Exhibit 99.1

CONDENSED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (UNAUDITED)

For the three and nine month periods ended September 30, 2024

Greenfire Resources Ltd. 

Condensed Interim Consolidated Balance Sheets

(Unaudited)

Related party transactions (note 11)

See accompanying notes to the unaudited condensed interim consolidated financial statements.

These Condensed Interim Consolidated Financial Statements were approved by the Board of Directors.

Condensed Interim Consolidated Statements of Comprehensive Income (Loss)

(Unaudited)

See accompanying notes to the unaudited condensed interim consolidated financial statements.

Condensed Interim Consolidated Statements of Changes in Shareholders’ Equity

(Unaudited)

See accompanying notes to the unaudited condensed interim consolidated financial statements.

Condensed Interim Consolidated Statements of Cash Flows

(Unaudited)

See accompanying notes to the unaudited condensed interim consolidated financial statements.

Notes to the Condensed Interim Consolidated Financial Statements

As at September 30, 2024 and for the three and nine months ended September 30, 2024 and 2023

(Unaudited)

Greenfire Resources Ltd. (the “Company” or “Greenfire”) was incorporated under the laws of Alberta on December 9, 2022. On September 20, 2023, the Company participated in a De-Spac transaction involving a number of entities, including Greenfire Resources Inc. (“GRI”) and M3-Brigade Acquisition III Corp (“MBSC”) (the “De-Spac Transaction”). Refer to Note 3 De-Spac Transaction for additional information. On January 1, 2024, GRI was amalgamated with Greenfire Resources Operation Corporation (“GROC”) and on April 4, 2024, MBSC was dissolved. These unaudited condensed interim consolidated financial statements are comprised of the accounts of Greenfire and its wholly owned direct subsidiaries.

The Company and its subsidiaries are engaged in the exploration, development and operation of oil and gas properties, focused primarily in the Athabasca oil sands region of Alberta. The Company’s corporate head office is located at 1900, 205 5th Avenue SW, Calgary, AB T2P 2V7.

These unaudited condensed interim consolidated financial statements (“interim consolidated financial statements”) have been prepared in accordance with International Financial Reporting Standards (“IFRS”) as issued by the International Accounting Standards Board (“IASB”) using International Accounting Standard IAS 34: “Interim Financial Reporting”. They are condensed as they do not include all of the information required for full annual consolidated financial statements, and they should be read in conjunction with the audited annual consolidated financial statements of the Company for the year ended December 31, 2023 (the “Annual Financial Statements”). The interim consolidated financial statements have been prepared on a basis consistent with the accounting, estimation and valuation policies described in the Annual Financial Statements, except as described below. The unaudited condensed interim financial statements reflect all normal and reoccurring adjustments that are, in the opinion of management, necessary for a fair presentation of the results for the interim periods presented.

In these interim consolidated financial statements, all amounts are expressed in Canadian dollars (“$CAD”), which is the Company’s functional currency, unless otherwise indicated. These interim consolidated financial statements have been prepared on a historical cost basis, except for certain financial instruments which are measured at their fair value.

The Company has one reportable operating segment which is made up of its oil sands operations based on geographic location (Athabasca oil sands region of Alberta, Canada), nature of the products sold and integration of facilities and operations. The chief operating decision maker is the President and CEO, who reviews operating results at this level to assess financial performance and make resource allocation decisions. The Company determines its operating segments based on the differences in the nature of operations, products sold, economic characteristics and regulatory environments and management. All of the Company’s non-current assets are located in Canada, and all of its revenue is earned there.

These interim consolidated financial statements were approved by Greenfire’s Board of Directors on November 14, 2024.

On September 20, 2023, Greenfire, GRI, MBSC, DE Greenfire Merger Sub Inc. (“DE Merger Sub”) and 2476276 Alberta ULC (“Canadian Merger Sub”), completed a De-Spac Transaction pursuant to a business combination agreement dated December 14, 2022, as amended (the “Business Combination Agreement”) with MBSC. DE Merger Sub and Canadian Merger Sub were incorporated in December 2022 for the purposes of completing the De-Spac Transaction.

Pursuant to the De-Spac Transaction, Canadian Merger Sub amalgamated with and into GRI, with GRI continuing as the surviving corporation and becoming a direct, wholly-owned subsidiary of Greenfire and DE Merger Sub merged with and into MBSC with MBSC continuing as the surviving corporation and becoming a direct, wholly-owned subsidiary of Greenfire.

Greenfire has been identified as the acquirer for accounting purposes. As MBSC does not meet the definition of a business under IFRS 3 Business Combinations, the transaction was accounted for pursuant to IFRS 2, Share Based Payment. On closing of the De-Spac Transaction, the Company accounted for the excess of the fair value of Greenfire common shares issued to MBSC shareholders as consideration, over the fair value of MBSC’s identifiable net assets at the date of closing, resulting in $106.5 million (US$79.4 million) being recognized for the year ended December 31, 2023 as a listing expense.

For the three and nine months ended September 30, 2024, the Company expensed $nil (2023 – $4.1 million) and $nil (2023 – $8.3 million) in transaction costs related to the De-Spac Transaction, respectively.

