec 31, 2022 1,313,062 738,037 82,858 2,133,957 5,628,762 38 % Adjusted working capital: Defined as current assets less current liabilities, excluding current derivatives and current lease liabilities. The measure is used to calculate net debt, a capital management measure disclosed below. Vermilion Energy Inc. ■ Page 65 ■ 2023 Annual Report ($M) Current assets Current derivative asset Current liabilities Current lease liability Current derivative liability Adjusted working capital As at Dec 31, 2023 823,514 (313,792) (696,074) 21,068 732 (164,552) Dec 31, 2022 714,446 (162,843) (892,045) 19,486 55,845 (265,111) Acquisitions: The sum of acquisitions and acquisitions of securities from the Consolidated Statements of Cash Flows, Vermilion common shares issued as consideration, the estimated value of contingent consideration, the amount of acquiree's outstanding long-term debt assumed, and net acquired working capital deficit or surplus. We believe that including these components provides a useful measure of the economic investment associated with our acquisition activity and is most directly comparable to cash flows used in investing activities. A reconciliation to the acquisitions line items in the Consolidated Statements of Cash Flows can be found below. ($M) Acquisitions, net of cash acquired Acquisition of securities Acquired working capital deficit Acquisitions Capital Management Measure Q4 2023 Q4 2022 2,669 17,448 5,607 25,724 3,594 964 — 4,558 Q4 2023 142,281 21,603 109,134 273,018 Q4 2022 510,309 23,282 6,122 539,713 Net debt: Is in accordance with IAS 1 "Presentation of Financial Statements" that is most directly comparable to long-term debt. Net debt is comprised of long-term debt (excluding unrealized foreign exchange on swapped USD borrowings) plus adjusted working capital (defined as current assets less current liabilities, excluding current derivatives and current lease liabilities), and represents Vermilion's net financing obligations after adjusting for the timing of working capital fluctuations. Net debt excludes lease obligations which are secured by a corresponding right-of-use asset. ($M) Long-term debt Adjusted working capital Unrealized FX on swapped USD borrowings Net debt As at Dec 31, 2023 914,015 164,552 — 1,078,567 Dec 31, 2022 1,081,351 265,111 (1,876) 1,344,586 Ratio of net debt to four quarter trailing fund flows from operations 0.9 0.8 Supplementary Financial Measures Diluted shares outstanding: The sum of shares outstanding at the period end plus outstanding awards under the LTIP, based on current estimates of future performance factors and forfeiture rates. ('000s of shares) Shares outstanding Potential shares issuable pursuant to the LTIP Diluted shares outstanding Q4 2023 162,271 4,185 166,456 Q4 2022 163,227 5,389 168,616 Vermilion Energy Inc. ■ Page 66 ■ 2023 Annual Report Fund flows from operations per basic and diluted share: Management assesses fund flows from operations on a per share basis as we believe this provides a measure of our operating performance after taking into account the issuance and potential future issuance of Vermilion common shares. Fund flows from operations per basic share is calculated by dividing fund flows from operations (total of segments measure) by the basic weighted average shares outstanding as defined under IFRS. Fund flows from operations per diluted share is calculated by dividing fund flows from operations by the sum of basic weighted average shares outstanding and incremental shares issuable under the equity based compensation plans as determined using the treasury stock method. Operating netback: Most directly comparable to net (loss) earnings that is calculated as sales less royalties, operating expense, transportation costs, PRRT, and realized hedging gains and losses presented on a per unit basis. Management assesses operating netback as a measure of the profitability and efficiency of our field operations. Fund flows from operations per boe: Calculated as FFO (total of segments measure) by boe production. Fund flows from operations netback is used by management to assess the profitability of our business units and Vermilion as a whole. Net debt to four quarter trailing fund flows from operations: Calculated as net debt (capital management measure) over the FFO (total of segments measure) from the preceding four quarters. The measure is used to assess the ability to repay debt. Cash dividends per share: Represents cash dividends declared per share that is a useful measure of the dividends a common shareholder was entitled to during the period. Covenants: The financial covenants on our revolving credit facility contain non-GAAP measures. The definitions for these financial covenants are included in Financial Position Review. Vermilion Energy Inc. ■ Page 67 ■ 2023 Annual Report Management's Report to Shareholders Management's Responsibility for Financial Statements The accompanying consolidated financial statements of Vermilion Energy Inc. are the responsibility of management and have been approved by the Board of Directors of Vermilion Energy Inc. The consolidated financial statements have been prepared in accordance with the accounting policies detailed in the notes to the consolidated financial statements and are prepared in accordance with International Financial Reporting Standards as issued by the International Accounting Standards Board. Where necessary, management has made informed judgments and estimates of transactions that were not yet completed at the balance sheet date. Financial information throughout the Annual Report is consistent with the consolidated financial statements. Management ensures the integrity of the consolidated financial statements by maintaining high-quality systems of internal control. Procedures and policies are designed to provide reasonable assurance that assets are safeguarded and transactions are properly recorded, and that the financial records are reliable for preparation of the consolidated financial statements. Deloitte LLP, Vermilion’s Independent Registered Public Accounting Firm, have conducted an audit of the consolidated financial statements in accordance with the standards of the Public Company Accounting Oversight Board (United States) and have provided their report. The Board of Directors is responsible for ensuring that management fulfills its responsibility for financial reporting and internal control. The Board carries out this responsibility principally through the Audit Committee, which is appointed by the Board and is comprised entirely of independent Directors. The Committee meets periodically with management and Deloitte LLP to satisfy itself that each party is properly discharging its responsibilities and to review the consolidated financial statements, Management’s Discussion and Analysis and the Report of the Independent Registered Public Accounting Firm before they are presented to the Board of Directors. Management's Report on Internal Control Over Financial Reporting Management is responsible for establishing and maintaining an adequate system of internal control over financial reporting. Management, under the supervision and with the participation of the principal executive officer and principle financial officer, conducted an evaluation of the effectiveness of the system of internal control over financial reporting based on the criteria established in “Internal Control - Integrated Framework (2013)” issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this evaluation, management has assessed the effectiveness of Vermilion’s internal control over financial reporting as defined in Rule 13a-15(f) and 15d-15(f) under the US Securities Exchange Act of 1934 and as defined in Canada by National Instrument 52-109, Certification of Disclosure in Issuers’ Annual and Interim Filings. Management concluded that Vermilion’s internal control over financial reporting was effective as of December 31, 2023. Vermilion has limited the scope of design controls and procedures ("DC&P") and internal controls over financial reporting to exclude controls, policies and procedures of Equinor Energy Ireland Limited, which was acquired on March 31, 2023. The scope limitation is in accordance with section 3.3(1)(b) of NI 52-109 which allows an issuer to limit the design of DC&P and ICFR to exclude controls, policies, and procedures of a business that the issuer acquired not more than 365 days before the end of the fiscal period. Total assets and revenues excluded from management's assessment of internal control over financial reporting represents 12% and 8%, respectively, of the related Consolidated Financial Statement amounts as at and for the year ended December 31, 2023. Because of inherent limitations, internal control over financial reporting may not prevent or detect misstatements and even those systems determined to be effective can provide only reasonable assurance with respect to the financial statement preparation and presentation. The effectiveness of Vermilion’s internal control over financial reporting as of December 31, 2023 has been audited by Deloitte LLP, the Company’s Independent Registered Public Accounting Firm, who also audited the Company’s consolidated financial statements for the year ended December 31, 2023. (“Dion Hatcher”) (“Lars Glemser”) Dion Hatcher President & Chief Executive Officer March 6, 2024 Lars Glemser Vice President & Chief Financial Officer Vermilion Energy Inc. ■ Page 68 ■ 2023 Annual Report   Report of Independent Registered Public Accounting Firm To the Shareholders and the Board of Directors of Vermilion Energy Inc. Opinion on Internal Control over Financial Reporting We have audited the internal control over financial reporting of Vermilion Energy Inc. and subsidiaries (the “Company") as of December 31, 2023, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2023, based on criteria established in Internal Control - Integrated Framework (2013) issued by COSO. We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated financial statements as of and for the year ended December 31, 2023, of the Company and our report dated March 6, 2024, expressed an unqualified opinion on those financial statements. As described in Management’s Report to Shareholders, management excluded from its assessment the internal control over financial reporting at Equinor Energy Ireland Limited (“EEIL”), which was acquired on March 31, 2023, and whose financial statements constitute 12% of total assets and 8% of total revenues of the consolidated financial statement amounts as of and for the year ended December 31, 2023. Accordingly, our audit did not include the internal control over financial reporting at EEIL. Basis for Opinion The Company's management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report to Shareholders. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB. We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion. Definition and Limitations of Internal Control over Financial Reporting A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, 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 or procedures may deteriorate. /s/ Deloitte LLP Chartered Professional Accountants Calgary, Canada March 6, 2024 Vermilion Energy Inc. ■ Page 69 ■ 2023 Annual Report Report of Independent Registered Public Accounting Firm To the Shareholders and the Board of Directors of Vermilion Energy Inc. Opinion on the Financial Statements We have audited the accompanying consolidated balance sheet of Vermilion Energy Inc. and subsidiaries (the "Company") as of December 31, 2023 and 2022, the related consolidated statements of net (loss) earnings and comprehensive (loss) income, consolidated statements of cash flows and consolidated statements of changes in shareholders' equity for each of the two years in the period ended December 31, 2023, and the related notes (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2023 and 2022, and its financial performance and its cash flows for each of the two years in the period ended December 31, 2023, in accordance with International Financial Reporting Standards as issued by the International Accounting Standards Board. We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company's internal control over financial reporting as of December 31, 2023, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated March 6 2024, expressed an unqualified opinion on the Company's internal control over financial reporting. Basis for Opinion These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB. We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion. Critical Audit Matters The critical audit matters communicated below are matters arising from the current-period audit of the financial statements that were communicated or required to be communicated to the audit committee and that (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate. Valuation of capital assets acquired from Equinor Energy Ireland Limited. - Refer to Notes 2 and 4 to the financial statements Critical Audit Matter Description The Company completed the acquisition of Equinor Energy Ireland Limited (“EEIL”) on March 31, 2023. The Company accounted for the acquisition as a business combination