Amplify Energy Corp 10-Q for FY2025 Q3
Amplify Energy Corp. (AMPY)
About this 10-Q
Amplify Energy Corp filed this 10-Q on November 5, 2025, covering the quarter ended September 30, 2025 (FY2025 Q3).
Headline figures
Quarter ended September 30, 2025, as reported in this filing, compared with the same period a year earlier where the filing states it.
- Revenue
- $66.4M
- down 5.0% from $69.86M a year earlier
- Net loss
- $20.97M
- compared with net income of $22.65M a year earlier
- Diluted EPS
- -$0.52
- compared with $0.54 a year earlier
UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the quarterly period ended
OR
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the transition period from to .
Commission File Number:
(Exact name of registrant as specified in its charter)
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(State or other jurisdiction of incorporation or organization) | | (I.R.S. Employer Identification No.) |
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(Address of principal executive offices) | | (Zip Code) |
Registrant’s telephone number, including area code: (
Not Applicable
(Former name or Former Address, if changed since last report)
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer ☐ | |
Non-accelerated filer ☐ | Smaller reporting company |
Emerging growth company | |
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b–2 of the Exchange Act). Yes
Securities Registered Pursuant to Section 12(b):
Title of each class | Trading Symbol(s) | Name of each exchange on which registered |
As of October 31, 2025, the registrant had
AMPLIFY ENERGY CORP.
TABLE OF CONTENTS
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Item 1. | | | 8 | |
| | Unaudited Condensed Consolidated Balance Sheets as of September 30, 2025 and December 31, 2024 | | 8 |
| | | 9 | |
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| | Notes to Unaudited Condensed Consolidated Financial Statements | | 12 |
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Item 2. | | Management’s Discussion and Analysis of Financial Condition and Results of Operations | | 31 |
Item 3. | | | 43 | |
Item 4. | | | 43 | |
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Item 1. | | | 44 | |
Item 1A. | | | 44 | |
Item 2. | | | 44 | |
Item 3. | | | 45 | |
Item 4. | | | 45 | |
Item 5. | | | 45 | |
Item 6. | | | 46 | |
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| | | 48 | |
i
GLOSSARY OF OIL AND NATURAL GAS TERMS
Analogous Reservoir: Analogous reservoirs, as used in resource assessments, have similar rock and fluid properties, reservoir conditions (depth, temperature, and pressure) and drive mechanisms, but are typically at a more advanced stage of development than the reservoir of interest and thus may provide concepts to assist in the interpretation of more limited data and estimation of recovery. When used to support proved reserves, analogous reservoir refers to a reservoir that shares all of the following characteristics with the reservoir of interest: (i) the same geological formation (but not necessarily in pressure communication with the reservoir of interest); (ii) the same environment of deposition; (iii) similar geologic structure; and (iv) the same drive mechanism.
Bbl: One stock tank barrel, or 42 U.S. gallons liquid volume, used in reference to oil or other liquid hydrocarbons.
Bbl/d: One Bbl per day.
Bcfe: One billion cubic feet of natural gas equivalent.
Boe: One barrel of oil equivalent, calculated by converting natural gas to oil equivalent barrels at a ratio of six Mcf of natural gas to one Bbl of oil.
BOEM: U.S. Bureau of Ocean Energy Management.
BSEE: Bureau of Safety and Environmental Enforcement.
Btu: One British thermal unit, the quantity of heat required to raise the temperature of a one-pound mass of water by one degree Fahrenheit.
CO2: Carbon dioxide.
Development Project: A development project is the means by which petroleum resources are brought to the status of economically producible. As examples, the development of a single reservoir or field, an incremental development in a producing field or the integrated development of a group of several fields and associated facilities with a common ownership may constitute a development project.
Dry Hole or Dry Well: A well found to be incapable of producing hydrocarbons in sufficient quantities such that proceeds from the sale of such production would exceed production expenses and taxes.
Economically Producible: The term economically producible, as it relates to a resource, means a resource which generates revenue that exceeds, or is reasonably expected to exceed, the costs of the operation. For this determination, the value of the products that generate revenue are determined at the terminal point of oil and natural gas producing activities.
Exploitation: A development or other project which may target proven or unproven reserves (such as probable or possible reserves), but which generally has a lower risk than that associated with exploration projects.