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). The Company utilizes market data or assumptions that market participants who are independent, knowledgeable and willing and able to transact would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. The Company is able to classify fair value balances based on the observability of these inputs. The authoritative guidance for fair value measurements establishes three levels of the fair value hierarchy, defined as follows:

The carrying values of cash and cash equivalents, accounts receivable and accounts payable and accrued liabilities included on the condensed interim consolidated balance sheets approximates the fair values of the respective assets and liabilities due to the short-term nature of those instruments.

Derivative financial instruments are used by the Company to manage risks related to commodity prices. All financial risk management contracts are classified at fair value through profit and loss (level 2). Financial risk management contracts are included on the condensed interim consolidated balance sheet and are classified as current or non-current based on the contractual terms specific to the instrument. Gains and losses on re-measurement of derivatives are shown separately on the condensed interim consolidated statement of comprehensive income (loss) in the period in which they arise.

The warrants issued were classified as financial liabilities due to a cashless exercise feature and are measured at fair value upon issuance and at each subsequent reporting period, with the changes in fair value and recorded in the condensed interim consolidated statement of comprehensive income (loss). The fair value of these warrants is determined using the Black-Scholes option valuation model (level 2).

The estimated fair value of long-term debt has been determined based on period-end trading prices of long-term debt on the secondary market (level 2).

The Company is exposed to a number of different financial risks arising from normal course business exposures, as well as the Company’s use of financial instruments. There have been no changes in the Company’s objectives, policies or risks surrounding financial instruments.

Commodity price risk

The Company is exposed to commodity price risk on its oil sales, diluent expense and certain operating expenses due to fluctuations in market prices. The Company continues to execute a consistent risk management program that is primarily designed to reduce the volatility of revenue and cash flow, generate sufficient cash flows to service debt obligations, and fund the Company’s operations. The Company’s risk management liabilities may consist of hedging instruments such as fixed price swaps and option structures, including costless collars on WTI, WCS differentials, condensate differential, natural gas and electricity swaps. The Company does not use financial derivatives for speculative purposes.

Liquidity risk

Liquidity risk is the risk that the Company will not be able to meet its financial obligations as they become due. The Company’s objective in managing liquidity risk is to maintain sufficient available reserves to meet its financial obligations at any point in time. The Company expects to achieve this objective through prudent capital spending, an active commodity risk management program and through strategies such as continuously monitoring forecast and actual cash flows from operating, financing and investing activities, and available credit facilities. Management believes that future cash flows generated from these sources will be adequate to settle Greenfire’s financial liabilities.

The following table details the financial liabilities as at September 30, 2024:

Foreign exchange risk

The Company is exposed to foreign currency risk on the principal and interest components of its US dollar denominated 2028 Notes (note 9) and US Dollar denominated cash, cash equivalents, accounts receivables and accounts payables, and accrued liabilities. As at September 30, 2024, Greenfire’s net foreign exchange risk exposure was a US$237.6 million liability (December 31, 2023 – US$257.4 million liability), and a 10% change in the foreign exchange rate would result in a $32.1 million change in the foreign exchange gain or loss.

Credit risk

Credit risk is the risk of financial loss to the Company if a customer or counterparty to a financial instrument fails to meet its contractual obligations and arises principally from the Company’s accounts receivable. The Company is primarily exposed to credit risk from receivables associated with its oil sales. The Company manages its credit risk exposure by transacting with high-quality credit worthy counterparties and monitoring credit worthiness and/or credit ratings on an ongoing basis. Trade receivables from oil sales are generally collected on the 25th day of the month following production. Joint interest receivables are typically collected within one to three months of the invoice being issued. The Company has not previously experienced any material credit losses on the collection of accounts receivable.

At September 30, 2024, the Company was exposed to concentration risk associated with its outstanding trade receivables and joint interest receivables balances. Trade receivables consisted of balances receivable from two counterparties, representing 84% and 16% of the amounts outstanding, respectively (December 31, 2023- 100% receivable from a single company). At September 30, 2024, 100% of the Company’s joint interest receivables were held by a single company (December 31, 2023- 100% by a single company). Maximum exposure to credit risk is represented by the carrying amount of accounts receivable on the balance sheet. There are no material financial assets that the Company considers past due and no accounts have been written off.

The Company has long-term marketing agreements with a single counterparty (“Petroleum Marketer”), which has exclusive marketing rights over the Company’s production and diluent purchases at Hangingstone Expansion (“Expansion”) until October 2028 and at Hangingstone Demo (“Demo”), until April 2026. Fees paid to the Petroleum Marketer as part of these agreements include marketing, incentive and royalty fees. These fees are expensed as incurred as transportation and marketing expenses.

On February 22, 2024, Greenfire acquired natural gas assets in the Hangingstone area for consideration of $2.5 million. This acquisition resulted in an increase in PP&E of $12.7 million, including $10.2 million of future decommissioning obligations. On April 19, 2024, Greenfire acquired heavy oil assets in the Athabasca region of Northern Alberta for consideration of $1.2 million. This acquisition resulted in an increase in PP&E of $3.5 million, including $2.3 million of future decommissioning obligations. The Company applied the optional IFRS 3 concentration test to these acquisitions which resulted in the acquired assets being accounted for as asset acquisitions.