using the acquisition method. The purchase price was allocated to assets acquired, including capital assets and liabilities assumed based on their respective fair value at the date of acquisition. As a result of the fair value of the net assets acquired exceeding the consideration paid, a gain on business combination of $439 million was also recognized. The fair value of capital assets is estimated based on the future after-tax cash flows of the underlying proved and probable natural gas reserves. The Company engaged an independent reserve engineer to estimate these reserves using estimates, assumptions, and engineering data. The development of the Company’s reserves and their future after-tax cash flows required management to make significant estimates and assumptions related to future natural gas prices, discount rate, reserves, and future operating and development costs. Given the significant judgments made by management related to future natural gas prices, discount rate, reserves, and future operating and development costs, these estimates and assumptions are subject to a high degree of estimation uncertainty. This required a high degree of auditor judgment and resulted in an increased extent of audit effort, including the involvement of fair value specialists. Vermilion Energy Inc. ■ Page 70 ■ 2023 Annual Report How the Critical Audit Matter Was Addressed in the Audit Our audit procedures related to future natural gas prices, discount rate, reserves, and future operating and development costs used to determine the fair value of capital assets included the following, among others: • • • • Evaluated the effectiveness of the relevant controls, including those over the determination of the future natural gas prices, discount rate, reserves, and future operating and development costs. Evaluated the Company’s independent reserve engineer by: ◦ ◦ Examining reports and assessing their scope of work and findings; and Assessing the competence, capability, and objectivity by evaluating their relevant professional qualifications and experience. Evaluated the reasonableness of reserves by testing the source financial information underlying the reserves and comparing the reserve volumes to historical production volumes. Evaluated the reasonableness of future operating and development costs by testing the source financial information underlying the estimate as of December 31, 2022, and conducting roll forward procedures up to March 31, 2023, to assesses any significant changes in assumptions, comparing future operating and development costs to historical results, and evaluating whether they are consistent with evidence obtained in other areas of the audit. • With the assistance of fair value specialists: ◦ ◦ Evaluated the future natural gas prices by independently developing a reasonable range of forecasts based on reputable third- party forecasts and market data and comparing those to the future prices selected by management; and Evaluated the reasonableness of the discount rate by testing the source information underlying the determination of the discount rate and developing a range of independent estimates and comparing those to the discount rate determined by management. Impairment of Capital Assets – Refer to Note 2 and 6 to the financial statements Critical Audit Matter Description The Company reviews all Cash Generating Units (“CGUs”) for indicators of potential impairment or reversal of impairment at each reporting date. As a result of allocating future capital spending to align with the Company’s long-term capital priorities, indicators of impairment were identified for Saskatchewan, France and US CGUs as of December 31, 2023. An impairment loss is recognized if the carrying amount of the CGU exceeds its recoverable amount. The recoverable amount is determined based on the higher of fair value less cost of disposal and value-in-use, using future after-tax cash flows of the underlying proved and probable oil and natural gas reserves. The Company engages an independent reserve engineer to estimate oil and natural gas reserves using estimates, assumptions, and engineering data. The development of the Company’s reserves and their future after-tax cash flows requires management to make significant estimates and assumptions related to future oil, natural gas liquids and natural gas prices (“future commodity prices”), discount rates, reserves, and future operating and development costs. As at December 31, 2023, the carrying amount of the CGUs exceeded the recoverable amount, which resulted in an impairment charge. Given the significant judgments made by management related to future commodity prices, discount rates, reserves, and future operating and development costs, these estimates and assumptions are subject to a high degree of estimation uncertainty. This required a high degree of auditor judgment and an increased extent of audit effort, including the involvement of fair value specialists. How the Critical Audit Matter Was Addressed in the Audit Our audit procedures related to future commodity prices, discount rates, reserves, and future operating and development costs used to determine the recoverable amount of the CGUs included the following, among others: • • • • Evaluated the effectiveness of the relevant controls, including those over the determination of the future commodity prices, discount rates, reserves, and future operating and development costs. Evaluated the Company’s independent reservoir engineer by: ◦ ◦ Examining reports and assessing their scope of work and findings; and Assessing the competence, capability, and objectivity by evaluating their relevant professional qualifications and experience. Evaluated the reasonableness of reserves by testing the source financial information underlying the reserves and comparing the reserve volumes to historical production volumes. Evaluated the reasonableness of future operating and development costs by testing the source financial information underlying the estimate, comparing future operating and development costs to historical results, and evaluating whether they are consistent with evidence obtained in other areas of the audit. • With the assistance of fair value specialists: ◦ ◦ Evaluated the future commodity prices by independently developing a reasonable range of forecasts based on reputable third- party forecasts and market data and comparing those to the future prices selected by management; and Evaluated the reasonableness of the discount rates by testing the source information underlying the determination of the discount rates and developing a range of independent estimates and comparing those to discount rates determined by management. Vermilion Energy Inc. ■ Page 71 ■ 2023 Annual Report Valuation of deferred tax asset - Refer to Notes 2 and 11 to the financial statements Critical Audit Matter Description The Company recognizes deferred income taxes for differences between the financial statement and tax basis of assets and liabilities at substantively enacted statutory tax rates in effect for the years in which the differences are expected to reverse. Deferred income tax assets are reduced to the amounts expected to be realized based on forecasts of future taxable income, specifically forecasts of future revenue (commodity price forecasts and forecasted reserves). The Company recorded a deferred income tax asset for Canada and Ireland primarily arising from past taxable losses in these jurisdictions. To determine whether it is probable that the deferred income tax assets in these jurisdictions will be realized, management makes assumptions related to the forecasts of future taxable income, specifically forecasts of future revenue (commodity price forecasts and forecasted reserves). Auditing the probability of the deferred income tax assets being realized and management’s commodity price forecasts and forecasted reserves involved a high degree of auditor judgement as the estimations made by management contain significant measurement uncertainty. This resulted in an increased extent of audit effort, which included the need to involve income tax specialists. How the Critical Audit Matter Was Addressed in the Audit Our audit procedures related to assessing the probability of the deferred income tax assets being realized and management’s forecasts of taxable income, specifically forecasts of future revenue (commodity price forecasts and forecasted reserves) to evaluate the deferred income tax assets in Canada and Ireland included the following, among others: • • • Evaluated the effectiveness of relevant controls, including those over the determination of the forecasts of future revenue, specifically commodity price forecasts and forecasted reserves. Evaluated management’s ability to accurately forecast future taxable income by comparing management’s assumptions to historical data and available market trends. Evaluated the reasonableness of management’s forecasts of future revenue by: ◦ ◦ Comparing the forecasts prepared by management’s expert to third party forecasts; and, Evaluating whether management’s estimates of commodity price forecasts and estimated reserves were consistent with the requirements of IAS 12 – Income taxes relating to the probability of forecasted future revenue and the length of the forecast period. /s/ Deloitte LLP Chartered Professional Accountants Calgary, Canada March 6, 2024 We have served as the Company's auditor since 2000. Vermilion Energy Inc. ■ Page 72 ■ 2023 Annual Report Consolidated Financial Statements Consolidated Balance Sheet thousands of Canadian dollars Note December 31, 2023 December 31, 2022 Assets Current Cash and cash equivalents Accounts receivable Crude oil inventory Derivative instruments Prepaid expenses Total current assets Derivative instruments Investment in securities Deferred taxes Exploration and evaluation assets Capital assets Total assets Liabilities Current Accounts payable and accrued liabilities Dividends payable Derivative instruments Income taxes payable Total current liabilities Derivative instruments Long-term debt Lease obligations Asset retirement obligations Deferred taxes Total liabilities Shareholders' Equity Shareholders' capital Contributed surplus Accumulated other comprehensive income Deficit Total shareholders' equity Total liabilities and shareholders' equity Approved by the Board (Signed “Manjit Sharma”) Manjit Sharma, Director 19 19 19 9 19 9 5 11 7 4, 6 19 13 9 19 9 12 10 8 11 13 141,456 242,926 57,333 313,792 68,007 823,514 76,107 73,261 182,051 198,379 4,882,509 6,235,821 380,370 16,227 732 298,745 696,074 21,050 914,015 33,001 1,159,063 380,970 3,204,173 4,142,566 43,348 109,302 (1,263,568) 3,031,648 6,235,821 13,836 373,651 19,657 162,843 144,459 714,446 132,598 56,366 125,533 270,593 5,691,522 6,991,058 481,444 13,058 55,845 341,698 892,045 — 1,081,351 51,507 1,087,757 477,340 3,590,000 4,243,794 35,409 123,505 (1,001,650) 3,401,058 6,991,058 (Signed “Dion Hatcher”) Dion Hatcher, Director Vermilion Energy Inc. ■ Page 73 ■ 2023 Annual Report Consolidated Statements of Net (Loss) Earnings and Comprehensive (Loss) Income thousands of Canadian dollars, except share and per share amounts Revenue Petroleum and natural gas sales Royalties Sales of purchased commodities Petroleum and natural gas revenue Expenses Purchased commodities Operating Transportation Equity based compensation Gain on derivative instruments Interest expense General and administration Foreign exchange (gain) loss Other expense (income) Accretion Depletion and depreciation Impairment expense (reversal) Gain on business combination Loss on disposition (Loss) earnings before income taxes Income tax (recovery) expense Deferred Current Windfall taxes Net (loss) earnings Other comprehensive (loss) income Currency translation adjustments Hedge accounting reserve, net of tax Fair value adjustment on investment in securities, net of tax Comprehensive (loss) income Net (loss) earnings per share Basic Diluted Weighted average shares outstanding ('000s) Basic Diluted Year Ended Note Dec 31, 2023 Dec 31, 2022 2,022,555 (191,694) 177,000 2,007,861 3,476,394 (306,017) 244,834 3,415,211 177,000 513,381 88,856 42,756 (414,072) 85,212 80,716 (7,906) 420 78,187 712,619 1,016,094 (439,487) 352,367 2,286,143 (278,282) 244,834 489,034 78,896 44,390 (134,907) 82,858 57,677 69,269 (11,149) 58,170 577,134 (192,094) — — 1,364,112 2,051,099 (190,193) 71,072 78,426 (40,695) 288,707 226,471 222,859 738,037 (237,587) 1,313,062 (16,468) 6,357 (4,092) (251,790) 60,543 5,599 28,896 1,408,100 (1.45) (1.45) 8.03 7.80 163,719 163,719 163,489 168,426 19 15 9 19 8 6, 7 6 4 6 11 11 5 16 16 Vermilion Energy Inc. ■ Page 74 ■ 2023 Annual Report Consolidated Statements of Cash Flows thousands of Canadian dollars Operating Net (loss) earnings Adjustments: Accretion Depletion and depreciation Impairment expense (reversal) Gain on business combination Loss on disposition Unrealized gain on derivative instruments Equity based compensation Unrealized foreign exchange (gain) loss Unrealized other expense Deferred tax (recovery) expense Asset retirement obligations settled Changes in non-cash operating working capital Cash flows from operating activities Investing Drilling and