Field: An area consisting of a single reservoir or multiple reservoirs, all grouped on or related to the same individual geological structural feature and/or stratigraphic condition. The field name refers to the surface area, although it may refer to both the surface and the underground productive formations.
Gross Acres or Gross Wells: The total acres or wells, as the case may be, in which we have a working interest.
Henry Hub: A distribution hub in Louisiana that serves as the delivery location for natural gas futures contracts on the New York Mercantile Exchange.
ICE: Inter-Continental Exchange.
MBbl: One thousand Bbls.
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MBbls/d: One thousand Bbls per day.
MBoe: One thousand barrels of oil equivalent.
MBoe/d: One thousand barrels of oil equivalent per day.
MMBoe: One million barrels of oil equivalent.
Mcf: One thousand cubic feet of natural gas.
Mcf/d: One Mcf per day.
MMBtu: One million Btu.
MMcf: One million cubic feet of natural gas.
MMcfe: One million cubic feet of natural gas equivalent.
MMcfe/d: One MMcfe per day.
Net Production: Production that is owned by us less royalties and production due to others.
NGLs: The combination of ethane, propane, butane and natural gasolines that, when removed from natural gas, become liquid under various levels of higher pressure and lower temperature.
NYMEX: New York Mercantile Exchange.
NYSE: New York Stock Exchange.
Oil: Oil and condensate.
Operator: The individual or company responsible for the exploration and/or production of an oil or natural gas well or lease.
OPIS: Oil Price Information Service.
Plugging and Abandonment: Refers to the sealing off of fluids in the strata penetrated by a well so that the fluids from one stratum will not escape into another stratum or to the surface. Regulations of all states require plugging of abandoned wells.
Probabilistic Estimate: The method of estimation of reserves or resources is called probabilistic when the full range of values that could reasonably occur for each unknown parameter (from the geoscience and engineering data) is used to generate a full range of possible outcomes and their associated probabilities of occurrence.
Proved Developed Reserves: Proved reserves that can be expected to be recovered from existing wells with existing equipment and operating methods.
2
Proved Reserves: Those quantities of oil and natural gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible, from a given date forward, from known reservoirs, and under existing economic conditions, operating methods and government regulations, prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced, or the operator must be reasonably certain that it will commence the project, within a reasonable time. The area of the reservoir considered as proved includes (i) the area identified by drilling and limited by fluid contacts, if any, and (ii) adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or natural gas on the basis of available geoscience and engineering data. In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons, as seen in a well penetration, unless geoscience, engineering or performance data and reliable technology establishes a lower contact with reasonable certainty. Where direct observation from well penetrations has defined a highest known oil elevation and the potential exists for an associated natural gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty. Reserves which can be produced economically through application of improved recovery techniques (including fluid injection) are included in the proved classification when (i) successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir, or an Analogous Reservoir or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based, and (ii) the project has been approved for development by all necessary parties and entities, including governmental entities. Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price used is the average price during the twelve-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.
Realized Price: The cash market price less all expected quality, transportation and demand adjustments.
Reliable Technology: Reliable technology is a grouping of one or more technologies (including computational methods) that has been field tested and has been demonstrated to provide reasonably certain results with consistency and repeatability in the formation being evaluated or in an analogous formation.
Reserves: Reserves are estimated remaining quantities of oil and natural gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. In addition, there must exist, or there must be a reasonable expectation that there will exist, the legal right to produce or a revenue interest in the production, installed means of delivering oil and natural gas or related substances to market and all permits and financing required to implement the project. Reserves should not be assigned to adjacent reservoirs isolated by major, potentially sealing, faults until those reservoirs are penetrated and evaluated as economically producible. Reserves should not be assigned to areas that are clearly separated from a known accumulation by a non-productive reservoir (i.e., absence of reservoir, structurally low reservoir or negative test results). Such areas may contain prospective resources (i.e., potentially recoverable resources from undiscovered accumulations).
Reservoir: A porous and permeable underground formation containing a natural accumulation of producible oil and/or natural gas that is confined by impermeable rock or water barriers and is individual and separate from other reserves.
Resources: Resources are quantities of oil and natural gas estimated to exist in naturally occurring accumulations. A portion of the resources may be estimated to be recoverable and another portion may be considered unrecoverable. Resources include both discovered and undiscovered accumulations.
SEC: The U.S. Securities and Exchange Commission.
Working Interest: An interest in an oil and natural gas lease that gives the owner of the interest the right to drill for and produce oil and natural gas on the leased acreage and requires the owner to pay a share of the costs of drilling and production operations.
