The table below summarizes the Company's financial and operating results for the three months ended September 30, 2023:

OPERATIONS AND WELL PERFORMANCE UPDATE

Logan began drilling operations in July at Simonette with a well in the North Simonette oil play segment (the "5-11 well") which was completed in August and began flowback in September. From there, the rig moved to South Simonette in August to drill a single well within the gas-condensate play segment (the "14-33 well") which was completed and began flowback in September. The rig then moved to Pouce Coupe to drill a three well pad which spud on September 7, 2023. The Pouce Coupe pad has now been completed and has just begun flowback.

North Simonette 5-11 Performance

The Logan 5-11 well is offsetting a 2012 vintage well (the "16-12 legacy well") that was completed with a 12 stage oil frac and 885 tonnes of proppant across 1,942 meters of horizontal. The 16-12 legacy well achieved peak monthly production of 120 bbls/d of oil and is expected to have ultimate recovery of 210 mbbl of oil, 4.7 mbbl of NGLs and 0.62 bcf of sales gas (318 mBOE with 68% liquids)^1.

The Logan 5-11 well was completed with a high intensity frac consisting of 207 stages and 8,275 tonnes of proppant across 2,914 meters of horizontal. For the month of October, 5-11 averaged 494 bbls/d of oil, 8 bbls/d of NGLs and 1.4 mmcf/d of sales gas (732 BOE/d with 69% liquids)². As of October 31, 2023, the well had been on production for 65 days. The water cut continues to decline as the well continues to clean up. Importantly, the drawdown for October was only ~25% (or 5MPa of drawdown) due to downhole pump capacity limits demonstrating that the well has significantly more inflow potential. The Company's experience is that wells in the under-pressured Montney oil play, like North Simonette, can take up to three to four months to reach peak production.

Initial production results from the 5-11 well exceeded our Previous H2 2023 Guidance (defined herein) assumptions by 35%. While the production results are early, Logan is encouraged by the results to date and believes that North Simonette will be a highly economic and material play segment for the Company going forward.

South Simonette 14-33 Performance

The Logan 14-33 well is offsetting the top performing legacy well in South Simonette (the "16-33 legacy well") that was completed in 2017 with a 70 stage frac and 3,150 tonnes of proppant across 2,937 meters of horizontal. The 16-33 legacy well achieved peak monthly production of 318 bbls/d of condensate, 45 bbls/d of NGLs and 5.9 mmcf/d of sales gas (1,352 BOE/d with 27% liquids) and is expected to have an ultimate recovery of 253 mbbl of condensate, 54 mbbl of NGLs and 7.1 bcf of sales gas (1,493 mBOE with 21% liquids) ³.

The Logan 14-33 well was completedwith 125 stages and 7,378 tonnes of proppant across 2,974 meters of horizontal. Importantly, the 14-33 well was landed 35 meters deeper in the Montney section than a typical legacy well in South Simonette, as Logan believes this will lead to materially better liquids capture.

For the month of October, 14-33 averaged 528 bbls/d of condensate, 47 bbls/d of NGLs and 6.1 mmcf/d of sales gas (1,598 BOE/d with 36% liquids) ⁴. As of October 31, 2023, the well had been on production for 38 days.

For context, the initial gas rate of 14-33 is equivalent to that of the best legacy well in the field, but 14-33's liquids ratio of 87 bbl/mmcf is ~60% higher than the offsetting legacy well's initial liquids ratio and substantially higher than the average legacy well.

Initial production results from the 14-33 well exceeded our Previous H2 2023 Guidance assumptions by 81%, with the condensate rate exceeding our guidance assumptions by over 145%. Logan is also very encouraged by these early results in South Simonette. To date, the new deeper landing depth and more intense completion is yielding increased condensate production consistent with our hypothesis.

On the back of these well results, Logan took advantage of a rig coming available in the area and has commenced drilling again with a three well pad spud at South Simonette on October 28, 2023 ("4-10 Pad"). The Company's total budget for Capital Expenditures before A&D of $75 million for 2023 remains unchanged. The land holding well initially planned for Flatrock in the fourth quarter of 2023 has been deferred to 2024 and replaced by this accelerated drilling at Simonette.

UPDATED H2 2023 GUIDANCE AND 2024 BUDGET

Logan is pleased to provide increased guidance for the second half of 2023 ("Updated H2 2023 Guidance") as well as the Company's preliminary budget for 2024 ("2024 Guidance").