No indicators of impairment were identified at September 30, 2024, and as such no impairment test was performed.

The Company’s decommissioning liabilities result from net ownership interests in petroleum assets including well sites, gathering systems and processing facilities. In 2024, the Company acquired certain natural gas and heavy oil assets in the Athabasca region of Northern Alberta and recognized $12.5 million of future decommissioning obligations. The Company estimates the total undiscounted escalated amount of cash flows required to settle its decommissioning liabilities to be approximately $288.4 million (December 31, 2023 - $206.5 million). For the three and nine months ended September 30, 2024, a credit-adjusted discount rate of 12% (December 31, 2023 -12%) and an inflation rate of 2.0% (December 31, 2023 - 2.0%) were used to calculate the decommissioning liabilities. A 1.0% change in the credit-adjusted discount rate would impact the discounted value of the decommissioning liabilities by approximately $2.3 million with a corresponding adjustment to PP&E. The decommissioning liabilities are estimated to be settled in periods up to year 2071.

A reconciliation of the decommissioning liabilities is provided below:

The Company’s risk management liabilities may consist of hedging instruments such as fixed price swaps and option structures, including costless collars on WTI, WCS differentials, condensate differential, natural gas and electricity swaps. The Company does not use financial derivatives for speculative purposes.

The Company’s obligations under its 2028 Notes (see note 9) includes a requirement to implement a 12-month forward commodity price risk management program encompassing not less than 50% of the hydrocarbon output under the proved developed producing reserves (“PDP”) forecast in the Company’s most recent reserves report, as determined by a qualified and independent reserves evaluator. This requirement is assessed monthly for the duration of time that at least US$100 million of the 2028 Notes remain outstanding.

The Company’s commodity price risk management program does not involve margin accounts that require posting of margin with increased volatility in underlying commodity prices. Financial risk management contracts are measured at fair value, with gains and losses on re-measurement included in the consolidated statements of comprehensive income (loss) in the period in which they arise.

The Company’s financial risk management contracts are subject to master netting agreements that create the legal right to settle the instruments on a net basis, with each counterparty. The following table summarizes the gross asset and liability positions of the Company’s individual risk management contracts that are offset in the consolidated balance sheets:

As at September 30, 2024, the following financial commodity risk management contracts were in place:

Subsequent to September 30, 2024, Greenfire entered into the following financial commodity risk management contracts:

At September 30, 2024, a US$5 increase or decrease in the price of WTI has a $nil impact on the WTI Costless Collar contracts. The following table summarizes the sensitivity to price changes for Greenfire’s WTI Fixed Price Swaps:

The Company’s commodity risk management contracts are held with two large reputable financial institutions. As a result, the Company concluded that credit risk associated with its commodity risk management contracts is low.

Senior Secured Notes

On September 20, 2023, Greenfire issued US$300 million of senior secured notes (the “2028 Notes”). The 2028 Notes bear interest at the fixed rate of 12.00% per annum payable semi-annually, have a term of five years maturing on October 1, 2028, and is secured by a second priority lien on the Company’s assets, junior to the Senior Credit Facility and financial risk management contracts with the Senior Credit Facility lenders.

The 2028 Notes are not subject to any financial covenants but subject to certain exceptions and qualifications. The indenture governing the 2028 Notes (the “2028 Indenture”) contains certain non-financial covenants that limit the Company’s ability to, among other things, incur additional indebtedness, create or permit liens to exist, pay dividends, redeem stock, make certain restricted payments, and sell assets. In addition, the Company is required to maintain financial hedges for a minimum of 50% of the forward twelve calendar month forecasted production(1), and to limit capital expenditures to CAD$100 million annually until the outstanding principal amount of the 2028 Notes is less than US$100 million and US$150 million, respectively. As at September 30, 2024 the Company was compliant with all covenants.

The 2028 Indenture requires the Company to redeem the 2028 Notes at 105% of the principal amount plus accrued and unpaid interest with 75% of its Excess Cash Flow (as defined in the 2028 Indenture) every six-months (the “ECF Sweep”). When consolidated indebtedness(2) is less than US$150 million, the ECF Sweep is reduced to 25% of Excess Cash Flow until the principal outstanding on the 2028 Notes is US$100 million. On July 12, 2024, the Company redeemed $84.3 million (US$61.0 million) of the 2028 Notes under the ECF Sweep. The next redemption is due by March 6, 2025.

The Company may make additional redemptions of some or all of the 2028 Notes on or after October 1, 2025, inclusive of a “make whole” premium, as set out in the table below. At any time before October 1, 2025, the Company may redeem up to 40% of the aggregate principal amount of the notes using the net proceeds from certain equity issuances as a redemption price equal to 112% of the principal amount plus accrued and unpaid interest. The following table discloses the redemption amount including the “make whole” premium on redemption of the 2028 Notes:

As at September 30, 2024, the carrying value of the Company’s long-term debt was $308.6 million and the fair value was $349.4 million (December 31, 2023 carrying value – $376.4 million, fair value - $394.1 million). The 2028 Notes are subject to fixed interest rates and are not exposed to changes in interest rates.