development Exploration and evaluation Acquisitions, net of cash acquired Acquisition of securities Dispositions Changes in non-cash investing working capital Cash flows used in investing activities Financing Net borrowings (repayments) on the revolving credit facility Issuance of senior unsecured notes Payments on lease obligations Repurchase of shares Cash dividends Cash flows used in financing activities Foreign exchange (loss) gain on cash held in foreign currencies Net change in cash and cash equivalents Cash and cash equivalents, beginning of period Cash and cash equivalents, end of period Supplementary information for cash flows from operating activities Interest paid Income taxes paid Note Dec 31, 2023 Dec 31, 2022 Year Ended (237,587) 1,313,062 8 6, 7 6 4 6 9 15 11 8 19 6 7 6 5 6 19 12 12 10 13 13 19 78,187 712,619 1,016,094 (439,487) 352,367 (179,707) 42,756 (12,438) — (190,193) (56,966) (61,117) 1,024,528 (569,110) (21,081) (142,281) (21,603) 197,007 (19,367) (576,435) (146,324) — (17,094) (94,838) (62,080) (320,336) (137) 127,620 13,836 141,456 84,471 306,911 58,170 577,134 (192,094) — — (540,801) 44,390 84,464 1,833 288,707 (37,514) 216,869 1,814,220 (528,056) (23,761) (510,309) (23,282) — 26,116 (1,059,292) (1,121,868) 499,037 (21,168) (71,659) (32,711) (748,369) 1,249 7,808 6,028 13,836 75,042 144,814 Vermilion Energy Inc. ■ Page 75 ■ 2023 Annual Report Consolidated Statements of Changes in Shareholders' Equity thousands of Canadian dollars Shareholders' capital Balance, beginning of year Vesting of equity based awards Equity based compensation Share-settled dividends on vested equity based awards Repurchase of shares Balance, end of year Contributed surplus Balance, beginning of year Equity based compensation Vesting of equity based awards Balance, end of year Accumulated other comprehensive income Balance, beginning of year Currency translation adjustments Hedge accounting reserve, net of tax Fair value adjustment on investment in securities, net of tax Balance, end of year Deficit Balance, beginning of year Net (loss) earnings Dividends declared Share-settled dividends on vested equity based awards Repurchase of shares Balance, end of year Year Ended December 31, 2023 December 31, 2022 Note 13 4,243,794 23,575 11,242 1,179 (137,224) 4,142,566 35,409 31,514 (23,575) 43,348 123,505 (16,468) 6,357 (4,092) 109,302 (1,001,650) (237,587) (65,248) (1,179) 42,096 (1,263,568) 4,241,773 44,811 13,699 4,377 (60,866) 4,243,794 49,529 30,691 (44,811) 35,409 28,467 60,543 5,599 28,896 123,505 (2,253,624) 1,313,062 (45,769) (4,377) (10,942) (1,001,650) 13 5 13 Total shareholders' equity 3,031,648 3,401,058 Vermilion Energy Inc. ■ Page 76 ■ 2023 Annual Report Description of equity reserves Shareholders’ capital Represents the recognized amount for common shares issued (net of equity issuance costs and deferred taxes) less the weighted-average carrying value of shares repurchased. The price paid to repurchase common shares is compared to the carrying value of the shares and the difference is recorded against deficit. Contributed surplus Represents the recognized value of unvested equity based awards that will be settled in shares. Once vested, the value of the awards are transferred to shareholders’ capital. Accumulated other comprehensive income Represents currency translation adjustments, hedge accounting reserve and fair value adjustments on investments. Currency translation adjustments result from translating the balance sheets of subsidiaries with a foreign functional currency to Canadian dollars at period-end rates. These amounts may be reclassified to net (loss) earnings if there is a disposal or partial disposal of a subsidiary. The hedge accounting reserve represents the effective portion of the change in fair value related to cash flow and net investment hedges recognized in other comprehensive income, net of tax and reclassified to the consolidated statement of net (loss) earnings in the same period in which the transaction associated with the hedged item occurs. Fair value adjustment on investment in securities, net of tax, are a result of changes in the fair value of investments that have been elected to be subsequently measured at fair value through other comprehensive income. Deficit Represents the cumulative net (loss) earnings less distributed earnings and surplus of the price paid to repurchase common shares of Vermilion Energy Inc. over the weighted-average carrying value of the shares repurchased. Vermilion Energy Inc. ■ Page 77 ■ 2023 Annual Report Notes to the Consolidated Financial Statements for the year ended December 31, 2023 and 2022 tabular amounts in thousands of Canadian dollars, except share and per share amounts 1. Basis of presentation Vermilion Energy Inc. and its subsidiaries (the “Company” or “Vermilion”) are engaged in the business of petroleum and natural gas exploration, development, acquisition, and production. Vermilion was incorporated in Canada and the Company’s registered office and principal place of business is located at 3500, 520, 3rd Avenue SW, Calgary, Alberta, Canada. These consolidated financial statements were approved and authorized for issuance by Vermilion’s Board of Directors on March 6, 2024. 2. Material accounting policies Accounting framework The consolidated financial statements are prepared in accordance with International Financial Reporting Standards (“IFRS”) as issued by the International Accounting Standards Board (“IASB”). Principles of consolidation The consolidated financial statements include the accounts of Vermilion Energy Inc. and its subsidiaries. Vermilion’s subsidiaries include entities in each of the jurisdictions that Vermilion operates as described in Note 3 (Segmented information) including: Canada, France, Netherlands, Germany, Ireland, Australia, the United States, and Central and Eastern Europe (Hungary, Slovakia, and Croatia). Vermilion Energy Inc. directly or indirectly through holding companies owns all of the voting securities of each material subsidiary. Transactions between Vermilion Energy Inc. and its subsidiaries have been eliminated. Vermilion accounts for joint operations by recognizing the Company’s share of assets, liabilities, income, and expenses. Exploration and evaluation assets Vermilion classifies costs as exploration and evaluation (“E&E”) assets when they relate to exploring and evaluating an area for which the Company has the license or right to explore and extract resources. E&E costs may include: geological and geophysical costs; land and license acquisition costs; and costs for the drilling, completion, and testing of exploration wells. E&E costs are reclassified to capital assets if the technical feasibility and commercial viability of the area can be determined. E&E assets are assessed for impairment prior to any reclassification. The technical feasibility and commercial viability of extracting the reserves is considered to be determinable when proved and probable reserves are identified. Costs incurred prior to the acquisition of the legal rights to explore an area are expensed as incurred. If reserves are not found within the license area or the area is abandoned, the related E&E costs are depreciated over a period not greater than five years. If an exploration license expires prior to the commencement of exploration activities, the cost of the exploration license is written off through depreciation in the year of expiration. Capital assets Vermilion recognizes capital assets at cost less accumulated depletion, depreciation, and impairment losses. Costs include directly attributable costs incurred for the drilling, completion, and tie-in of wells and the construction of production and processing facilities. When components of capital assets are replaced, disposed of, or no longer in use, they are derecognized. Gains and losses on disposal of capital assets are determined by comparing the proceeds of disposal compared to the carrying amount. Depletion and depreciation Capital assets are grouped into depletion units, which are groups of assets within a specific production area that have similar economic lives. Depletion units represent the lowest level of disaggregation for which costs are accumulated for the purposes of calculating depletion and depreciation. The net carrying value of each depletion unit is depleted using the unit of production method by reference to the ratio of production in the period to the total proved and probable reserves, taking into account the future development costs necessary to bring the applicable reserves into production. Vermilion Energy Inc. ■ Page 78 ■ 2023 Annual Report For the purposes of the depletion calculations, oil and gas reserves are converted to a common unit of measure on the basis of their relative energy content based on a conversion ratio of six thousand cubic feet of natural gas to one barrel of oil equivalent. Impairment of capital assets and exploration and evaluation assets Depletion units are aggregated into cash generating units (“CGUs”) for impairment testing. CGUs are the lowest level for which there are identifiable cash inflows that are largely independent of cash inflows of other groups of assets. CGUs are reviewed for indicators of potential impairment at each reporting date. E&E assets are tested for impairment when reclassified to capital assets or when indicators of potential impairment are identified. E&E assets are reviewed for indicators of potential impairment at each reporting date. If indicators of potential impairment are identified, E&E assets are tested for impairment as part of the CGU attributable to the jurisdiction in which the exploration area resides. If an indicator of potential impairment exists, the CGU’s carrying value is compared to its recoverable amount. A CGU’s recoverable amount is the higher of its fair value less costs of disposal and its value-in-use. If the carrying amount of a CGU exceeds its recoverable amount, an impairment loss is recognized to reduce the carrying value of the CGU to its recoverable amount. If an impairment loss has been recognized in a prior period, an assessment is performed at each reporting date to determine if there are indicators that the circumstances which led to the impairment loss have reversed. If the change in circumstances results in the recoverable amount being higher than the carrying value after the impairment loss, then the impairment loss (net of depletion that would otherwise have been recorded) is reversed. Lease obligations and right-of-use assets A contract is, or contains, a lease if the contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration. At the lease commencement date, a lease obligation is recognized at the present value of future lease payments, typically using the applicable incremental borrowing rate. A corresponding right-of-use asset is recognized at the amount of the lease obligation, adjusted for lease incentives received and initial direct costs. Vermilion does not recognize leases for short-term leases with a lease term of 12 months or less, or leases for low-value assets. Payments are applied against the lease obligation and interest expense is recognized on the lease obligations using the effective interest rate method. Depreciation is recognized on the right-of-use asset over the lease term. Cash and cash equivalents Cash and cash equivalents include cash on deposit with financial institutions and guaranteed investment certificates. Crude oil inventory Crude oil inventory is valued at the lower of cost or net realizable value. The cost of crude oil inventory produced includes related operating expense, royalties, and depletion determined on a weighted-average basis. Asset retirement obligations Vermilion recognizes a provision for asset retirement obligations when an event occurs giving rise to an obligation of uncertain timing or amount. Asset retirement obligations are recognized on the consolidated balance sheet as a long-term liability with a corresponding increase to E&E or capital assets. Asset retirement obligations reflect the present value of estimated future settlement costs. The discount rate used to calculate the present value is specific to the jurisdiction the obligation relates to and is reflective of current market assessment of the time value of money and risks specific to the liabilities that have not been reflected in the cash flow estimates. Asset retirement obligations are remeasured at each reporting period to reflect changes in market rates and estimated future settlement costs. Asset retirement obligations are increased each reporting period to reflect the passage of time with a corresponding charge to accretion expense. Revenue recognition Revenue associated with the sale of crude oil and condensate, natural gas, and natural gas liquids is measured based on the consideration specified in contracts with customers. Revenue from contracts with customers is recognized when or as Vermilion satisfies a performance obligation by transferring control of crude oil and condensate, natural gas, or natural gas liquids to a customer at contractually specified transfer points. This transfer coincides with title passing to the customer and the customer taking