Workover: Operations on a producing well to restore or increase production.
WTI: West Texas Intermediate.
3
NAMES OF ENTITIES
As used in this Form 10-Q, unless indicated otherwise:
| ● | “Amplify Energy,” “Amplify,” “it,” the “Company,” “we,” “our,” “us,” or like terms refer to Amplify Energy Corp. individually and/or collectively with its subsidiaries, as the context requires; and |
| ● | “OLLC” refers to Amplify Energy Operating LLC, our wholly owned subsidiary through which we operate our properties. |
4
CAUTIONARY NOTE REGARDING FORWARD–LOOKING STATEMENTS
This Quarterly Report on Form 10-Q contains “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), that are subject to a number of risks and uncertainties, many of which are beyond our control, which may include statements about our:
| ● | business strategies; |
| ● | acquisition and disposition strategy; |
| ● | cash flows and liquidity; |
| ● | financial strategy; |
| ● | ability to replace the reserves we produce through drilling; |
| ● | drilling locations; |
| ● | oil and natural gas reserves; |
| ● | technology; |
| ● | realized oil, natural gas and NGL prices; |
| ● | production volumes; |
| ● | lease operating expense; |
| ● | gathering, processing and transportation; |
| ● | general and administrative expense; |
| ● | future operating results; |
| ● | ability to procure drilling and production equipment; |
| ● | ability to procure oil field labor; |
| ● | planned capital expenditures and the availability of capital resources to fund capital expenditures; |
| ● | ability to access capital markets; |
| ● | marketing of oil, natural gas and NGLs; |
| ● | political and economic conditions and events in foreign oil and natural gas producing countries, including embargoes, trade wars, continued hostilities in the Middle East and other sustained military campaigns; |
| ● | acts of God, fires, earthquakes, storms, floods, other adverse weather conditions, war, acts of terrorism, cybersecurity breaches, military operations or national emergency; |
| ● | the occurrence or threat of epidemic or pandemic diseases, or any government response to such occurrence or threat; |
5
| ● | expectations regarding general economic conditions, including inflation; |
| ● | competition in the oil and natural gas industry; |
| ● | effectiveness of risk management activities; |
| ● | environmental liabilities; |
| ● | counterparty credit risk; |
| ● | expectations regarding governmental regulation and taxation; |
| ● | expectations regarding developments in oil-producing and natural-gas producing countries; and |
| ● | plans, objectives, expectations and intentions. |
All statements, other than statements of historical fact included in this report, are forward-looking statements. In some cases, you can identify forward-looking statements by terminology such as “may,” “will,” “could,” “should,” “expect,” “plan,” “project,” “intend,” “anticipate,” “believe,” “estimate,” “predict,” “potential,” “pursue,” “target,” “outlook,” “continue,” the negative of such terms or other comparable terminology. These statements address activities, events or developments that we expect or anticipate will or may occur in the future, including things such as projections of results of operations, plans for growth, goals, future capital expenditures, competitive strengths, references to future intentions and other such references. These forward-looking statements involve risks and uncertainties. Important factors that could cause our actual results or financial condition to differ materially from those expressed or implied by forward-looking statements include, but are not limited to, the following risks and uncertainties:
| ● | risks related to a redetermination of the borrowing base under our senior secured reserve-based revolving credit facility (the “Revolving Credit Facility”); |
| ● | our ability to access funds on acceptable terms, if at all, because of the terms and conditions governing our indebtedness, including financial covenants; |
| ● | our ability to access funds on acceptable terms, if at all, due to potentially worsening economic conditions, including continued or further inflation, disruption in the financial markets, the imposition of tariffs or trade or other economic sanctions and political instability; |
| ● | our ability to satisfy debt obligations; |
| ● | volatility in the prices for oil, natural gas and NGLs, including due to actions taken by the Organization of the Petroleum Exporting Countries (OPEC+) as it pertains to global supply and demand of, and prices for such commodities; |
| ● | the potential for additional impairments due to continuing or future declines in oil, natural gas and NGL prices; |
| ● | the uncertainty inherent in estimating quantities of oil, natural gas and NGL reserves; |
| ● | our substantial future capital requirements, which may be subject to limited availability of financing; |
| ● | the uncertainty inherent in the development and production of oil and natural gas; |
| ● | our need to make accretive acquisitions or substantial capital expenditures to maintain our declining asset base; |
| ● | the existence of unanticipated liabilities or problems relating to acquired or divested businesses or properties; |
6
| ● | potential acquisitions, including our ability to make acquisitions on favorable terms or to integrate acquired properties; |
| ● | the consequences of changes we have made, or may make from time to time in the future, to our capital expenditure budget, including the impact of those changes on our production levels, reserves, results of operations and liquidity; |
| ● | potential shortages of, or increased costs for, drilling and production equipment and supply materials for production, such as CO2; |
| ● | potential difficulties in the marketing of oil and natural gas; |
| ● | changes to the financial condition of counterparties; |
| ● | uncertainties surrounding the success of our secondary and tertiary recovery efforts; |
| ● | competition in the oil and natural gas industry; |