Senior Credit Facility

Greenfire has a reserve-based credit facility (the “Senior Credit Facility”) comprised of an operating facility and a syndicated facility. Total credit available under the Senior Credit Facility is $50 million comprised of a $20 million operating facility and a $30 million syndicated facility.

The Senior Credit Facility is a committed facility available on a revolving basis. On May 24, 2024, the Senior Credit Facility was extended until May 31, 2025, and may, subject to the lenders’ approval, be extended for a further 364-day period. If the revolving period is not extended, the undrawn portion of the facility will be cancelled and any amounts outstanding would be repayable on May 31, 2026. The Senior Credit Facility is subject to a semi-annual borrowing base review, occurring in May and November of each year. The borrowing base is determined based on the lenders’ evaluation of the Company’s petroleum and natural gas reserves and their commodity price outlook at the time of each borrowing base review.

The Senior Credit Facility is secured by a first priority security interest on substantially all of the assets of the Company and is senior in priority to the 2028 Notes. The Senior Credit Facility contains certain covenants that limit the Company’s ability to, among other things, incur additional indebtedness, create or permit liens to exist, pay dividends, redeem stock, and sell assets. The Senior Credit Facility is not subject to any financial covenants.

Amounts borrowed under the Senior Credit Facility bear interest at a floating rate based on the applicable Canadian prime rate, US base rate, adjusted secured overnight financing rate or adjusted Canadian overnight repo rate average, plus a margin of 1.75% to 6.25% based on Debt to EBITDA ratio. A standby fee on the undrawn portion of the Senior Credit Facility ranges from 0.6875% to 1.5625% based on Debt to EBITDA ratio. As at September 30, 2024 and December 31, 2023, the Company had no amounts drawn under the Senior Credit Facility.

Letter of Credit Facility

Greenfire maintains a separate $55 million letter of credit facility (the “EDC Facility”) with a Canadian bank that is supported by a performance security guarantee from Export Development Canada (“EDC”). The EDC Facility is available on a demand basis. As at September 30, 2024, the Company had $54.0 million (December 31, 2023 - $54.3 million) in letters of credit outstanding under the EDC Facility.

Share capital

As at September 30, 2024 the Company’s authorized share capital consists of an unlimited number of common shares without a nominal or par value. The following table summarizes the changes to the Company’s common share capital:

Per share amounts

Net income (loss) per share was calculated using the historical weighted average shares outstanding, scaled by the applicable exchange ratio following the completion of the De-Spac Transaction. The following table summarizes the Company’s basic and diluted net income (loss) per share:

For the three and nine months ended September 30, 2023, 3.3 million performance warrants were anti-dilutive.

Issued and Outstanding Share Units

A summary of the performance warrants (“PWs”), restricted share units (“RSUs”), performance share units (“PSUs”), and deferred share units (“DSUs”), collectively the share units, issued and outstanding is as follows:

Stock-based compensation

Performance warrants

The PWs expire 10 years after the issuance date and became fully vested with the closing of the De-Spac Transaction on September 20, 2023. The PW plan was replaced by the omnibus share incentive plan (the “Incentive Plan”).

Incentive plan

The Company’s incentive plan provides for the granting of DSUs, PSUs, RSUs and options. The aggregate maximum number of Common Shares reserved for issuance thereunder is limited to 10% of the Company’s issued and outstanding Common Shares, less any Common Shares underlying securities granted under any of the Company’s other share compensation arrangements, including Common Shares issuable on exercise of PWs. RSUs, PSUs and DSUs can be settled in either cash or shares issued from treasury and is at the sole discretion of the Board of Directors. It is the Board of Director’s intention to settle all incentive units with shares issued from treasury, therefore the incentive units have been accounted for as equity-settled compensation.

DSUs are issued to independent members of the Board of Directors and vest immediately upon grant, however the units cannot be settled until the director ceases to be a director. DSUs are valued based on the grant date share price.

RSUs granted under the Incentive Plan typically vest annually in thirds over a three-year period, have no exercise price and automatically settle at each vesting date. RSUs are valued based on their grant date share price.

PSUs granted under the Incentive Plan vest on the third anniversary of the grant date, provided that the Company satisfies certain performance criteria identified by the Board of Directors, which are set and measured to establish a performance multiplier from zero to two. PSUs have been granted with either market-based (“Market PSUs”) or non-market operations-based (“Operations PSUs”) performance criteria. Market PSUs are valued using a Monte Carlo simulation incorporating a three-year life and a volatility of 57%. Operations PSUs are valued based on the share price at the time of grant multiplied by the expected number of shares to be issued. The award value of the Operations PSUs is adjusted at each reporting date for the expected number of shares to be issued, with the cumulative change recognized in net income (loss).