On the strength of its initial well results in Simonette, the Company has raised its H2 2023 guidance to 6,000 BOE/d (previously 5,000 BOE/d).  For 2024, the Company's Board of Directors has approved an initial capital budget of $120 million. The budget is designed to deliver growth in Simonette, maintain production in Pouce Coupe and advance long term growth projects like Flatrock. The 2024 capital budget is allocated as follows: $64 million for drilling, completion, equipment and tie-in projects at Simonette and Pouce Coupe, $13 million for drilling and completion at Flatrock, $28 million for infrastructure and $15 million for land and contingency.

At Simonette, Logan plans to drill, complete and bring onstream four 100% working interest Montney wells. The 4-10 three well pad currently drilling is budgeted to come onstream in August 2024, allowing for contingency of an extended spring breakup. In addition, Logan plans to drill and test one well on the recently acquired lands in the Lator area.

At Pouce Coupe, Logan plans to drill and bring onstream a two well pad which will fill Logan's available third-party processing capacity. During the third quarter, Logan advanced its long-term infrastructure plans for Pouce Coupe. Logan was successful in procuring strategic long-term egress for its Pouce Coupe development project by adding 40 mmcf/d of firm transport commencing in 2027. This is a critical part of the development plan for Pouce Coupe and ensures that Logan will be able to execute on its long-term growth plans for the asset. Logan is also advancing a company built and operated processing solution that is optimized for Logan's development plan. Additionally, Logan is advancing procurement of secondary market gas egress that, together with the processing solution, will target a production growth ramp between 2025 to 2027.

At Flatrock, Logan plans to drill its first two wells in 2024 and complete and test one of the two wells.

The following table summarizes Logan's 2024 Guidance, along with Updated H2 2023 Guidance as compared to previous guidance provided as part of the Company's press release dated July 13, 2023 ("Previous H2 2023 Guidance"), which is reproduced below:

The increase in average production forecast for H2 2023 to 6,000 BOE per day is reflective of new wells drilled both exceeding initial production type curves, as well as these wells coming on production earlier than originally estimated. The forecasted working capital surplus for year-end 2023 decreased as a result of 19.4 million transaction warrants that expired unexercised (which resulted in less dilution to the share count than originally anticipated), as well as unbudgeted land acquisitions completed by the Company, offset by the forecasted increase in Adjusted Funds Flow. The 2024 budget of 8,700 BOE per day assumes all new pads come onstream in mid 2024; Logan expects to exit 2024 above 10,000 BOE per day (Q4 average production⁵).

GRANT OF STOCK OPTIONS

On November 22, 2023, the Company's Board of Directors approved the grant of 22.7 million stock options with an exercise price of $0.89 per common share and a five year term. The options vest as to one-third on each of the first, second and third anniversary of the grant date. Of the total number of options granted, an aggregate of 9.7 million options were granted to officers and directors of the Company.

ABOUT LOGAN ENERGY CORP.

Logan is a growth-oriented exploration, development and production company formed through the spin-out of Spartan's early stage Montney assets. Logan is founded with a strong initial capitalization and three high quality and opportunity rich Montney assets located in the Simonette and Pouce Coupe areas of northwest Alberta and the Flatrock area of northeastern British Columbia. The management team brings proven leadership and a track record of generating excess returns in various business cycles.

READER ADVISORIES

Non-GAAP Measures and Ratios

This press release contains certain financial measures and ratios which do not have standardized meanings prescribed by International Financial Reporting Standards ("IFRS") or Generally Accepted Accounting Principles ("GAAP"). As these non-GAAP financial measures and ratios are commonly used in the oil and gas industry, Logan believes that their inclusion is useful to investors. The reader is cautioned that these amounts may not be directly comparable to measures for other companies where similar terminology is used.

The non-GAAP measures and ratios used in this press release, represented by the capitalized and defined terms outlined below, are used by Logan as key measures of financial performance and are not intended to represent operating profits nor should they be viewed as an alternative to cash provided by operating activities, net income or other measures of financial performance calculated in accordance with IFRS.

The definitions below should be read in conjunction with the "Non-GAAP and Other Financial Measures" section of the Company's MD&A dated November 22, 2023, which includes discussion of the purpose and composition of the specified financial measures and detailed reconciliations to the most directly comparable GAAP financial measures.

Operating Income and Operating Netback

Operating Income, a non-GAAP financial measure, is a useful supplemental measure that provides an indication of the Company's ability to generate cash from field operations, prior to administrative overhead, financing and other business expenses. "Operating Income" is calculated by Logan as oil and gas sales, net of royalties, plus processing and other revenue, less operating and transportation expenses.

The Company refers to Operating Income expressed per unit of production as an "Operating Netback" which is a non-GAAP financial ratio. Logan considers Operating Netback an important measure to evaluate its operational performance as it demonstrates its field level profitability relative to current commodity prices.