| ● | our results of evaluation and implementation of strategic alternatives; |
| ● | general political and economic conditions, globally and in the jurisdictions in which we operate, including the Russian invasion of Ukraine, ongoing conflicts in the Middle East, trade wars and the potential destabilizing effect such conflicts may pose for those regions and/or the global oil and natural gas markets; |
| ● | the impact of climate change and natural disasters, such as earthquakes, tidal waves, mudslides, fires and floods; |
| ● | the impact of local, state and federal governmental regulations, including those related to climate change and hydraulic fracturing, and potential changes in these regulations; |
| ● | the risk that our hedging strategy may be ineffective or may reduce our income; |
| ● | the cost and availability of insurance as well as operating risks that may not be covered by an effective indemnity or insurance; |
| ● | actions of third-party co-owners of interests in properties in which we also own an interest; and |
| ● | other risks and uncertainties described in “Item 1A. Risk Factors.” |
The forward-looking statements contained in this report are largely based on our expectations, which reflect estimates and assumptions made by our management. These estimates and assumptions reflect our best judgment based on currently known market conditions and other factors. Although we believe such estimates and assumptions to be reasonable, they are inherently uncertain and involve a number of risks and uncertainties that are beyond our control. In addition, management’s assumptions about future events may prove to be inaccurate. All readers are cautioned that the forward-looking statements contained in this report are not guarantees of future performance, and we cannot assure any reader that such statements will be realized or that the events or circumstances described in any forward-looking statement will occur. Actual results may differ materially from those anticipated or implied in the forward-looking statements due to factors described in “Part I—Item 1A. Risk Factors” of Amplify’s Annual Report on Form 10-K for the year ended December 31, 2024 initially filed with the SEC on March 5, 2025 and amended on April 17, 2025 (“2024 Form 10-K”). All forward-looking statements speak only as of the date of this report. The Company does not intend to update or revise any forward-looking statements as a result of new information, future events or otherwise. These cautionary statements qualify all forward-looking statements attributable to the Company or persons acting on its behalf.
7
PART I—FINANCIAL INFORMATION
ITEM 1.FINANCIAL STATEMENTS.
AMPLIFY ENERGY CORP.
UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS
(In thousands, except outstanding shares)
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| September 30, |
| December 31, | ||
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| 2025 | | 2024 | ||
ASSETS |
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Current assets: |
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Cash and cash equivalents | | $ | | | $ | |
Accounts receivable, net (see Note 13) | |
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Short-term derivative instruments | |
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Prepaid expenses and other current assets | |
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Total current assets | |
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Property and equipment, at cost: | |
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Oil and natural gas properties, successful efforts method | |
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Support equipment and facilities | |
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Other | |
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Accumulated depreciation, depletion and amortization | |
| ( | |
| ( |
Property and equipment, net | |
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Long-term derivative instruments | |
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Restricted investments | |
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Operating lease - long term right-of-use asset | |
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Deferred tax asset | | | | | | |
Other long-term assets | |
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Total assets | | $ | | | $ | |
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LIABILITIES AND EQUITY | |
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Current liabilities: | |
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Accounts payable | | $ | | | $ | |
Revenues payable | |
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Accrued liabilities (see Note 13) | |
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Total current liabilities | |
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Long-term debt (see Note 8) | |
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Asset retirement obligations | |
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Operating lease liability | |
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Other long-term liabilities | |
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Total liabilities | |
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Commitments and contingencies (see Note 16) | |
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Stockholders' equity (deficit): | |
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Preferred stock, $ | |
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Common stock, $ | |
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Additional paid-in capital | |
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Accumulated deficit | |
| ( | |
| ( |
Total stockholders' equity (deficit) | |
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Total liabilities and equity | | $ | | | $ | |
See Accompanying Notes to Unaudited Condensed Consolidated Financial Statements.