Related party transaction

On April 19, 2024, the Company entered into a consulting agreement with M3-Brigage Sponsor III, LP (the “MBSC Sponsor”) for the provision of consulting services to the Company relating to, among other things, the Company’s transition to being a public company, maximizing the value of the Company, and educating the market about the Company and its value. Matthew Perkal, a member of the Company’s Board of Directors, who was nominated to the Company’s Board of Directors by MBSC Sponsor pursuant to its rights under the Investor Rights Agreement, is Head of SPACs and Special Situations at Brigade Capital Management, LP, an affiliate of MBSC Sponsor and, prior to the Business Combination, served as the Chief Executive Officer of M3-Brigade Acquisition III Corp. The term of the consulting agreement continues until the earlier of April 18, 2029, and the date MBSC Sponsor no longer holds any “Registrable Securities” in the Company (as defined in the Investor Rights Agreement). As compensation for the consulting services, the Company issued MBSC Sponsor 500,000 RSUs under the Company’s Incentive Plan, which vest in four quarterly instalments starting in the second quarter of 2024. The terms of the MBSC Sponsor Consulting agreement were reviewed and approved by the disinterested directors of the Company Board. The fair market value of the RSUs issued to MBSC Sponsor was $4.3 million. During the three and nine months ended September 30, 2024, the Company recognized an expense of $1.3 million and $3.2 million, respectively, and issued 125,000 and 250,000 common shares upon vesting of the RSUs.

In conjunction with the De-Spac transaction (note 3), the Company issued approximately 7.5 million warrants, entitling each warrant holder to purchase one common share of Greenfire. The outstanding warrants expire on October 19, 2028, and contain a cashless exercise feature, permitting an exercise without the payment of the exercise price by the issuance of a net, lower number of common shares. The warrants are remeasured to their fair value at each reporting period with the change recognized through the statement of comprehensive income (loss). The following table reconciles the warrant liability.

The fair value of each warrant was estimated using the Black Scholes Merton model with the following assumptions:

The following table reconciles the net changes in non-cash working capital and other liabilities from the consolidated balance sheet to the consolidated statement of cash flows:

Corporate Information

Exhibit 99.2

MANAGEMENT’S DISCUSSION & ANALYSIS

For the three and nine month periods ended September 30, 2024

Greenfire Resources Ltd.

MANAGEMENT’S DISCUSSION AND ANALYSIS

This Management’s Discussion and Analysis of the financial condition and results of operations of Greenfire Resources Ltd. (“Greenfire” or the “Company”) is dated November 14, 2024, which is the date this MD&A was approved by the Board of Directors of the Company, and should be read in conjunction with the Company’s unaudited condensed interim consolidated financial statements (“financial statements”) and notes thereto for the three and nine months ended September 30, 2024 and 2023 and the audited consolidated financial statements for the years ended December 31, 2023 and 2022 and the related MD&A. The financial statements, including the comparative figures, were prepared in accordance with International Accounting Standard 34 “Interim Financial Reporting” as issued by the International Accounting Standards Board.

This MD&A contains forward-looking information based on the Company’s current expectations and projections. For information on the material factors and assumptions underlying such forward-looking information, refer to the “Forward Looking Statements” section of this MD&A. Also see Abbreviations section within this MD&A for information regarding abbreviations used in this MD&A.

This MD&A contains non-GAAP financial measures, non-GAAP financial ratios, and capital management measures, collectively the “Non-GAAP Measures”. They include adjusted EBITDA, adjusted EBITDA per barrel ($/bbl), operating netback, operating netback per barrel ($/bbl), operating netback excluding realized gain (loss) risk management contracts, operating netback excluding realized gain (loss) risk management contracts per barrel ($/bbl), effective royalty rate, adjusted funds flow, adjusted free cash flow, adjusted working capital surplus (deficit) and net debt.

All financial information included in this MD&A is presented in Canadian dollars (“CAD”), unless otherwise noted. Certain dollar amounts have been rounded to the nearest million dollars or thousand dollars, as noted, and tables may not add due to rounding.

Corporate Information

Greenfire is based in Canada with the Company’s registered office located in Calgary, Alberta. The Company’s principal business is the production and development of upstream energy resources from the oil sands in Canada, using in situ thermal oil production extraction techniques such as SAGD.

On December 14, 2022, Greenfire Resources Inc. (“GRI”), M3-Brigade Acquisition III Corp. (“MBSC”), a New York Stock Exchange (“NYSE”) listed special purpose acquisition company, and certain other parties entered into a definitive agreement for a business combination (the “De-Spac Transaction”), which valued Greenfire at an enterprise value of US$950.0 million. The De-Spac Transaction was consummated on September 20, 2023 and Greenfire’s common shares (“Common Shares”) commenced trading on the NYSE. On February 2, 2024, Greenfire filed a final non-offering prospectus with the Alberta Securities Commission resulting in the Company becoming a reporting issuer in the Province of Alberta. On February 8, 2024, the Common Shares commenced trading on the Toronto Stock Exchange (“TSX”) under the symbol “GFR” and Greenfire became a reporting issuer in the Province of Ontario.

Unless indicated otherwise, production volumes and per unit statistics are presented throughout this MD&A on a “gross” basis as determined in accordance with National Instrument 51-101 – Standards for Disclosure for Oil and Gas Activities, which is the Company’s gross working interest basis before deduction of royalties. Dollar per barrel ($/bbl) figures presented throughout this MD&A are based upon sold bitumen barrels unless otherwise noted. The Company monitors and reviews financial information on a per barrel basis for comparability to prior period results and to analyze the Company’s competitiveness relative to its peer group.

