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In SCOOP/STACK, we brought seven gross wells online during the quarter with results that have exceeded our expectations, and company-wide, we expect to bring an additional 13 gross wells online throughout the rest of this fiscal year. We are pleased with the performance at Chaveroo, where we will begin drilling our next round of four gross wells in January 2025 to allow for warmer fracking conditions while continuing to position us for high-impact drilling in the upcoming quarters. At Delhi, we are proceeding as planned with ExxonMobil on the development of Test Site V, with the first of three initial producer wells on track to be drilled by fiscal year-end. In addition, the CO₂ supply line to the field was recently placed back in service after eight months of maintenance, allowing an increase in injection volumes that we expect will yield a positive impact on oil production and revenue, partially offset by the CO₂ purchase cost. These initiatives will continue to strengthen and further diversify our organic growth portfolio."

Mr. Loyd concluded, "As we look to the future, we remain focused on executing our strategy to drive long-term shareholder value. Our asset base has been strengthened by acquiring high-quality, long-life, low-decline properties and by adding valuable drilling locations at favorable costs. We believe our track record of delivering both organic and inorganic growth at highly accretive valuations will support our dividend program for years to come."

Fiscal First Quarter 2025 Financial Results

Total revenues increased 6% to $21.9 million compared to $20.6 million in the year-ago period. The improvement was driven by an increase in production volumes largely due to the Company's SCOOP/STACK acquisitions in February 2024 and the ongoing drilling and completion activities occurring there, as well as our new wells at Chaveroo that came online at the same time. Decreases in commodity prices partially offset the increase in production volumes.

Lease operating costs ("LOE") decreased to $11.8 million compared to $11.9 million in the year-ago period. On a per unit basis, total LOE decreased 14% to $17.14 per BOE compared to $20.01 per BOE last year. The overall decrease was driven by the suspension of CO₂ purchases at Delhi Field for the quarter due to maintenance on the pipeline that began in February 2024. CO₂ purchases restarted in October. The increase in production from our SCOOP/STACK properties and Chaveroo wells, which incur lower relative operating costs than our other areas, has also driven down our LOE on a per-unit basis.

Depletion, depreciation, and accretion expense was $5.7 million compared to $4.3 million in the year-ago period. On a per BOE basis, the Company's current quarter depletion rate increased to $7.74 per BOE compared to $6.58 per BOE in the year-ago period due to an increase in depletable base related to the Company's SCOOP/STACK acquisitions and capital development expenditures added since the prior fiscal year.

General and administrative ("G&A") expenses, excluding stock-based compensation, decreased to $2.0 million compared to $2.1 million in the year-ago period. On a per BOE basis, G&A expenses were $2.86 compared to $3.59 in the year-ago period. The decrease was primarily due to a reduction in transaction and third-party consulting fees.

Net income increased 40% to $2.1 million or $0.06 per diluted share, compared to $1.5 million or $0.04 per diluted share in the year-ago period.

Adjusted EBITDA increased 21% to $8.1 million compared to $6.7 million in the year-ago period. The increase was primarily due to increased revenue and reduced operating costs from the year-ago period.

Production & Pricing

Total production for the first quarter of fiscal 2025 increased 16% to 7,478 net BOEPD compared to 6,457 net BOEPD in the year-ago period. Total production for the first quarter of fiscal 2025 included 2,217 barrels per day ("BOPD") of crude oil, 4,033 BOEPD of natural gas, and 1,228 BOEPD of NGLs. The increase in total production was driven by the closing of the Company's SCOOP/STACK acquisitions in February 2024 and production from the initial three wells in the Chaveroo oilfield coming online at the same time. Liquids production generated 80% of revenue for the quarter compared to 73% in the year-ago period.

The Company's average realized commodity price (excluding the impact of derivative contracts) decreased 8% to $31.83 per BOE compared to $34.68 per BOE in the year-ago period. These decreases were primarily driven by a decrease of approximately 30% in realized natural gas prices year-over-year.