8
AMPLIFY ENERGY CORP.
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except per share amounts)
|
| For the Three Months Ended | | For the Nine Months Ended | ||||||||
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| September 30, | | September 30, | ||||||||
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| 2025 |
| 2024 | | 2025 |
| 2024 | ||||
Revenues: |
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Oil and natural gas sales | | $ | | | $ | | | $ | | | $ | |
Other revenues | |
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Total revenues | |
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Costs and expenses: | |
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Lease operating expense | |
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Gathering, processing and transportation | |
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Taxes other than income | |
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Depreciation, depletion and amortization | |
| | | | | |
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Impairment expense | |
| | | | | |
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General and administrative expense | |
| | | | | |
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Accretion of asset retirement obligations | |
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Loss (gain) on commodity derivative instruments | |
| ( | | | ( | |
| ( | |
| ( |
Pipeline incident loss | | | | | | | | | | | | |
(Gain) loss on sale of properties | | | ( | | | | | | ( | | | |
Other, net | |
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Total costs and expenses | |
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Operating income (loss) | |
| ( | |
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| ( | |
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Other income (expense): | |
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Interest expense, net | |
| ( | | | ( | |
| ( | |
| ( |
Other income (expense) | | | | | | ( | | | ( | | | ( |
Total other income (expense) | |
| ( | |
| ( | |
| ( | |
| ( |
Income (loss) before income taxes | |
| ( | |
| | |
| ( | |
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Income tax (expense) benefit - current | |
| | | | ( | |
| ( | |
| ( |
Income tax (expense) benefit - deferred | |
| | | | ( | |
| | |
| ( |
Net income (loss) | | $ | ( | | $ | | | $ | ( | | $ | |
| | | | | | | | | | | | |
Allocation of net income (loss) to: | | | | | | | | | | | | |
Net income (loss) available to common stockholders | | $ | ( | | $ | | | $ | ( | | $ | |
Net income (loss) allocated to participating securities | |
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Net income (loss) available to Amplify Energy Corp. | | $ | ( | | $ | | | $ | ( | | $ | |
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Earnings (loss) per share: (See Note 10) | |
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Basic and diluted earnings (loss) per share | | $ | ( | | $ | | | $ | ( | | $ | |
Weighted average common shares outstanding: | |
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Basic and diluted | |
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See Accompanying Notes to Unaudited Condensed Consolidated Financial Statements.
9
AMPLIFY ENERGY CORP.
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
|
| For the Nine Months Ended | ||||
|
| September 30, | ||||
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| 2025 |
| 2024 | ||
Cash flows from operating activities: |
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Net income (loss) | | $ | ( | | $ | |
Adjustments to reconcile net income (loss) to net cash provided by operating activities: | |
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Depreciation, depletion and amortization | |
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Impairment expense | |
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Loss (gain) on derivative instruments | |
| ( | |
| ( |
Cash settlements (paid) received on expired derivative instruments | |
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Cash settlements received (paid) on terminated derivative instruments | | | | | | |
Deferred income tax expense (benefit) | | | ( | | | |
Accretion of asset retirement obligations | |
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(Gain) loss on sale of properties | | | ( | | | |
Share-based compensation (see Note 11) | |
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Settlement of asset retirement obligations | |
| ( | |
| ( |
Amortization and write-off of deferred financing costs | |
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Bad debt expense | |
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Changes in operating assets and liabilities: | |
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Accounts receivable | |
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Prepaid expenses and other assets | |
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| ( |
Payables and accrued liabilities | |
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| ( |
Other | |
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Net cash provided by operating activities | |
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Cash flows from investing activities: | |
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Additions to oil and gas properties | |
| ( | |
| ( |
Additions to other property and equipment | |
| ( | |
| ( |
Additions to restricted investments | |
| ( | |
| ( |
Proceeds from the sale of oil and natural gas properties | | | | | | |
Net cash used in investing activities | |
| ( | |
| ( |
Cash flows from financing activities: | |
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Advances on Revolving Credit Facility | |
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Payments on Revolving Credit Facility | |
| ( | |
| ( |
Deferred financing costs | |
| ( | |
| ( |
Shares withheld for taxes | |
| ( | |
| ( |
Net cash used in financing activities | |
| ( | |
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Net change in cash and cash equivalents | |
| | |
| ( |
Cash and cash equivalents, beginning of period | |
| | |
| |
Cash and cash equivalents, end of period | | $ | | | $ | |
See Accompanying Notes to Unaudited Condensed Consolidated Financial Statements.