physical possession of the commodity. Vermilion principally satisfies its performance obligations at a point in time and the amounts of revenue recognized relating to performance obligations satisfied over time are not significant. Vermilion Energy Inc. ■ Page 79 ■ 2023 Annual Report Vermilion invoices customers for delivered products monthly and payment occurs shortly thereafter. Vermilion does not have any contracts where the period between the transfer of control of the commodity to the customer and payment by the customer exceeds one year. As a result, Vermilion does not adjust its revenue transactions to reflect significant financing components. Financial instruments On initial recognition, financial instruments are measured at fair value. Measurement in subsequent periods depends on the classification of the financial instrument as described below: • • • Fair value through profit or loss ("FVTPL"): Financial instruments under this classification include cash and cash equivalents and derivative assets and liabilities. Transaction costs under this classification are expensed as incurred. Fair value through other comprehensive income ("FVTOCI"): Financial instruments under this classification include derivative assets, investment in securities, and liabilities where hedge accounting is applied. Transaction costs under this classification are expensed as incurred. Amortized cost: Financial instruments under this classification include accounts receivable, accounts payable and accrued liabilities, dividends payable, lease obligations, and long-term debt. Transaction costs under this classification are included in the measurement of the financial instrument. Accounts receivable are measured net of a loss allowance equal to the lifetime expected credit loss. Equity based compensation Equity based compensation expense results from equity-settled awards issued under Vermilion’s long-term share-based compensation plans as well as the grant date fair value of Vermilion common shares issued under the Company’s bonus and employee share savings plans. Vermilion's long-term share-based compensation plans consist of the Long-term Incentive Plan (“LTIP”) and the Deferred Share Unit Plan ("DSU"). Equity-settled awards issued under the LTIP vest over a period of one to three years and awards issued under the DSU vest immediately upon granting. Equity based compensation expense for equity-settled plans is recognized over the vesting period with a corresponding adjustment to contributed surplus. The expense recognized is based on the grant date fair value of the awards, an estimate of the performance factor that will be achieved (if applicable), and an estimate of forfeiture rates based on historical vesting data. Dividends notionally accrue to the LTIP and are excluded in the determination of grant date fair values. When the awards are converted to Vermilion common shares, the amount recognized in contributed surplus is reclassified to shareholders’ capital. The grant date fair value of awards or Vermilion common shares issued is determined as the closing price of Vermilion’s common shares on the Toronto Stock Exchange on the grant date. Per share amounts Basic net (loss) earnings per share is calculated by dividing net (loss) earnings by the weighted-average number of shares outstanding during the period. Diluted net (loss) earnings per share is calculated by dividing net (loss) earnings by the diluted weighted-average number of shares outstanding during the period. The diluted weighted-average number of shares outstanding is the sum of the basic weighted-average number of shares outstanding and (to the extent inclusion reduces diluted net (loss) earnings per share) the number of shares issuable for equity-settled awards determined using the treasury stock method. The treasury stock method assumes that the unrecognized equity based compensation expense are deemed proceeds used to repurchase Vermilion common shares at the average market price during the period. Vermilion Energy Inc. ■ Page 80 ■ 2023 Annual Report Foreign currency translation Vermilion Energy Inc.’s functional and presentation currency is the Canadian dollar. Vermilion has subsidiaries that transact and operate in countries other than Canada and have functional currencies other than the Canadian dollar. Foreign currency translation includes the translation of foreign currency transactions and the translation of foreign operations. Foreign currency transaction translation occurs when translating transactions and balances in foreign currencies to the applicable functional currency of Vermilion Energy Inc. and its subsidiaries. Gains and losses from foreign currency transactions are recorded as foreign exchange gains or losses in the statement of Net (loss) earnings. Foreign currency transaction translation occurs as follows: • • • Income and expenses are translated at the prevailing rates on the date of the transaction. Non-monetary assets or liabilities are carried at the prevailing rates on the date of the transaction. Monetary items, including intercompany loans that are not deemed to represent net investments in a foreign subsidiary, are translated at the prevailing rates at the balance sheet date. Foreign operation translation occurs when translating the financial statements of non-Canadian functional currency subsidiaries to the Canadian dollar and when translating intercompany loans that are deemed to represent net investments in a foreign subsidiary. Gains and losses from foreign operation translations are recorded as currency translation adjustments in the statement of comprehensive income. Foreign operation translation occurs as follows: • • Income and expenses are translated at the average exchange rates for the period. Assets and liabilities are translated at the prevailing rates on the balance sheet date. Income taxes Deferred tax assets and liabilities are calculated using the balance sheet method. Deferred tax assets and liabilities are recognized for the estimated effect of any temporary differences between the amounts recognized on Vermilion’s consolidated balance sheet and the respective tax basis. This calculation uses enacted or substantively enacted tax rates that are expected to be in effect when the temporary differences are expected to reverse. The effect of a change in tax rates on deferred taxes is recognized in the period the related legislation is substantively enacted. Deferred tax assets are recognized to the extent that it is probable that future taxable profits will be available against which the deductible temporary differences can be used. Deferred tax assets are reviewed at each reporting date and are reduced to the extent it is no longer probable that the related tax benefit will be realized. Business combinations Acquisitions of corporations or groups of assets are accounted for as business combinations using the acquisition method if the acquired assets constitute a business. Under the acquisition method, assets acquired and liabilities assumed in a business combination (with the exception of deferred tax assets and liabilities) are measured at their fair values. Deferred tax assets or liabilities arising from the assets acquired and liabilities assumed are measured in accordance with the policies described in "Income taxes" above. If applicable, the excess or deficiency of the fair value of net assets acquired compared to consideration paid is recognized as a gain on business combination or as goodwill on the consolidated balance sheet. Acquisition-related costs incurred to effect a business combination are expensed in the period incurred. As part of the assessment to determine if the acquisition constitutes a business, Vermilion may elect to apply the concentration test on a transaction by transaction basis. The test is met if substantially all of the fair value related to the gross assets acquired is concentrated in a single identifiable asset (or group of similar assets) resulting in the acquisition not being deemed a business and recorded as an asset acquisition. Vermilion Energy Inc. ■ Page 81 ■ 2023 Annual Report Segmented information Vermilion has a decentralized business unit structure designed to manage assets in each country the Company operates. Each of Vermilion's operating segments derives its revenues solely from the production and sale of petroleum and natural gas. Vermilion’s Corporate segment aggregates costs incurred at the Company’s Corporate head office located in Calgary, Alberta, Canada as well as costs incurred relating to Vermilion’s exploration and production activities in Hungary, Slovakia, and Croatia (Central and Eastern Europe). These operating segments have similar economic characteristics as they do not currently generate material revenue. Vermilion’s chief operating decision maker regularly reviews fund flows from operations generated by each of Vermilion’s operating segments. Fund flows from operations is a measure of profit or loss that provides the chief operating decision maker with the ability to assess the profitability of each operating segment and, correspondingly, the ability of each operating segment to fund its share of dividends, asset retirement obligations, and capital investments. Management judgments and estimation uncertainty The preparation of the consolidated financial statements in accordance with IFRS requires management to make judgments, estimates, and assumptions that affect the reported amount of assets, liabilities, income, and expenses. Actual results could differ significantly from these estimates. Key areas where management has made judgments, estimates, and assumptions are described below. The determination of whether indicators of impairment or impairment reversals: • Determining whether there are indicators of impairment or impairment reversals are based on management's assessments of the changes in estimates for future commodity prices, costs, discount rates, or reserves. Changes in these estimates and assumptions can directly impact the calculated fair value of capital assets and therefore could be indicators of impairment or impairment reversals. In addition, change in the Vermilion's market capitalization relative to its book value could be an indicator of impairment. The measurement of the fair value of capital assets acquired in a business combination and the determination of the recoverable amount of cash generating units ("CGU"): • • Calculating the fair value of capital assets acquired in a business combination and the recoverable amount of CGUs (in the assessment of impairments or reversals of previous impairments if indicators of impairment or impairment reversal are identified) are based on estimated future commodity prices, discount rates and estimated reserves. Reserve estimates are based on: engineering data, estimated future commodity prices, expected future rates of production, and assumptions regarding the timing and amount of future expenditures. Changes in these estimates and assumptions can directly impact the calculated fair value of capital assets acquired (and thus the resulting goodwill or gain on business combination) and the recoverable amount of a CGU (and thus the resulting impairment loss or recovery). In addition, the recoverable amount of a CGU is impacted by the composition of CGUs, which are subject to management’s judgment of the lowest level at which there are identifiable cash inflows that are largely independent of the cash inflows of other groups of assets. The factors used by Vermilion to determine CGUs vary by jurisdiction due to their unique operating and geographic conditions. In general, Vermilion will assess the following factors: geographic proximity of the assets within a group to one another, geographic proximity of the group of assets to other groups of assets, homogeneity of the production from the group of assets and the sharing of infrastructure used to process and/or transport production. Changes in these judgments can directly impact the calculated recoverable amount of a CGU (and thus the resulting impairment loss or recovery). The measurement of the carrying value of asset retirement obligations on the balance sheet, including the fair value and subsequent carrying value of asset retirement obligations assumed in a business combination: • Asset retirement obligations are based on judgments regarding regulatory requirements, estimates of future costs, assumptions on the expected timing of expenditures, and estimates of the underlying risk inherent to the obligation. The carrying balance of asset retirement obligations and accretion expense may differ due to changes in: laws and regulations, technology, the expected timing of expenditures, and market conditions affecting the discount rate applied. The recognition and measurement of deferred tax assets and liabilities: • • Tax interpretations, regulations, and legislation in the various jurisdictions in which Vermilion and its subsidiaries operate are subject to change and interpretation. Changes in laws and interpretations can affect the timing of the reversal of temporary tax differences, the tax rates in effect when such differences reverse and Vermilion’s ability to use tax