Operations Update

At SCOOP/STACK, the Company's operators brought seven gross wells online during fiscal Q1 2025, and an additional three gross wells have been brought online since quarter-end. Additionally, Evolution has agreed to participate in five gross new horizontal wells across the acreage. Since the effective date of the acquisitions, a total of 32 gross wells (or 0.5 net wells) have commenced first production.

In the Chaveroo oilfield, Evolution plans to exercise its full 50% working interest in four horizontal wells located in Drilling Block 2 during fiscal 2025. These operations are expected to begin in early fiscal Q3 2025. The Company has preliminarily agreed to six additional horizontal wells in Drilling Block 3, which are anticipated to begin operations in early fiscal 2026.

In the Williston Basin, production was impacted by a few high-volume wells going offline. The production for these wells was quickly restored.

At Delhi, production was up quarter-over-quarter, attributed to the replacement of one of the CO₂ recycle compressors that had limited CO₂ injection in the prior quarter. Production was also affected by the CO₂ purchase pipeline being down for preventative maintenance from the end of February 2024 through fiscal Q1 2025. CO₂ purchases resumed in October 2024.

Balance Sheet, Liquidity, and Capital Spending

On September 30, 2024, cash and cash equivalents totaled $6.9 million, and working capital was $8.5 million. Evolution had $39.5 million of borrowings outstanding under its revolving credit facility, which was used to fund the acquisitions of SCOOP/STACK, and total liquidity of $17.4 million, including cash and cash equivalents. In fiscal Q1, Evolution paid $4.0 million in common stock dividends and $2.7 million in capital expenditures.

Cash Dividend on Common Stock

On November 11, 2024, Evolution's Board of Directors declared a cash dividend of $0.12 per share of common stock, which will be paid on December 31, 2024, to common stockholders of record on December 13, 2024. This will be the 45^th consecutive quarterly cash dividend on the Company's common stock since December 31, 2013. To date, Evolution has returned approximately $122.5 million, or $3.69 per share, back to stockholders in common stock dividends.

Conference Call

As previously announced, Evolution Petroleum will host a conference call on Wednesday, November 13, 2024, at 10:00 a.m. CT to review its fiscal first quarter 2025 financial and operating results. Participants can join online at https://event.choruscall.com/mediaframe/webcast.html?webcastid=zEqrDXV4 or by dialing (844) 481-2813. Dial-in participants should ask to join the Evolution Petroleum Corporation call. A replay will be available through November 13, 2025, via the provided webcast link and on Evolution's Investor Relations website at www.ir.evolutionpetroleum.com.

About Evolution Petroleum

Evolution Petroleum Corporation is an independent energy company focused on maximizing total shareholder returns through the ownership of and investment in onshore oil and natural gas properties in the U.S. The Company aims to build and maintain a diversified portfolio of long-life oil and natural gas properties through acquisitions, selective development opportunities, production enhancements, and other exploitation efforts. Properties include non-operated interests in the following areas: the SCOOP/STACK plays of the Anadarko Basin in Oklahoma; the Chaveroo Oilfield located in Chaves and Roosevelt Counties, New Mexico; the Jonah Field in Sublette County, Wyoming; the Williston Basin in North Dakota; the Barnett Shale located in North Texas; the Hamilton Dome Field located in Hot Springs County, Wyoming; the Delhi Holt-Bryant Unit in the Delhi Field in Northeast Louisiana; as well as small overriding royalty interests in four onshore Texas wells. Visit www.evolutionpetroleum.com for more information.

Cautionary Statement

All forward-looking statements contained in this press release regarding the Company's current and future expectations, potential results, and plans and objectives involve a wide range of risks and uncertainties. Statements herein using words such as "believe," "expect," "may," "plans," "outlook," "should," "will," and words of similar meaning are forward-looking statements. Although the Company's expectations are based on business, engineering, geological, financial, and operating assumptions that it believes to be reasonable, many factors could cause actual results to differ materially from its expectations. The Company gives no assurance that its goals will be achieved. These factors and others are detailed under the heading "Risk Factors" and elsewhere in our periodic reports filed with the Securities and Exchange Commission ("SEC"). The Company undertakes no obligation to update any forward-looking statement.