Adjusted Funds Flow

Cash provided by operating activities is the most directly comparable measure to Adjusted Funds Flow. "Adjusted Funds Flow" is reconciled to cash provided by operating activities by excluding changes in non-cash working capital, adding back transaction costs on acquisitions (if applicable). Logan utilizes Adjusted Funds Flow as a key performance measure in the Company's annual financial forecasts and public guidance.

The Company refers to Adjusted Funds Flow expressed per unit of production as an "Adjusted Funds Flow Netback".

Capital Expenditures before A&D

"Capital Expenditures before A&D" is used by Logan to measure its capital investment level compared to the Company's annual budgeted capital expenditures for its organic drilling program. It includes capital expenditures on exploration and evaluation assets and property, plant and equipment, before acquisitions and dispositions. The directly comparable GAAP measure to capital expenditures is cash used in investing activities.

Capital Management Measures

Working capital

Management uses working capital as a measure to assess the Company's financial position. The working capital surplus (deficit) is calculated as current assets less current liabilities determined in accordance with GAAP.

Supplementary Financial Measures

The supplementary financial measures used in this press release (primarily average sales price per product type and certain per BOE and per share figures) are either a per unit disclosure of a corresponding GAAP measure, or a component of a corresponding GAAP measure, presented in the financial statements. Supplementary financial measures that are disclosed on a per unit basis are calculated by dividing the aggregate GAAP measure (or component thereof) by the applicable unit for the period. Supplementary financial measures that are disclosed on a component basis of a corresponding GAAP measure are a granular representation of a financial statement line item and are determined in accordance with GAAP.

Other Measurements

All dollar figures included herein are presented in Canadian dollars, unless otherwise noted. This press release contains various references to the abbreviation "BOE" which means barrels of oil equivalent. Where amounts are expressed on a BOE basis, natural gas volumes have been converted to oil equivalence at six thousand cubic feet (Mcf) per barrel (bbl). The term BOE may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet per barrel is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead and is significantly different than the value ratio based on the current price of crude oil and natural gas. This conversion factor is an industry accepted norm and is not based on either energy content or current prices. Such abbreviation may be misleading, particularly if used in isolation.

References to "oil" in this press release include light crude oil, medium crude oil, heavy oil and tight oil combined. NI 51-101 includes condensate within the product type of "natural gas liquids". References to "natural gas liquids" or "NGLs" include pentane, butane, propane and ethane. References to "gas" or "natural gas" relates to conventional natural gas. References to "liquids" includes crude oil, condensate and NGLs.

References in this press release to peak rates, peak monthly production, producing day rates and other short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long-term performance or of ultimate recovery. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production of Logan.

Assumptions for Guidance

Logan expects production to average approximately 6,000 BOE/d for the second half of 2023 (previously 5,000 BOE/d). The significant assumptions used in the forecast of Operating Netbacks and Adjusted Funds Flow for the Company's 2024 Guidance, the Updated H2 2023 Guidance and Previous H2 2023 Guidance are summarized below.

 

Share Capital

Common shares of Logan trade on the TSX Venture Exchange ("TSXV") under the symbol "LGN".

As of the date hereof, there are 465.5 million common shares outstanding. There are no preferred shares or special shares outstanding. Logan's convertible securities outstanding as of the date of this press release include: 64.3 million common share purchase warrants with an exercise price of $0.35 per share expiring July 12, 2028; and 22.7 million stock options with an exercise price of $0.89 per share expiring November 22, 2028.

Reserves Disclosure

All P+PDP EUR information contained in this press release is derived from the report prepared by McDaniel & Associates Consultants Ltd. ("McDaniel"), an independent qualified reserve evaluator, dated March 14, 2023 and effective as of March 1, 2023 (the "McDaniel Report") evaluating the crude oil, natural gas and natural gas liquids reserves attributable to assets acquire by Logan from Spartan pursuant to the Spin-Out. All reserve references in this press release are "Company gross reserves". Company gross reserves are the Company's total working interest reserves before the deduction of any royalties payable by the Company. Estimates of reserves for individual properties may not reflect the same level of confidence as estimates of reserves for all properties, due to the effect of aggregation. There is no assurance that the forecast price and cost assumptions applied by McDaniel in evaluating Logan's reserves will be attained and variances could be material.