losses and other tax pools in the future. The Company’s income tax filings are subject to audit by taxation authorities in numerous jurisdictions and the results of such audits may increase or decrease the tax liability. The determination of tax amounts recognized in the consolidated financial statements are based on management’s assessment of the tax positions, which includes consideration of their technical merits, communications with tax authorities and management’s view of the most likely outcome. The extent to which deferred tax assets are recognized are based on estimates of future profitability. These estimates are based on estimated future commodity prices and estimates of reserves. Judgments, estimates, and assumptions inherent in reserve estimates are described above. Vermilion Energy Inc. ■ Page 82 ■ 2023 Annual Report The measurement of lease obligations and corresponding right-of-use assets: • The measurement of lease obligations are subject to management's judgments of the applicable incremental borrowing rate and the expected lease term. The carrying balance of the right-of-use assets, lease obligations, and the resulting interest and depletion and depreciation expense, may differ due to changes in the market conditions and expected lease terms. Applicable incremental borrowing rates are based on judgments of the economic environment, term, currency, and the underlying risk inherent to the asset. Lease terms are based on assumptions regarding cancellation and extension terms that allow for operational flexibility based on future market conditions. Vermilion Energy Inc. ■ Page 83 ■ 2023 Annual Report 3. Segmented information Total assets Drilling and development Exploration and evaluation Crude oil and condensate sales NGL sales Natural gas sales Sales of purchased commodities Canada 1,805,049 288,223 — 621,985 68,753 170,653 USA France Netherlands Germany Ireland Australia Corporate Total Year Ended December 31, 2023 425,532 1,137,648 280,532 1,507,026 6,235,821 254,884 91,977 — 587,824 48,297 — 129,775 285,626 15,240 6,143 — — — — 237,326 44,147 — 2,306 — 48,463 11,248 57,464 — 184,548 138,017 302,330 — — 20,283 26,005 — 74 — — — — 36,381 — — — — 1,715 9,833 569,110 21,081 — — 3,260 177,000 1,133,611 83,993 804,951 177,000 (1,711) (191,694) Royalties (103,511) (41,487) (37,425) (1,567) (5,993) Revenue from external customers 757,880 109,671 248,201 185,287 189,488 302,404 36,381 178,549 2,007,861 Purchased commodities Transportation Operating — — (43,163) (751) (24,511) — — — — (13,333) (7,098) — — (177,000) (177,000) — (88,856) (233,417) (23,424) (80,134) (39,157) (43,857) (39,464) (52,360) (1,568) (513,381) General and administration (96,296) (9,734) (20,642) (8,317) (13,104) (19,054) (8,182) 94,613 PRRT Corporate income taxes Windfall taxes Interest expense Realized gain on derivative instruments Realized foreign exchange loss Realized other expense — (53) — — — — — — — — — — — — — — — — 20,860 (14,313) (48,349) (28,533) (715) — — — — — — — — — — — — — — — — — — — — 13 — — — — — — 18 (78,426) (85,212) (80,716) 20,860 (91,932) (78,426) (85,212) 234,365 234,365 (4,532) (420) (4,532) (420) Fund flows from operations 384,951 75,762 108,601 89,464 90,661 236,073 (3,288) 160,387 1,142,611 Total assets Drilling and development Exploration and evaluation Crude oil and condensate sales NGL sales Natural gas sales Sales of purchased commodities Canada 3,612,487 275,203 — 910,863 114,128 319,293 — USA France Netherlands Germany Ireland Australia Corporate Total Year Ended December 31, 2022 618,116 63,353 — 823,544 44,250 2 130,150 365,431 19,385 16,698 — — — — 240,276 21,629 23 2,119 — 398,612 465,643 25,087 1,070 62,464 — 3,030 — 15 — 560,738 418,796 324,330 — — — — 249,253 95,173 — 221,187 — — — — 583,127 6,991,058 331 22,666 528,056 23,761 — — 1,692,229 133,513 10,797 1,650,652 244,834 244,834 (3,488) (306,017) Royalties (196,005) (44,427) (40,353) (512) (21,232) Revenue from external customers 1,148,279 121,806 325,078 562,345 460,028 324,345 221,187 252,143 3,415,211 Purchased commodities — — — (44,849) (618) (20,100) — — — — (9,751) (3,578) — — (244,834) (244,834) — (78,896) (240,899) (27,372) (57,588) (45,903) (41,523) (16,580) (57,478) (1,691) (489,034) Transportation Operating General and administration (28,643) (5,863) (16,444) (4,255) (6,949) 122 PRRT Corporate income taxes Windfall tax Interest expense Realized loss on derivative instruments Realized foreign exchange gain Realized other income — (10) — — — — — — — — — — — — — — — (29,889) (150,647) (31,513) — — — — — — — — — — — — — — — — — — — — — — (4,964) (18,318) 9,319 — (57,677) (18,318) 5,016 (1,110) (208,153) — — — — — (222,859) (222,859) (82,858) (82,858) (405,894) (405,894) 15,195 12,982 15,195 12,982 Fund flows from operations 833,878 87,953 201,057 361,540 370,292 304,309 145,443 (669,607) 1,634,865 Vermilion Energy Inc. ■ Page 84 ■ 2023 Annual Report Reconciliation of fund flows from operations to net (loss) earnings: Fund flows from operations Equity based compensation Unrealized gain on derivative instruments Unrealized foreign exchange gain (loss) Accretion Depletion and depreciation Deferred tax recovery (expense) Gain on business combination Loss on disposition Impairment (expense) reversal Unrealized other expense Net (loss) earnings 4. Business combination Equinor Energy Ireland Limited Year Ended Dec 31, 2023 1,142,611 (42,756) 179,707 12,438 (78,187) (712,619) 190,193 439,487 (352,367) (1,016,094) — (237,587) Dec 31, 2022 1,634,865 (44,390) 540,801 (84,464) (58,170) (577,134) (288,707) — — 192,094 (1,833) 1,313,062 On March 31, 2023, Vermilion purchased 100% of the shares outstanding of Equinor Energy Ireland Limited ("EEIL") from Equinor ASA. The acquisition adds an incremental 36.5% interest in the Corrib Natural Gas Project, increasing Vermilion's operated interest to 56.5%. The total consideration paid and the fair value of the assets acquired and liabilities assumed at the date of acquisition are detailed in the table below. Cash consideration paid Cash acquired Capital assets Acquired working capital deficit Asset retirement obligations Derivative liability Deferred tax liability Net assets acquired Gain on business combination Total net assets acquired, net of gain on business combination Consideration 488,893 Allocation of consideration 400,002 768,026 (109,134) (42,277) (51,789) (36,448) 928,380 (439,487) 488,893 The gain on the business combination primarily resulted from increases in working capital and the fair value of capital assets from when the purchase and sale agreement was entered into in November 2021 and when the acquisition closed in March 2023 due to significant increases in European natural gas prices throughout 2022 and Q1 2023. The results of operations from the assets acquired and liabilities assumed have been included in Vermilion's consolidated financial statements beginning March 31, 2023 and have contributed revenues net of royalties of $161.7 million and net earnings of $43.6 million. Had the acquisition occurred on January 1, 2023, consolidated petroleum and natural gas revenue would have been $2,098.2 million and consolidated net loss would have been 182.6 million for the year ended December 31, 2023. Vermilion Energy Inc. ■ Page 85 ■ 2023 Annual Report 5. Investment in securities The total consideration paid and the fair value of the investments acquired are detailed in the table below: Balance at January 1 Acquisition of securities Fair value adjustment (1) Balance at December 31 (1) The investment is classified as a level 1 instrument on the fair value hierarchy and therefore uses observable inputs when making fair value adjustments. 2023 56,366 21,603 (4,708) 73,261 2022 — 23,282 33,084 56,366 6. Capital assets The following table reconciles the change in Vermilion's capital assets: Balance at January 1 Acquisitions Dispositions Additions Increase in right-of-use assets Transfers from exploration and evaluation assets Impairment (expense) reversal Depletion and depreciation Changes in asset retirement obligations Foreign exchange Balance at December 31 Cost Accumulated depletion, depreciation, and impairment Balance at December 31 Impairment 2023 5,691,522 836,295 (676,471) 569,110 3,103 40,521 (1,016,094) (699,343) 138,239 (4,373) 4,882,509 12,966,256 (8,083,747) 4,882,509 2022 4,824,195 572,535 — 528,056 13,871 1,223 192,094 (546,381) 65,462 40,467 5,691,522 12,058,520 (6,366,998) 5,691,522 In the fourth quarter of 2023, indicators of impairment were present in our France CGU due to changes in forecasted cost assumptions and in our Saskatchewan and United States CGUs due to negative technical revisions. As a result of the indicators of impairment, the Company performed impairment calculations on the identified CGUs and the recoverable amounts were determined using fair value less costs to sell, which considered future after-tax cash flows from proved plus probable reserves and an after-tax discount rate of 13% for Saskatchewan and 15.0% for France and United States. Based on the results of the impairment tests completed, the Company recognized non-cash impairment charges of $1.0 billion. Inputs used in the measurement of capital assets are not based on observable market data and fall within level 3 of the fair value hierarchy. The following benchmark price forecasts were used to calculate the recoverable amounts: Brent Crude ($ US/bbl) (1) WTI Crude ($ US/bbl) (1) Light Sour Crude ($/bbl) (1) SK Plant Gate Gas - Spot Gas ($/MMbtu) (1) Henry Hub Gas ($ US/MMbtu) (1) 2026 2025 2029 2024 2027 2033 (2) 2028 92.10 78.00 79.18 80.36 81.79 83.41 85.09 86.79 88.52 90.29 73.67 74.98 76.14 77.66 79.22 80.80 82.42 84.06 85.75 87.46 93.35 95.50 96.53 98.46 100.43 102.44 104.49 106.58 108.71 110.88 4.43 4.62 3.15 3.64 4.25 4.44 1.98 2.75 4.08 4.27 3.91 4.10 3.99 4.18 3.83 4.02 4.16 4.35 4.34 4.53 2031 2030 2032 (1) (2) The forecast benchmark prices listed are adjusted for quality differentials, heat content, transportation and marketing costs and other factors specific to the Company’s operations when determining recoverable amounts. In 2033 and beyond, commodity price forecasts are inflated at a rate of 2.0% per annum. Vermilion Energy Inc. ■ Page 86 ■ 2023 Annual Report The following are the results of tests completed, recoverable amounts, and sensitivity impacts which would increase the impairments taken: Operating Segment Canada France United States Total (1) CGU Saskatchewan France (1) United States Impairment 542,937 226,858 246,299 1,016,094 Recoverable Amount 704,636 523,303 239,179 1,467,118 1% increase in discount rate 42,657 24,653 12,819 80,129 5% decrease in pricing 79,452 70,035 38,290 187,777 During 2023, Vermilion finalized an evaluation of the management and organization of Vermilion’s assets in France resulting in a combination of its Neocomian, Chaunoy, Champotran, and Aquitaine Basin CGUs into the France CGU. If these CGUs were not combined, impairment recognized would have increased by $23.2 million. Southeast Saskatchewan disposition In March 2023, Vermilion sold non-core assets in southeast Saskatchewan for net proceeds of $182.2 million and resulted in a loss on disposition of $226.8 million. The book value of the net assets disposed of was $409.0 million and consisted of $534.0 million of capital assets, $25.9 million of exploration and evaluation assets, and $150.9 million of asset retirement obligations. United States disposition In December 2023, Vermilion sold non-core assets in Wyoming for net proceeds of $16.3 million and resulted in a loss on disposition of $125.5 million. Minor acquisition In March 2023, Vermilion completed a minor acquisition of Alberta assets for total consideration of $19.0 million where $33.9 million of capital assets and $14.9 million of asset retirement obligations were recognized. Right-of-use assets The following table discloses the carrying balance and depreciation charge relating to right-of-use assets by class of underlying asset as at and for the year ended December 31, 2023: ($M) Office space Gas processing facilities Oil storage facilities Vehicles and equipment Total As at Dec 31, 2023 As at Dec 31, 2022 Depreciation Balance Depreciation 8,115 7,691 2,667 5,433 23,906 25,893 6,326 7,037 9,760 49,016 8,328 7,691 2,429 4,716 23,164 Balance 31,199 13,415 8,970 13,944 67,528 Vermilion Energy Inc. ■ Page 87 ■ 2023 Annual Report 7. Exploration and evaluation assets The following table reconciles the change in Vermilion's exploration and evaluation assets: Balance at January 1 Acquisitions Additions Dispositions Changes in asset retirement obligations Transfers to capital assets Depreciation Foreign exchange Balance at December 31 Cost Accumulated depreciation Carrying amount at December 31 8. Asset retirement obligations The following table reconciles the change in Vermilion’s asset retirement obligations: Balance at January 1 Additional obligations recognized Dispositions Changes in estimated abandonment timing and costs Obligations settled Accretion Changes in rates Foreign exchange Balance at December 31 2023 270,593 — 21,081 (25,862) (980) (40,521) (27,386) 1,454 198,379 432,345 (233,966) 198,379 2023 1,087,757 60,012 (151,566) 1,159 (56,966) 78,187 133,575 6,905 1,159,063 2022 233,290 43,227 23,761 — 646 (1,223) (30,503) 1,395 270,593 476,571 (205,978) 270,593 2022 1,000,554 5,184 — 207,919 (37,514) 58,170 (145,555) (1,001) 1,087,757 Vermilion calculated the present value of the obligations using a credit-adjusted risk-free rate, calculated using a credit spread of 3.6% as at December 31, 2023 (December 31, 2022 - 4.5%) added to risk-free rates based on long-term, risk-free government bonds. Vermilion's credit spread is determined using the Company's expected cost of borrowing at the end of the reporting period. The country-specific risk-free rates used as inputs to discount the obligations were as follows: Canada United States France Netherlands Germany Ireland Australia Dec 31, 2023 3.0 % 4.2 % 3.0 % 2.1 % 2.3 % 2.7 % 4.0 % Dec 31, 2022 3.3 % 4.1 % 3.4 % 2.7 % 2.5 % 3.2 % 4.2 % Vermilion has estimated the asset retirement obligations based on current cost estimates of $2.2 billion (2022 - $2.3 billion). Current cost estimates are inflated to the estimated time of abandonment using inflation rates of between 1.3% and 5.5% (2022 - between 1.6% and 4.2%), resulting in inflated cost estimates of $3.4 billion (2022 - $3.7 billion). These payments are expected to be made over the next 60 years, with the majority of the costs incurred in the first 40 years. Vermilion Energy Inc. ■ Page 88 ■ 2023 Annual Report A 0.5% increase/decrease in the discount rate applied to asset retirement obligations would decrease/increase asset retirement obligations by approximately $70.1 million. A one-year increase/decrease in the expected timing of abandonment spend would decrease/increase asset retirement obligations by approximately $34.0 million. 