GREENFIRE’S ASSETS, POSITIONING & STRATEGY

Greenfire is an intermediate, lower-cost and growth-oriented oil sands producer focused on the development of its Tier-1 assets in Western Canada using SAGD. Greenfire is pursuing capital-efficient and lower-risk growth through the optimization of existing production, facilities and reserves to maximize free cash flow generation. The Company has a large, long-life and relatively low decline oil sands resource base, with two producing and adjacent SAGD assets at the Hangingstone Facilities (as defined below), with expandable pipeline infrastructure in place for diluted bitumen and diluent at the Expansion Asset. These two assets are:

The Company believes that the Expansion Asset and Demo Asset (together, the “Hangingstone Facilities”) have a Tier-1 SAGD reservoir, meaning there is no top gas, bottom water, or lean zones (“thief zones”). Other SAGD reservoirs may have thief zones, which limit reservoir pressure and require the constant use and routine replacement of downhole pumps for production. Tier-1 SAGD reservoirs allow production to flow to the surface with natural lift, which reduces the Company’s capital and operating expenditure requirements compared to other SAGD producers, which the Company believes represents a structural cost advantage for Greenfire.

Greenfire’s strategy is to implement industry proven SAGD optimization techniques, concentrating on maximizing utilization of plant capacity, and controlling operating cost structures, to maximize the value of its Tier-1 SAGD assets. The Company believes that the Hangingstone Facilities have significant opportunities for additional value generation, including a brownfield expansion of production capacity at the Expansion Asset, the relocation of a newly acquired SAGD facility to the Expansion asset, and the restart of an existing facility to increase production capacity at the Demo Asset. Greenfire also plans to evaluate and consider additional potential prospects for further production growth, including external acquisitions that compete with the expected returns from its existing Tier-1 SAGD assets, if the Company believes they are accretive to Greenfire’s shareholders.

THIRD QUARTER 2024 HIGHIGHTS:

Financial & Operational Highlights

Liquidity and Balance Sheet

OPERATIONAL UPDATE AND OUTLOOK

Operational Update:

Expansion Asset

Demo Asset

Corporate 2024 Outlook:

Greenfire expects that annual average production for 2024 will be approximately 19,500 bbls/d, slightly below the guidance range of 20,000 to 21,000 bbls/d as part of the Updated 2024 Outlook that was released in August 2024. Lower annual production for 2024 reflects additional deferred growth from three Refill wells at the Demo Asset, which are now operational, and an unplanned outage of a steam generator at the Expansion Asset.

The Company plans to accelerate the drilling of an additional Refill well at the Expansion Asset in December 2024, resulting in an increase to annual capital expenditure guidance to $90 - $100 million relative to the previous range of $80 - $90 million.

Greenfire remains committed to prioritizing debt repayment and intends to reduce debt in the near-term using 75% of excess cash flow(1) to semi-annually redeem a portion of the 2028 Notes until consolidated indebtedness(1) is less than US$150 million.

DE-SPAC TRANSACTION

On September 20, 2023, Greenfire, GRI, MBSC, DE Greenfire Merger Sub Inc. (“DE Merger Sub”) and 2476276 Alberta ULC (“Canadian Merger Sub”), completed the De-Spac Transaction pursuant to a business combination agreement dated December 14, 2022, as amended with MBSC. DE Merger Sub and Canadian Merger Sub were incorporated in December 2022 for the purposes of completing the De-Spac Transaction.

Pursuant to the De-Spac Transaction, Canadian Merger Sub amalgamated with and into GRI, with GRI continuing as the surviving corporation and becoming a direct, wholly-owned subsidiary of Greenfire and DE Merger Sub merged with and into MBSC with MBSC continuing as the surviving corporation and becoming a direct, wholly-owned subsidiary of Greenfire. As of January 1, 2024, GRI was amalgamated with Greenfire Resources Operating Corporation, a wholly owned direct subsidiary of Greenfire. As of April 4, 2024, MBSC was legally dissolved into Greenfire.

Greenfire was identified as the acquirer for accounting purposes. As MBSC did not meet the definition of a business under IFRS 3 Business Combinations, the transaction was accounted for pursuant to IFRS 2, Share Based Payment. On closing of the De-Spac Transaction, the Company accounted for the excess of the fair value of the Common Shares issued to MBSC shareholders as consideration, over the fair value of MBSC’s identifiable net assets at the date of closing, resulting in $106.5 million (US$79.4 million) being recognized for the year ended December 31, 2023 as a listing expense. For the three and nine months ended September 30, 2024, the Company expensed $nil in transaction costs during both respective periods, compared to $4.1 million and $8.3 million during the same respective periods in 2023, related to the De-Spac Transaction.

RESULTS OF OPERATIONS

Bitumen Production and Sales

Production

The Company’s average bitumen production was 19,125 bbls/d and 19,262 bbls/d for the three and nine months ended September 30, 2024, respectively, both higher than 14,670 bbls/d and 17,742 bbls/d in the same respective periods in 2023. The increase in production is attributable to the Refill wells drilled in the second half of 2023 and throughout 2024. Year-to-date production growth has been impacted by downhole temperature sensor failures, delayed regulatory approvals for water disposal operations, wildfires in northern Alberta, and the planned maintenance turnaround of the Expansion Asset.

Commodity Prices

The prices received for Greenfire’s crude oil production directly impact earnings, cash flow and financial position.

WCS

Revenue from Greenfire’s bitumen production is closely linked to WCS, the pricing benchmark for Canadian heavy oil at Hardisty, Alberta. WCS trades at a discount to WTI known as the WCS differential, which fluctuates based on heavy oil production, inventory levels, infrastructure egress capacity, and refinery demand in Canada and the United States, among other factors.

Condensate

The Company uses condensate as a blending diluent to facilitate transportation of its produced bitumen. The price of condensate has historically been correlated to the price of WTI but is usually comparatively higher in winter months owing to increased diluent requirements in colder temperatures relative to warmer summer months.

Oil Sales

Greenfire’s oil sales include diluted and non-diluted bitumen sales. Volumes from the Demo Asset can be transported to various sales locations, including pipeline and rail points, based on the economics at the time of sale. The Expansion Asset includes a bitumen truck off-loading facility (the “Truck Rack”) capable of receiving approximately 5,000 bbls/d of non-diluted bitumen from the Demo Asset. This bitumen can be blended with production from the Expansion Asset and sold via pipeline.

The Company recorded oil sales of $193.6 million and $614.1 million during the three and nine months ended, September 30, 2024, respectively, compared to $161.0 million and $514.2 million for the same periods of 2023, mainly due to higher sales volumes.

Royalties

Royalties consist of crown royalties paid to the Province of Alberta. Alberta oil sands royalty projects are based on government prescribed pre and post-payout(1) royalty rates, which are determined on a sliding scale using the Canadian dollar equivalent one-month trailing WTI benchmark price.

Royalties for a pre-payout project are based on a monthly calculation that applies a royalty rate (ranging from one percent to nine percent, based on the Canadian dollar equivalent WTI benchmark price) to the gross revenues from the project. Gross revenues are a function of oil sales less diluent costs and transportation costs. The Expansion Asset is a pre-payout project.

Royalties for a post-payout project are based on an annualized calculation that uses the greater of: (1) the gross revenues multiplied by the applicable royalty rate (one percent to nine percent, based on the Canadian dollar equivalent WTI benchmark price); or (2) the net revenues of the project multiplied by the applicable royalty rate (25 percent to 40 percent, based on the Canadian dollar equivalent WTI benchmark price). Net revenues are a function of oil sales less diluent costs, transportation costs, and allowable operating and capital costs.

While the Demo Asset is a post-payout project, due to the carry forward of previous years costs, it is currently assessed under scenario (1) discussed above, for the nine-month period ended September 30, 2024. The Company’s Demo Asset may become assessable under scenario (2) in 2025, depending on production, oil prices and costs.

Royalties were $5.11/bbl and $4.77/bbl during the three and nine months ended September 30, 2024, respectively, compared to $5.60/bbl and $3.64/bbl for the same respective periods in 2023. The Effective royalty rate was 7.52% and 7.36% during the three and nine months ended 2024, compared to 7.49% and 7.01% for the same respective periods in 2023.

Risk Management Contracts

The Company is exposed to commodity price risk on its oil sales and energy operating costs due to fluctuations in market prices. The Company continues to execute a risk management program that is primarily designed to reduce the volatility of revenue and cash flow, generate sufficient cash flows to service debt obligations and fund the Company’s operations. The Company’s risk management liabilities may consist of hedging instruments such as fixed price swaps and option structures, including costless collars on WTI, WCS differentials, condensate differential, natural gas and electricity swaps. The Company does not use financial derivatives for speculative purposes.

The Company’s obligations under its 2028 Notes (as outlined in the “Capital Resources and Liquidity – Long Term Debt” section of this MD&A), includes a requirement to implement and maintain a twelve month forward commodity price risk management program encompassing not less than 50% of the hydrocarbon output under the proved developed producing reserves (“PDP”) forecast in the Company’s most recent reserves report, as determined by a qualified and independent reserves evaluator.

The Company’s commodity price risk management program does not involve margin accounts that require posting of margin, including in scenarios of increased volatility in underlying commodity prices. Financial risk management contracts are measured at fair value, with gains and losses on re-measurement included in the consolidated statements of comprehensive income (loss) in the period in which they arise.

The Company’s financial risk management contracts are subject to master netting agreements that create the legal right to settle the instruments on a net basis. No instruments were netted as at September 30, 2024 or December 31, 2023.

Outstanding Financial Risk Management Contracts at September 30, 2024

Financial Risk Management Contracts Subsequent to September 30, 2024

Realized and Unrealized Gain (Loss) on Risk Management Contracts

Financial contracts settled in the period result in realized gains or losses based on the market price compared to the contract price and the notional volume outstanding. Changes in the fair value of unsettled financial contracts are reported as unrealized gains or losses in the period as the forward markets for commodities fluctuate and as new contracts are executed.

Three Months Ended September 30, 2024

Nine Months Ended September 30, 2024

Diluent Expense

To facilitate the transportation of bitumen, the Company uses condensate as a blending diluent. Greenfire’s diluent expense includes the cost of the condensate and the associated transportation costs to the Hangingstone Facilities. The Company’s diluent expense was $9.08/bbl and $11.73/bbl during the three and nine months ended September 30, 2024, respectively, $7.37/bbl and $15.99/bbl for the same respective periods in 2023.