Forward-Looking and Cautionary Statements

Certain statements contained within this press release constitute forward-looking statements within the meaning of applicable Canadian securities legislation. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "anticipate", "budget", "plan", "endeavor", "continue", "estimate", "evaluate", "expect", "forecast", "monitor", "may", "will", "can", "able", "potential", "target", "intend", "consider", "focus", "identify", "use", "utilize", "manage", "maintain", "remain", "result", "cultivate", "could", "should", "believe" and similar expressions. Logan believes that the expectations reflected in such forward-looking statements are reasonable as of the date hereof, but no assurance can be given that such expectations will prove to be correct and such forward-looking statements should not be unduly relied upon. Without limitation, this press release contains forward-looking statements pertaining to: Logan's Updated H2 2023 Guidance and 2024 Guidance, including with respect to drilling, completions, tie-ins and infrastructure; the Company's opportunity rich assets; the assumption that new gas processing commitments at Pouce Coupe will be sufficient for near-term growth plans and retain long-term optionality; the assumption that Logan is well capitalized to execute on its growth strategy, including the assumption that the borrowing base under the Company's credit facility will be increased following completion of the 2023 year-end reserves report; the belief that North Simonette will be a highly economic and material play segment going forward; newer deeper landing depth and more intense completions will yield increased condensate production; the expected completion and on stream date for the 4-10 Pad at Simonette; and the timing of drilling its first two wells and completing and testing one well at Flatrock. In addition, statements relating to expected production, reserves, recovery, costs and valuation are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves described can be profitably produced in the future.

The forward-looking statements and information are based on certain key expectations and assumptions made in respect of Logan including expectations and assumptions concerning the business plan of Logan, the timing of and success of future drilling, development and completion activities, the performance of existing wells, the performance of new wells, the availability and performance of facilities and pipelines, the geological characteristics of Logan's properties, the successful integration of the recently acquired assets into Logan's operations, the successful application of drilling, completion and seismic technology, prevailing weather conditions, prevailing legislation affecting the oil and gas industry, prevailing commodity prices, price volatility, price differentials and the actual prices received for Logan's products, impact of inflation on costs, royalty regimes and exchange rates, the application of regulatory and licensing requirements, the availability of capital, labour and services, the creditworthiness of industry partners and the ability to source and complete acquisitions.

Although Logan believes that the expectations and assumptions on which such forward-looking statements and information are based are reasonable, undue reliance should not be placed on the forward-looking statements and information because Logan can give no assurance that they will prove to be correct. By its nature, such forward-looking information is subject to various risks and uncertainties, which could cause the actual results and expectations to differ materially from the anticipated results or expectations expressed. These risks and uncertainties include, but are not limited to, fluctuations in commodity prices, changes in industry regulations and political landscape both domestically and abroad, wars (including Russia's ongoing military actions in Ukraine and the recent crisis in Israel and Gaza), hostilities, civil insurrections, foreign exchange or interest rates, increased operating and capital costs due to inflationary pressures (actual and anticipated), volatility in the stock market and financial system, impacts of pandemics, the retention of key management and employees, risks with respect to unplanned third party pipeline outages and risks relating to inclement and severe weather events and natural disasters, such as fire, drought and flooding, including in respect of safety, asset integrity and shutting-in production. Ongoing military actions between Russia and Ukraine and the recent crisis in Israel and Gaza have the potential to threaten the supply of oil and gas from those regions. The long-term impacts of these actions remains uncertain. The foregoing list is not exhaustive. Please refer to the MD&A and Logan's listing application dated July 12, 2023, for discussion of additional risk factors relating to Logan, which can be accessed on its SEDAR+ profile at www.sedarplus.ca. Readers are cautioned not to place undue reliance on this forward-looking information, which is given as of the date hereof, and to not use such forward-looking information for anything other than its intended purpose. Logan undertakes no obligation to update publicly or revise any forward-looking information, whether as a result of new information, future events or otherwise, except as required by law.

This press release contains future-oriented financial information and financial outlook information (collectively, "FOFI") about Logan's prospective results of operations and production, including expectations to exit 2024 above 10,000 BOE per day, organic growth, operating costs, capital expenditures, Adjusted Funds Flow, working capital, Operating Netback, Logan's Updated H2 2023 Guidance and 2024 Guidance and components thereof, all of which are subject to the same assumptions, risk factors, limitations, and qualifications as set forth in the above paragraphs. FOFI contained in this document was approved by management as of the date of this document and was provided for the purpose of providing further information about Logan's proposed business activities in 2023 and 2024. Logan and its management believe that FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments, and represent, to the best of management's knowledge and opinion, the Company's expected course of action. However, because this information is highly subjective, it should not be relied on as necessarily indicative of future results. Logan disclaims any intention or obligation to update or revise any FOFI contained in this document, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law. Readers are cautioned that the FOFI contained in this document should not be used for purposes other than for which it is disclosed herein. Changes in forecast commodity prices, differences in the timing of capital expenditures, and variances in average production estimates can have a significant impact on the key performance measures included in Logan's guidance. The Company's actual results may differ materially from these estimates.

Neither TSX Venture Exchange nor its regulation services provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this news release.

Abbreviations

SOURCE Logan Energy Corp.

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