Contact
Investor Relations
(713) 935-0122
ir@evolutionpetroleum.com

Evolution Petroleum Corporation
Non-GAAP Reconciliation – Adjusted EBITDA (Unaudited)
(In thousands)

Adjusted EBITDA and Net income (loss) and earnings per share excluding selected items are non-GAAP financial measures that are used as supplemental financial measures by our management and by external users of our financial statements, such as investors, commercial banks, and others, to assess our operating performance as compared to that of other companies in our industry, without regard to financing methods, capital structure, or historical costs basis. We use these measures to assess our ability to incur and service debt and fund capital expenditures. Our Adjusted EBITDA and Net income (loss) and earnings per share, excluding selected items, should not be considered alternatives to net income (loss), operating income (loss), cash flows provided by (used in) operating activities, or any other measure of financial performance or liquidity presented in accordance with U.S. GAAP. Our Adjusted EBITDA and Net income (loss) and earnings per share excluding selected items may not be comparable to similarly titled measures of another company because all companies may not calculate Adjusted EBITDA and Net income (loss) and earnings per share excluding selected items in the same manner.

We define Adjusted EBITDA as net income (loss) plus interest expense, income tax expense (benefit), depreciation, depletion, and accretion (DD&A), stock-based compensation, ceiling test impairment, and other impairments, unrealized loss (gain) on change in fair value of derivatives, and other non-recurring or non-cash expense (income) items.

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^{(1) The tax impact for the three months ended September 30, 2024, and June 30, 2024, is represented using estimated tax rates of 28.4% and 16.4%, respectively. The effective tax rate increased year-over-year as projected state income taxes have become a larger component of our overall income tax expense during the current quarter.
(2) Net income (loss) and earnings per share excluding selected items are non-GAAP financial measures presented as supplemental financial measures to enable a user of the financial information to understand the impact of these items on reported results. These financial measures should not be considered an alternative to net income (loss), operating income (loss), cash flows provided by (used in) operating activities, or any other measure of financial performance or liquidity presented in accordance with U.S. GAAP. Our Adjusted Net Income (Loss) and earnings per share may not be comparable to similarly titled measures of another company because all companies may not calculate Adjusted Net Income (Loss) and earnings per share in the same manner.
(3) The impact of selected items for the three months ended September 30, 2024, and 2023, was calculated based upon weighted average diluted shares of 32.9 million and 33.0 million, respectively, due to the net income (loss), excluding selected items. The impact of selected items for the three months ended June 30, 2024, was calculated based upon weighted average diluted shares of 32.8 million due to the net income (loss), excluding selected items.}

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^{(1) Equivalent oil reserves are defined as six MCF of natural gas and 42 gallons of NGLs to one barrel of oil conversion ratio, which reflects energy equivalence and not price equivalence. Natural gas prices per MCF and NGL prices per barrel often differ significantly from the equivalent amount of oil.
(2) Amounts exclude the impact of cash paid or received on the settlement of derivative contracts since we did not elect to apply hedge accounting.}

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^{(1) Equivalent oil reserves are defined as six MCF of natural gas and 42 gallons of NGLs to one barrel of oil conversion ratio, which reflects energy equivalence and not price equivalence. Natural gas prices per MCF and NGL prices per barrel often differ significantly from the equivalent amount of oil.}

Evolution Petroleum Corporation
Summary of Open Derivative Contracts (Unaudited)

For more information on the Company's hedging practices, see Note 7 to its financial statements included on Form 10-Q filed with the SEC for the quarter ended September 30, 2024.

The Company had the following open crude oil and natural gas derivative contracts as of November 12, 2024:

This press release was published by a CLEAR® Verified individual.