Transportation and Marketing Expense

Transportation expenses at the Expansion Asset includes the costs to move bitumen from the facility to the sales point. At the Demo Asset, transportation expenses relate to the trucking of bitumen from the facility to various pipeline and rail sales points, including to the Truck Rack.

Greenfire has exclusive marketing contracts with a large, reputable international energy marketing company. These agreements expire in April 2026 and October 2028 for the Demo Asset and Expansion Asset, respectively. Exclusive marketing services include the purchase of all bitumen produced, the facilitation of all bitumen transportation from both assets, and the supply of all the diluent at the Expansion Asset. In addition to marketing fees, production at the Demo Asset is subject to royalty incentives and performance fees under these agreements.

Transportation and marketing expenses were $7.34/bbl and $7.47/bbl during the three and nine months ended September 30, 2024, respectively, lower than $9.69/bbl and $8.72/bbl for the same respective periods in 2023, mainly due to lower pipeline supplier tariffs.

Operating Expenses

Operating expenses include energy operating expenses and non-energy operating expenses.

The Company’s energy operating expenses for the three and nine months ended September 30, 2024, were $3.45/bbl and $4.84/bbl, respectively, which was lower than the comparative periods in 2023 of $9.85/bbl and $9.13/bbl, respectively. The lower per barrel energy operating expenses in 2024 were due to lower natural gas and electricity prices.

Non-energy operating expenses for the three and nine months ended September 30, 2024, were $20.45/bbl and $16.60/bbl, respectively, higher than the comparative periods in 2023 of $19.27/bbl and $14.29/bbl, respectively. The increase is due to the replacement of downhole temperature sensors, higher greenhouse gas emission fees, remediation work on the Demo Asset’s water disposal well, and general inflationary pressures.

Operating Netback(1)

Oil sales is a GAAP measure that is the most directly comparable measure to operating netback(1), which is a non-GAAP measure.

Operating netback(1) for the three months ended September 30, 2024 was $34.00/bbl compared to $38.08/bbl for the same period in 2023. This decrease is primarily related to a decrease in the WCS benchmark oil prices partially offset by lower operating expenses.

Operating netback(1) for the nine months ended September 30, 2024 $31.66/bbl compared to $21.65/bbl for the same respective periods in 2023. This increase was due to higher WCS benchmark oil prices, and lower diluent costs per barrel, partially offset by higher realized risk management contract losses.

General & Administrative Expenses

G&A expenses include head office and corporate costs such as salaries and employee benefits, legal fees, engineering services, audit and tax-related fees, and may also include expenses related to corporate strategic initiatives if any, among other costs. G&A expenses primarily fluctuate with head office staffing levels.

G&A expenses for the three months and nine months ended September 30, 2024, were $2.83/bbl and $2.57/bbl, respectively, which was higher than the comparative periods in 2023 of $2.50/bbl and $1.67/bbl, respectively. The increase in G&A expenses was due to the adoption of a limited purpose shareholder rights plan, the evaluation of strategic alternatives, and public company compliance costs associated with listing Common Shares on the NYSE and the TSX, combined with higher employee-related costs. The evaluation of strategic alternatives and the adoption of a shareholder rights plan are corporate strategic initiatives and are considered non-recurring.

Stock-Based Compensation

In September 2023, the Company adopted and later amended an omnibus share incentive plan (the “Incentive Plan”) in February 2024. The Incentive Plan allows for the issuance of DSUs, PSUs, RSUs, and options, reserving up to 10% of the Company’s issued and outstanding Common Shares, minus shares under other compensation arrangements, including PWs. The Board of Directors intends to settle all awards with Common Shares from treasury and classifying them as equity-settled. The Incentive Plan replaced the performance warrants plan; the PWs granted under the performance warrant plan fully vested in September of 2023 and no additional PWs may be granted.

The Company recorded stock-based compensation of $2.4 million in relation to the PSUs and RSUs issued during the three months ended September 30, 2024, compared to $9.2 million for the same period during 2023, relating to the PWs.

The Company recorded stock-based compensation of $5.8 million in relation to the PSUs, RSUs and DSUs issued during the nine months ended September 30, 2024, compared to $9.8 million for the same period during 2023, relating to the PWs.

DSUs are issued to members of the Board of Directors and vest immediately upon grant, however the units cannot be settled until the director ceases to be a director of the Company.

PSUs granted under the Incentive Plan vest on the third anniversary date of the grant date, and are subject to certain performance criteria as determined by the Board of Directors, which are set and measured to establish a performance multiplier from zero to two. PSUs have been granted with market-based and non-market operations-based performance criteria.

RSUs granted under the Incentive Plan typically vest annually in thirds over a three-year period, have no exercise price and automatically settle at each vesting date in either cash or shares issued from treasury at the Board of Directors’ discretion. On April 19, 2024, the Company granted 500,000 RSUs to M3-Brigage Sponsor III, LP (“MBSC Sponsor”) for the provision of consulting services. Refer to the “Related Party Transaction” section in this MD&A for further information.