9. Derivative instruments The following table reconciles the change in the fair value of Vermilion’s derivative instruments: Fair value of contracts, beginning of year Reversal of opening contracts settled during the year Assumed in acquisitions Realized gain (loss) on contracts settled during the year Unrealized gain during the year on contracts outstanding at the end of the year Unwinding of contracts assumed in acquisitions Net receipt from counterparties on contract settlements during the year Fair value of contracts, end of year Comprised of: Current derivative asset Current derivative liability Non-current derivative asset Non-current derivative liability Fair value of contracts, end of year The gain on derivative instruments for 2023 and 2022 were comprised of the following: Realized (gain) loss on contracts settled during the year Reversal of opening contracts settled during the year Unwinding of contracts assumed in acquisitions Unrealized gain on contracts outstanding at the end of the year Gain on derivative instruments Year Ended Dec 31, 2023 239,596 (43,267) 51,866 234,365 171,448 (51,526) (234,365) 368,117 313,792 (732) 76,107 (21,050) 368,117 Dec 31, 2022 (300,865) 164,208 (339) (405,894) 376,593 — 405,893 239,596 162,843 (55,845) 132,598 — 239,596 Year Ended Dec 31, 2023 (234,365) 43,267 (51,526) (171,448) (414,072) Dec 31, 2022 405,894 (164,208) — (376,593) (134,907) Vermilion executes derivative instruments where there is an underlying exposure to offset the position. Consistent with our accounting policy we do not match unrealized gains / losses on these contracts with the underlying exposure. Please refer to Note 19 (Supplemental information) for a listing of Vermilion's outstanding derivative instruments as at December 31, 2023. Vermilion Energy Inc. ■ Page 89 ■ 2023 Annual Report 10. Leases Vermilion had the following future commitments associated with its lease obligations: ($M) Less than 1 year 1 - 3 years 3 - 5 years After 5 years Total lease payments Amounts representing interest Present value of net lease payments Current portion of lease obligations Non-current portion of lease obligations Total cash outflow Interest on lease liabilities As at Dec 31, 2023 24,029 31,077 4,591 2 59,699 (5,630) 54,069 (21,068) 33,001 21,002 3,908 Dec 31, 2022 23,588 40,374 16,246 177 80,385 (9,392) 70,993 (19,486) 51,507 25,422 4,254 Vermilion Energy Inc. ■ Page 90 ■ 2023 Annual Report 11. Taxes  The following table reconciles Vermilion’s deferred tax asset and liability: Deferred tax assets: Non-capital losses Derivative contracts Other Stock based compensation Asset retirement obligations Capital assets Unrealized foreign exchange Deferred tax assets Deferred tax liabilities: Derivative contracts Asset retirement obligations Capital assets Stock based compensation Other Unrealized foreign exchange Non-capital losses Deferred tax liabilities As at Dec 31, 2023 Dec 31, 2022 632,870 (89,619) (437) 6,757 77,292 (447,463) 2,651 182,051 — 105,147 279,889 — 6,275 — (10,341) 380,970 200,781 — 39 — 5,818 (81,105) — 125,533 58,941 100,670 734,146 (5,805) (16,322) (4,282) (390,008) 477,340 Income tax expense differs from the amount that would have been expected if the reported earnings had been subject only to the statutory Canadian income tax rate as follows: (Loss) earnings before income taxes Canadian corporate tax rate Expected tax (recovery) expense (Decrease) increase in taxes resulting from: Petroleum resource rent tax rate (PRRT) differential (1) Foreign tax rate differentials (2) (3) Equity based compensation expense Amended returns and changes to estimated tax pools and tax positions Statutory rate changes and the estimated reversal rates on temporary differences (3) Derecognition (recognition) of deferred tax assets Non-taxable amounts related to business combinations Windfall taxes (3) Other non-deductible items Provision for income taxes (1) Year Ended Dec 31, 2023 (278,282) 24.35 % (67,762) Dec 31, 2022 2,051,099 24.60 % 504,570 (14,177) 33,404 (1,914) (7,664) (17,474) 202,216 (172,692) 78,426 (73,058) (40,695) 13,729 101,701 (11,610) (5,691) 14,274 (118,304) — 222,859 16,509 738,037 (2) (3) In Australia, current taxes include both corporate income tax rates and PRRT. For both 2023 and 2022, corporate income tax rates were applied at a rate of 30% and PRRT was applied at a rate of 40%. The applicable tax rates for 2023 were: 25.8% in France, 50.0% in the Netherlands, 31.2% in Germany, 25.0% in Ireland, and 21.0% in the United States (2022: 25.8% in France, 50.0% in the Netherlands, 31.3% in Germany, 25.0% in Ireland, and 21.0% in the United States). On October 6, 2022 the Council of the European Union adopted a regulation that implemented a temporary windfall tax on the profits of oil and gas producers resident in the European Union. This windfall tax was referred to as a temporary solidarity contribution and was calculated on the amount by which the taxable profits for the elected years exceeded the greater of zero and 120% of the average taxable profits for the 2018 to 2021 period. The regulation required Member States to implement the temporary solidarity contribution at a minimum rate of 33% while providing Member States with the option to apply the temporary solidarity contribution to fiscal years beginning on or after January 1, 2022, January 1, 2023, or both. The temporary solidarity contribution does not apply to 2024 or later years and is considered a tax pursuant to IAS 12 “Income Taxes”. Vermilion Energy Inc. ■ Page 91 ■ 2023 Annual Report The following table summarizes the manner of implementation of the temporary solidarity contribution by the Member States in which Vermilion operates: Jurisdiction France Netherlands (1) Germany Ireland (1) 2024 N/A N/A 33.0 % 75.0 % 2023 33.0 % 33.0 % 33.0 % 75.0 % For 2023 and 2024, Netherlands has implemented a windfall royalty which, for natural gas sales, is calculated as 65% of the excess of the realized price for a subject year versus the threshold price of €0.50/Nm3 (€13.40/mcf). This royalty is deductible against current income taxes. At December 31, 2023, Vermilion had $3.2 billion (2022 - $2.4 billion) of unused tax losses of which $1.4 billion (2022 - $1.4 billion) relates to Vermilion's Canada segment and expire between 2030 and 2042. The majority of the remaining unused tax losses relate to Vermilion's Ireland segment and do not expire. At December 31, 2023, Vermilion derecognized $202.2 million (2022 - recognized $118.3 million) of deferred income tax assets relating to the Canada, USA, Ireland and Australia segments as there is uncertainty as to the Company's ability to fully utilize such losses based on the forecasted commodity prices in effect as at December 31, 2023. The aggregate amount of temporary differences associated with investments in subsidiaries for which deferred tax liabilities have not been recognized as at December 31, 2023 is approximately $1.0 billion (2022 – approximately $0.7 billion). In December 2021, the Organization for Economic Co-operation and Development (“OECD”) issued model rules for a new global minimum tax framework (“Pillar Two”). The objective of Pillar Two is to ensure that large multinational enterprises are subjected to a minimum 15% effective tax rate in each jurisdiction in which they operate. Most of the countries where Vermilion operates are in the process of enacting, or have enacted, tax legislation to comply with Pillar Two with effect from January 1, 2024. The Company expects that Pillar Two will not have a material impact on income tax expense. In May 2023, the IASB issued amendments to IAS 12, “Income Taxes” (“IAS 12”) to address the impacts and additional disclosure requirements related to Pillar Two. Vermilion has applied the mandatory exception required by IAS 12 and accordingly has not accounted for any related deferred income tax assets or liabilities. 12. Long-term debt The following table summarizes Vermilion’s outstanding long-term debt: Revolving credit facility 2025 senior unsecured notes 2030 senior unsecured notes Long-term debt As at Dec 31, 2023 — 395,839 518,176 914,015 Dec 31, 2022 147,666 404,463 529,222 1,081,351 The fair value of the revolving credit facility is equal to its carrying value due to the use of short-term borrowing instruments at market rates of interest. The fair value of the 2025 senior unsecured notes as at December 31, 2023 was $392.7 million (December 31, 2022 - $391.3 million). The fair value of the 2030 senior unsecured notes as at December 31, 2023 was $511.7 million (December 31, 2022 - $496.8 million). Vermilion Energy Inc. ■ Page 92 ■ 2023 Annual Report The following table reconciles the change in Vermilion’s long-term debt: Balance at January 1 Net repayments on the revolving credit facility Issuance of 2030 senior unsecured notes Amortization of transaction costs Foreign exchange Balance at December 31 Revolving credit facility 2023 1,081,351 (146,324) — 2,182 (23,194) 914,015 2022 1,651,569 (1,121,868) 499,037 1,833 50,780 1,081,351 As at December 31, 2023, Vermilion had in place a bank revolving credit facility maturing May 29, 2027 with the following terms: Total facility amount Amount drawn Letters of credit outstanding Unutilized capacity As at Dec 31, 2023 1,600,000 — (18,116) 1,581,884 Dec 31, 2022 1,600,000 (147,666) (13,527) 1,438,807 The facility can be extended from time to time at the option of the lenders and upon notice from Vermilion. If no extension is granted by the lenders, the amounts owing pursuant to the facility are due at the maturity date. The facility is secured by various fixed and floating charges against the subsidiaries of Vermilion. On May 19, 2023, the maturity date of the facility was extended to May 28, 2027 (previously May 29, 2026) and the total facility amount of $1.6 billion was unchanged. As at December 31, 2023, the revolving credit facility was undrawn. The facility bears interest at a rate applicable to demand loans plus applicable margins. As at December 31, 2023, the revolving credit facility was subject to the following financial covenants: Financial covenant Consolidated total debt to consolidated EBITDA Consolidated total senior debt to consolidated EBITDA Consolidated EBITDA to consolidated interest expense Limit Dec 31, 2023 As at Less than 4.0 Less than 3.5 Greater than 2.5 0.65 — 17.33 Dec 31, 2022 0.51 0.07 27.10 The financial covenants include financial measures defined within the revolving credit facility agreement that are not defined under IFRS. These financial measures are defined by the revolving credit facility agreement as follows: • • • • Consolidated total debt: Includes all amounts classified as “Long-term debt” and “Lease obligations” (including the current portion included within "Accounts payable and accrued liabilities" but excluding operating leases as defined under IAS 17) on the consolidated balance sheet. Consolidated total senior debt: Consolidated total debt excluding unsecured and subordinated debt. Consolidated EBITDA: Consolidated net (loss) earnings before interest, income taxes, depreciation, accretion and certain other non-cash items, adjusted for the impact of the acquisition of a material subsidiary. Consolidated total interest expense: Includes all amounts classified as "Interest expense", but excludes interest on operating leases as defined under IAS 17. In addition, our revolving credit facility has provisions relating to our liability management ratings in Alberta and Saskatchewan whereby if our security adjusted liability management ratings fall below specified limits in a province, a portion of the asset retirement obligations are included in the definitions of consolidated total debt and consolidated total senior debt. An event of default occurs if our security adjusted liability management ratings breach additional lower limits for a period greater than 90 days. As of December 31, 2023, Vermilion's liability management ratings were higher than the specified levels, and as such, no amounts relating to asset retirement obligations were included in the calculation of consolidated total debt and consolidated total senior debt. As at December 31, 2023 and December 31, 2022, Vermilion was in compliance with the above covenants. Vermilion Energy Inc. ■ Page 93 ■ 2023 Annual Report 2025 senior unsecured notes On March 13, 2017, Vermilion issued US $300.0 million of senior unsecured notes at par. The notes bear interest at a rate of 5.625% per annum, to be paid semi-annually on March 15 and September 15. The notes mature on March 15, 2025. As direct senior unsecured obligations of Vermilion, the notes rank equally with existing and future senior unsecured indebtedness of the Company. The senior unsecured notes were recognized at amortized cost and include the transaction costs directly related to the issuance. Subsequent to March 15, 2023, Vermilion may redeem some or all of the senior unsecured notes at a 100.000% redemption price plus any accrued and unpaid interest. 2030 senior unsecured notes On April 26, 2022, Vermilion closed a private offering of US $400.0 million 8-year senior unsecured notes. The notes were priced at 99.241% of par, mature on May 1, 2030, and bear interest at a rate of 6.875% per annum. Interest is paid semi-annually on May 1 and November 1, commencing on November 1, 2022. The notes are senior unsecured obligations of Vermilion and rank equally with existing and future senior unsecured indebtedness. The senior unsecured notes were recognized at amortized cost and include the transaction costs directly related to the issuance. Vermilion may, at its option, redeem the notes prior to maturity as follows: • • • On or after May 1, 2025, Vermilion may redeem some or all of the senior unsecured notes at the redemption prices set forth below, together with accrued and unpaid interest. Prior to May 1, 2025, Vermilion may redeem up to 35% of the original principal amount of the notes with an amount of cash not greater than the net cash proceeds of certain equity offerings at a redemption price of 106.875% of the principal amount of the notes, together with accrued and unpaid interest. Prior to May 1, 2025, Vermilion may also redeem some or all of the notes at a price equal to 100% of the principal amount of the notes, plus a “make-whole premium,” together with applicable premium, accrued and unpaid interest. Year 2025 2026 2027 2028 and thereafter Redemption price 103.438 % 102.292 % 101.146 % 100.000 % 13. Shareholders' capital The following table reconciles the change in Vermilion’s shareholders’ capital: Shareholders' capital Balance at January 1 Vesting of equity based awards Shares issued for equity based compensation Share-settled dividends on vested equity based awards Repurchase of shares Balance at December 31 2023 2022 Shares ('000s) Amount ($M) Shares ('000s) 163,227 3,657 655 64 (5,332) 162,271 4,243,794 23,575 11,242 1,179 (137,224) 4,142,566 162,261 2,578 549 178 (2,339) 163,227 Amount ($M) 4,241,773 44,811 13,699 4,377 (60,866) 4,243,794 Vermilion is authorized to issue an unlimited number of common shares with no par value. Dividends declared to shareholders for the year ended December 31, 2023 were $65.2 million or $0.40 per common share (2022 - $45.8 million or $0.28 per share). On July 10, 2023, the Toronto Stock Exchange approved our notice of intention to commence a normal course issuer bid ("the NCIB"). The NCIB allows Vermilion to purchase up to 16,308,587 common shares representing approximately 10% of its public float as at July 12, 2023 beginning July 12, 2023 and ending July 11, 2024. Common shares purchased under the NCIB will be cancelled. Vermilion Energy Inc. ■ Page 94 ■ 2023 Annual Report In 2023, Vermilion purchased and cancelled 5.33 million common shares under the NCIB for total consideration of $94.8 million (2022 - 2.34 million common shares for total consideration of $71.7 million). The surplus between the total consideration and the carrying value of the shares repurchased was recorded as an increase to deficit. Subsequent to December 31, 2023 Vermilion purchased and cancelled 1.44 million common shares under the NCIB for total consideration of $21.4 million. Vermilion Energy Inc. ■ Page 95 ■ 2023 Annual Report 14. Capital disclosures Vermilion defines capital as net debt (long-term debt (excluding unrealized foreign exchange on swapped USD borrowings) plus adjusted working capital (defined as current assets less current liabilities, excluding current derivatives and current lease liabilities)) and shareholders’ capital. In managing capital, Vermilion reviews whether fund flows from operations is sufficient to fund capital expenditures, dividends, and asset retirement obligations. Vermilion monitors the ratio of net debt to fund flows from operations. As at December 31, 2023, our ratio of net debt to trailing fund flows from operations is 0.9 (2022 - 0.8). Vermilion manages the ratio of net debt to fund flows from operations (refer to Note 3 - Segmented information) by monitoring capital expenditures, dividends, and asset retirement obligations with expected fund flows from operations. Vermilion intends for the ratio of net debt to fund flows from operations to trend towards 1.0 over time. The following table calculates Vermilion’s ratio of net debt to fund flows from operations: Year Ended Dec 31, 2023 914,015 164,552 — 1,078,567 Dec 31, 2022 1,081,351 265,111 (1,876) 1,344,586 0.9 0.8 Long-term debt Adjusted working capital (1) Unrealized FX on swapped USD borrowings Net debt Ratio of net debt to four quarter trailing fund flows from operations (1) Adjusted working capital is defined as current assets (excluding current derivatives), less current liabilities (excluding current derivatives and current lease liabilities). 15. Equity based compensation The following table summarizes the number of awards outstanding under the LTIP: Number of LTIP Awards ('000s) Opening balance Granted Vested Forfeited Closing balance 2023 5,503 1,694 (2,476) (243) 4,478 2022 6,405 1,108 (1,733) (277) 5,503 For the year ended December 31, 2023, the awards had a weighted average grant date fair value of $18.19 (2022 - $25.60). Equity based compensation expense for the awards is calculated based on the number of awards outstanding multiplied by the estimated performance factor that will be realized upon vesting (2023 - 1.0; 2022 - 1.0) adjusted by an estimated annual forfeiture rate (2023 - 5.3%; 2022 - 3.8%). Equity based compensation expense of $29.2 million was recorded during the year ended December 31, 2023 (2022 - $29.2 million) relating to the awards. As at December 31, 2023, there were 470,952 DSUs outstanding with a weighted average grant date fair value of $14.26. In 2023, there were 106,644 DSUs granted with a weighted average grant date fair value of $21.85. Equity based compensation expense of $2.3 million was recorded during the year ended December 31, 2023 (2022 - $1.5 million) relating to the DSUs. Vermilion Energy Inc. ■ Page 96 ■ 2023 Annual Report 16. Per share amounts Basic and diluted net (loss) earnings per share have been determined based on the following: Net (loss) earnings Basic weighted average shares outstanding ('000s) Dilutive impact of equity based compensation ('000s) Diluted weighted average shares outstanding ('000s) Basic (loss) earnings per share Diluted (loss) earnings per share 17. Financial instruments Classification of financial instruments Year Ended Dec 31, 2023 (237,587) Dec 31, 2022 1,313,062 163,719 — 163,719 (1.45) (1.45) 163,489 4,937 168,426 8.03 7.80 The following table summarizes the carrying value relating to Vermilion’s financial instruments: ($M) As at Dec 31, 2023 FVTPL FVTOCI Amortized Cost As at Dec 31, 2022 Total FVTPL FVTOCI Amortized Cost Total Cash and cash equivalents Derivative assets Investment in securities Derivative liabilities Accounts receivable Accounts payable and accrued liabilities Dividends payable Lease obligations Long-term debt (1) 141,456 389,899 — (21,782) — — — — — — — 73,261 — — — — — — — — — — 242,926 (380,370) (16,227) (33,001) (914,015) 141,456 389,899 73,261 (21,782) 242,926 (380,370) (16,227) (33,001) (914,015) 13,836 295,441 — (55,845) — — — — — 13,836 — 295,441 — 56,366 56,366 (55,845) — 373,651 — (481,444) — (13,058) — — (51,507) — (1,081,351) (1,081,351) — — — — 373,651 (481,444) (13,058) (51,507) (1) The carrying value of the above equals fair value except for long-term debt. The fair value of long-term debt was $904,418 (2022 - $1,035,671). The carrying value of accounts receivable, accounts payable and accrued liabilities, dividends payable and lease obligations are a reasonable approximation of their fair value due to the short maturity of these financial instruments. The carrying value of long-term debt outstanding on the revolving credit facility approximates its fair value due to the use of short-term borrowing instruments at market rates of interest. Fair value measurements are categorized into a fair value hierarchy based on the lowest level input that is significant to the fair value measurement: • • • Level 1 inputs are determined by reference to unadjusted quoted prices in active markets for identical assets or liabilities. Inputs used in fair value measurement of cash and cash equivalents, investment in securities, the revolving credit facility, and the senior unsecured notes are categorized as Level 1. Level 2 inputs are determined based on inputs other than unadjusted quoted prices that are observable, either directly or indirectly. The fair value of Vermilion’s derivative assets and liabilities are determined using pricing models that incorporate future price forecasts (supported by prices from observable market transactions) and credit risk adjustments. Level 3 inputs are not based on observable market data. Vermilion does not have any financial instruments classified as Level 3. There were no transfers between levels in the hierarchy in the years ended December 31, 2023 and 2022. Nature and extent of risks associated with financial instruments Vermilion is exposed to financial risks from its financial instruments. These financial risks include: market risk (includes commodity price risk, interest rate risk, and currency risk), credit risk, and liquidity risk. Vermilion Energy Inc. ■ Page 97 ■ 2023 Annual Report Commodity price risk Vermilion is exposed to commodity price risk on its derivative assets and liabilities which are used as part of the Company’s risk management program to mitigate the effects of changes in commodity prices on future cash flows. While transactions of this nature relate to future petroleum and natural gas production, Vermilion does not designate these derivative assets and liabilities as accounting hedges. As such, changes in commodity prices impact the fair value of derivative instruments and the corresponding gains or losses recognized on derivative instruments. Currency risk Vermilion is exposed to currency risk on its financial instruments denominated in foreign currencies. These financial instruments include cash and cash equivalents, accounts receivables, accounts payables, lease obligations, long-term debt, derivative assets and derivative liabilities. These financial instruments are primarily denominated in the US dollar and the Euro. Vermilion monitors its exposure to currency risk and reviews whether the use of derivative financial instruments is appropriate to manage potential fluctuations in foreign exchange rates. Interest rate risk Vermilion is exposed to interest rate risk on its revolving credit facility, which consists of short-term borrowing instruments that bear interest at market rates. Thus, changes in interest rates could result in an increase or decrease in the amount paid by Vermilion to service this debt. The following table summarizes the increase (positive values) or decrease (negative values) to net (loss) earnings before tax due to a change in the value of Vermilion’s financial instruments as a result of a change in the relevant market risk variable. This analysis does not attempt to reflect any interdependencies between the relevant risk variables. ($M) Currency risk - Euro to Canadian dollar $0.01 increase in strength of the Canadian dollar against the Euro $0.01 decrease in strength of the Canadian dollar against the Euro Currency risk - US dollar to Canadian dollar $0.01 increase in strength of the Canadian dollar against the US $ $0.01 decrease in strength of the Canadian dollar against the US $ Commodity price risk - Crude oil US $5.00/bbl increase in crude oil price used to determine the fair value of derivatives US $5.00/bbl decrease in crude oil price used to determine the fair value of derivatives Commodity price risk - European natural gas € 5.0/GJ increase in European natural gas price used to determine the fair value of derivatives € 5.0/GJ decrease in European natural gas price used to determine the fair value of derivatives Share price risk - Equity swaps $1.00 increase from initial share price of the equity swap $1.00 decrease from initial share price of the equity swap Dec 31, 2023 Dec 31, 2022 5,855 (5,855) 6,816 (6,816) (27,573) 27,573 (256,731) 262,862 3,750 (3,750) 5,640 (5,640) 5,441 (5,441) — — (88,524) 91,828 3,750 (3,750) Credit risk Vermilion is exposed to credit risk on accounts receivable and derivative assets in the event that customers, joint operation partners, or counterparties fail to discharge their contractual obligations. As at December 31, 2023, Vermilion’s maximum exposure to receivable credit risk was $632.8 million (December 31, 2022 - $669.1 million) which is the value of accounts receivable and derivative assets on the balance sheet. Vermilion’s accounts receivable primarily relates to customers and joint operations partners in the petroleum and natural gas industry. These amounts are subject to normal industry payment terms and credit risks. Vermilion manages these risks by monitoring the creditworthiness of customers and joint operations partners and, where appropriate, obtaining assurances such as parental guarantees and letters of credit. Vermilion determines the lifetime expected credit losses recognized on accounts receivable using a provision matrix. In preparing the provision matrix, the Company takes into account historical credit loss experience based on the aging of accounts receivable, adjusted as necessary for current and future petroleum and natural gas prices to the extent that changes in pricing may negatively impact the Company's customers and joint operations partners. The lifetime expected credit losses on accounts receivable as at December 31, 2023 and 2022 is not material. As at the balance sheet date, approximately 3.7% (2022 - 0.5%) of the accounts receivable balance was outstanding for more than 90 days. Vermilion considers the balance of accounts receivable to be collectible. Vermilion Energy Inc. ■ Page 98 ■ 2023 Annual Report Vermilion’s derivative assets primarily relates to the fair value of financial instruments used as part of the Company’s risk management program to mitigate the effects of changes in commodity prices on future cash flows. Vermilion manages this risk by monitoring the creditworthiness of counterparties, transacting primarily with counterparties that have investment grade third party credit ratings, and by limiting the concentration of financial exposure to individual counterparties. As a result, Vermilion has not obtained collateral or other security to support its financial derivatives. Vermilion’s cash deposited in financial institutions and guaranteed investment certificates are also subject to counterparty credit risk. Vermilion mitigates this risk by transacting with financial institutions with high third party credit ratings. Liquidity risk Liquidity risk is the risk that Vermilion will encounter difficulty in meeting obligations associated with its financial liabilities. Vermilion does not consider this to be a significant risk as its financial position and available committed borrowing facility provide significant financial flexibility and allow Vermilion to meet its obligations as they come due. The following table summarizes Vermilion’s undiscounted non-derivative financial liabilities and their contractual maturities: 3 months to 1 year 26,820 23,412 ($M) December 31, 2023 December 31, 2022 1 month 134,381 192,572 1 month to 3 months 235,396 278,520 1 year to 5 years 430,993 607,796 18. Related party disclosures The compensation of directors and management is reviewed annually by the independent Governance and Human Resources Committee against industry practices for oil and gas companies of similar size and scope. The following table summarizes the compensation of directors and other members of key management personnel during the years ended December 31, 2023 and 2022: Short-term benefits Equity based compensation Number of individuals included in the above amounts Year Ended Dec 31, 2023 5,451 8,015 13,466 15 Dec 31, 2022 5,124 8,951 14,075 16 Vermilion Energy Inc. ■ Page 99 ■ 2023 Annual Report 19. Supplemental information Changes in non-cash working capital was comprised of the following: Changes in: Accounts receivable Crude oil inventory Prepaid expenses Accounts payable and accrued liabilities Income taxes payable Dividends payable Working capital assumed in acquisitions Foreign exchange Changes in non-cash working capital Changes in non-cash operating working capital Changes in non-cash investing working capital Changes in non-cash working capital Cash and cash equivalents was comprised of the following: Cash on deposit with financial institutions Guaranteed investment certificates Cash and cash equivalents Wages and benefits included in operating expenses and general and administration expenses were: Operating expense General and administration expense Wages and benefits As at December 31, 2023, we had the following contractual obligations and commitments: Year Ended Dec 31, 2023 Dec 31, 2022 130,725 (37,676) 76,452 (101,074) (42,953) 3,169 (109,134) 7 (80,484) (61,117) (19,367) (80,484) (45,067) 413 (45,617) 40,786 304,516 — — (12,046) 242,985 216,869 26,116 242,985 As at Dec 31, 2023 140,795 661 141,456 Dec 31, 2022 13,701 135 13,836 Year Ended Dec 31, 2023 87,418 61,550 148,968 Dec 31, 2022 75,165 45,525 120,690 ($M) Long-term debt (1) Lease obligations (2) Processing and transportation agreements Purchase obligations Drilling and service agreements Total contractual obligations and commitments (1) Less than 1 year 1 - 3 years 3 - 5 years After 5 years 58,690 58,034 42,127 32,087 18,572 209,510 480,682 80,281 54,205 13,519 49,784 678,471 72,743 53,839 27,493 2,374 — 156,449 583,597 43,907 151,777 105 — 779,386 Total 1,195,712 236,061 275,602 48,085 68,356 1,823,816 (2) (3) Includes interest on senior unsecured notes. Includes undiscounted IFRS 16 - Leases obligations of $59.7 million recognized in the financial statements as at December 31, 2023, future undiscounted IFRS 16 - leases due to commence in 2024 of $117.5 million, and surface lease rental commitments of $56.5 million and other of $2.4 million that are not considered leases under IFRS 16 and are not represented on the balance sheet. Commitments denominated in foreign currencies have been translated using the related spot rates on December 31, 2023. Vermilion Energy Inc. ■ Page 100 ■ 2023 Annual Report The following tables summarize Vermilion's outstanding risk management positions as at December 31, 2023: Daily Bought Put Volume Weighted Average Bought Put Price Daily Sold Call Volume Weighted Average Sold Call Price Daily Sold Put Volume Weighted Average Sold Put Price Daily Sold Swap Volume Weighted Average Sold Swap Price Daily Bought Swap Volume Weighted Average Bought Swap Price Unit Currency bbl bbl bbl mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf USD USD USD CAD CAD CAD CAD CAD CAD CAD CAD CAD CAD CAD CAD USD USD USD USD USD USD USD USD USD USD USD USD — — — 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 20,000 20,000 20,000 20,000 24,000 24,000 24,000 24,000 24,000 24,000 24,000 24,000 — — — 3.17 3.17 3.17 3.17 3.17 3.17 3.17 3.17 3.17 3.17 3.17 3.17 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 — — — 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 4,739 20,000 20,000 20,000 20,000 24,000 24,000 24,000 24,000 24,000 24,000 24,000 24,000 — — — 4.22 4.22 4.22 4.22 4.22 4.22 4.22 4.22 4.22 4.22 4.22 4.22 4.45 4.45 4.45 4.45 4.49 4.49 4.49 4.49 4.49 4.49 4.49 4.49 — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — 12,500 9,500 9,500 4,739 19,904 19,904 9,849 23,695 23,695 23,695 23,695 23,695 23,695 23,695 23,695 4,000 4,000 4,000 4,000 — — — — — — — — 79.00 80.11 80.11 3.69 3.14 3.14 3.31 3.89 3.89 3.89 3.89 3.89 3.89 3.89 3.89 3.51 3.51 3.51 3.51 — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — WTI Q1 2024 Q2 2024 Q3 2024 AECO Q1 2024 Q2 2024 Q3 2024 Q4 2024 Q1 2025 Q2 2025 Q3 2025 Q4 2025 Q1 2026 Q2 2026 Q3 2026 Q4 2026 NYMEX Henry Hub Q1 2024 Q2 2024 Q3 2024 Q4 2024 Q1 2025 Q2 2025 Q3 2025 Q4 2025 Q1 2026 Q2 2026 Q3 2026 Q4 2026 Vermilion Energy Inc. ■ Page 101 ■ 2023 Annual Report Daily Bought Put Volume Weighted Average Bought Put Price Daily Sold Call Volume Weighted Average Sold Call Price Daily Sold Put Volume Weighted Average Sold Put Price Daily Sold Swap Volume Weighted Average Sold Swap Price Daily Bought Swap Volume Weighted Average Bought Swap Price Unit Currency mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf mcf EUR EUR EUR EUR EUR EUR EUR EUR EUR EUR EUR EUR EUR EUR mcf EUR mcf mcf mcf mcf EUR EUR EUR EUR 4,913 41.03 4,913 84.26 — — 35,623 7,278 7,278 4,913 4,913 — — — — — — — — — — — — — 37.85 25.96 25.96 13.19 13.19 — — — — — — — — — — — — — 35,623 7,278 7,278 4,913 4,913 — — — — — — — — — — — — — 71.90 45.76 45.76 18.32 18.32 — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — 2,457 2,457 7,370 30,709 30,709 34,394 34,394 17,197 17,197 12,284 12,284 9,827 9,827 — 14.65 14.65 41.19 14.08 14.08 15.13 15.13 14.40 14.40 13.51 13.51 9.67 9.67 — 22,111 (0.26) — — — — 2,457 2,457 2,457 2,457 14.95 14.95 14.95 14.95 — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — — Jan 2020 - Apr 2025 Jan 2020 - Jul 2025 Initial Share Price Share Volume 20.9788 CAD 22.4587 CAD 2,250,000 1,500,000 NBP Q1 2024 Q2 2024 Q3 2024 TTF Q1 2024 Q2 2024 Q3 2024 Q4 2024 Q1 2025 Q2 2025 Q3 2025 Q4 2025 Q1 2026 Q2 2026 Q3 2026 Buy TTF, Sell NBP Basis Q1 2024 THE Q4 2024 Q1 2025 Q2 2025 Q3 2025 VET Equity Swaps Swap Swap Foreign Exchange Collar Forward Monthly Bought Put Amount Weighted Average Bought Put Price Monthly Sold Call Amount Weighted Average Sold Call Price Monthly Sold Swap Amount Weighted Average Sold Swap Price Jan 2024 - Dec 2024 4,000,000 USD 1.3600 4,000,000 USD 1.3963 — Jan 2024 - Dec 2024 — — — — 4,000,000 USD — 1.3531 The following sold option instruments allow the counterparties, at the specified date, to enter into a derivative instrument contract with Vermilion at the detailed terms: Period if Option Exercised Unit Currency WTI Option Expiration Date Daily Bought Put Volume Weighted Average Bought Put Price Daily Sold Call Volume Weighted Average Sold Call Price Daily Sold Put Volume Weighted Average Sold Put Price Daily Sold Swap Volume Weighted Average Sold Swap Price Oct 2024 - Sep 2025 bbl USD 29-Mar-2024 — — — — — — 1,000 80.00 Vermilion Energy Inc. ■ Page 102 ■ 2023 Annual Report DIRECTORS Robert Michaleski 1,3,5 Calgary, Alberta Dion Hatcher Calgary, Alberta James J. Kleckner Jr. 7,9 Edwards, Colorado Carin Knickel 4,7,11 Golden, Colorado Stephen P. Larke 3,5,10 Calgary, Alberta Timothy R. Marchant 6,9,11 Calgary, Alberta William Roby 7,8,11 Katy, Texas Manjit Sharma 2,5 Toronto, Ontario Myron Stadnyk 7,9 Calgary, Alberta Judy Steele 3,5,11 Halifax, Nova Scotia 1 Chairman (Independent) 2 Audit Committee Chair (Independent) 3 Audit Committee Member (Independent) 4 Governance and Human Resources Committee Chair __(Independent) 5 Governance and Human Resources Committee Member __(Independent) 6 Health, Safety and Environment Committee Chair __(Independent) 7 Health, Safety and Environment Committee Member __(Independent) 8 Technical Committee Chair (Independent) 9 Technical Committee Member __(Independent) 10 Sustainability Committee Chair (Independent) 11 Sustainability Committee Member (Independent) OFFICERS / CORPORATE SECRETARY Dion Hatcher * President & Chief Executive Officer Lars Glemser * Vice President & Chief Financial Officer AUDITORS Deloitte LLP Calgary, Alberta BANKERS Tamar Epstein General Counsel Terry Hergott Vice President Marketing Yvonne Jeffery Vice President Sustainability Darcy Kerwin * Vice President International & HSE Geoff MacDonald Vice President Geosciences Randy McQuaig * Vice President North America Kyle Preston Vice President Investor Relations Averyl Schraven Vice President People & Culture Gerard Schut Vice President European Operations Jenson Tan * Vice President Business Development Jamie Gagner Corporate Secretary * Principal Executive Committee Member The Toronto-Dominion Bank Alberta Treasury Branches Bank of America N.A., Canada Branch Canadian Imperial Bank of Commerce Export Development Canada National Bank of Canada Royal Bank of Canada The Bank of Nova Scotia Wells Fargo Bank N.A., Canadian Branch La Caisse Centrale Desjardins du Québec Citibank N.A., Canadian Branch - Citibank Canada Canadian Western Bank JPMorgan Chase Bank, N.A., Toronto Branch Goldman Sachs Lending Partners LLC EVALUATION ENGINEERS McDaniel & Associates Calgary, Alberta LEGAL COUNSEL Norton Rose Fulbright Canada LLP Calgary, Alberta TRANSFER AGENT Odyssey Trust Company STOCK EXCHANGE LISTINGS The Toronto Stock Exchange (“VET”) The New York Stock Exchange (“VET”) INVESTOR RELATIONS Kyle Preston Vice President Investor Relations 403-476-8431 TEL 403-476-8100 FAX 1-866-895-8101 IR TOLL FREE investor_relations@vermilionenergy.com Vermilion Energy Inc. ■ Page 103 ■ 2023 Annual Report

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