10
AMPLIFY ENERGY CORP.
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (DEFICIT)
(In thousands)
| | Stockholders' Equity | ||||||||||
| | | | | Additional | | Accumulated | | | | ||
| | Common | | Paid-in | | Earnings | | | | |||
|
| Stock |
| Capital |
| (Deficit) |
| Total | ||||
Balance at December 31, 2024 |
| $ | | | $ | | | $ | ( | | $ | |
Net income (loss) | |
| | |
| |
| ( | |
| ( | |
Share-based compensation expense | |
| | |
| | |
| |
| | |
Shares withheld for taxes | |
| | |
| ( | |
| |
| ( | |
Other | |
| | |
| ( | |
| |
| | |
Balance at March 31, 2025 | | | | | | | | | ( | | | |
Net income (loss) | | | | | | | | | | | | |
Share-based compensation expense | | | | | | | | | | | | |
Shares withheld for taxes | | | | | | ( | | | | | | ( |
Other | | | | | | | | | | | | |
Balance at June 30, 2025 | | | | | | | | | ( | | | |
Net income (loss) | |
| | |
| | |
| ( | |
| ( |
Share-based compensation expense | |
| | |
| | |
| | |
| |
Shares withheld for taxes | |
| | |
| ( | |
| | |
| ( |
Other | | | | | | ( | | | | | | |
Balance at September 30, 2025 |
| $ | |
| $ | |
| $ | ( |
| $ | |
| | Stockholders' Equity (Deficit) | ||||||||||
| | | | | Additional | | Accumulated | | | |||
| | Common | | Paid-in | | Earnings | | | | |||
|
| Stock |
| Capital |
| (Deficit) |
| Total | ||||
Balance at December 31, 2023 |
| $ | |
| $ | |
| $ | ( |
| $ | |
Net income (loss) | |
| |
| |
| ( | |
| ( | ||
Share-based compensation expense | |
| |
| | |
| |
| | ||
Shares withheld for taxes | |
| |
| ( | |
| |
| ( | ||
Other | |
| | |
| ( | |
| | |
| |
Balance at March 31, 2024 | | | | | | | | | ( | | | |
Net income (loss) | | | |
| |
| | |
| | ||
Share-based compensation expense | | | |
| | |
| | |
| | |
Shares withheld for taxes | | | |
| ( | |
| |
| ( | ||
Balance at June 30, 2024 | | | | | | | | | ( | | | |
Net income (loss) | |
| |
| |
| | |
| | ||
Share-based compensation expense | |
| |
| | |
| |
| | ||
Shares withheld for taxes | | | | | ( | | | | | ( | ||
Other | | | | | | ( | | | | | | |
Balance at September 30, 2024 |
| $ | |
| $ | |
| $ | ( |
| $ | |
See Accompanying Notes to Unaudited Condensed Consolidated Financial Statements.
11
Note 1. Organization and Basis of Presentation
General
Amplify Energy Corp. (“Amplify Energy,” “Amplify,” “it” or the “Company”) is a publicly traded Delaware corporation whose common stock, par value $
The Company operates in
Basis of Presentation
The Company’s accompanying Unaudited Condensed Consolidated Financial Statements include the accounts of the Company and its wholly owned subsidiaries which have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). In the Company’s opinion, the accompanying Unaudited Condensed Consolidated Financial Statements include all adjustments of a normal recurring nature necessary for fair presentation. Material intercompany transactions and balances have been eliminated.
The results reported in these Unaudited Condensed Consolidated Financial Statements are not necessarily indicative of results that may be expected for the entire year. Furthermore, certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to the rules and regulations of the SEC. Accordingly, the accompanying Unaudited Condensed Consolidated Financial Statements and Notes should be read in conjunction with the Company’s annual financial statements included in its 2024 Form 10-K.
Use of Estimates
The preparation of the accompanying Unaudited Condensed Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Significant estimates include, but are not limited to, oil and natural gas reserves, fair value estimates, revenue recognition, and contingencies and insurance accounting.
Segments
Operating segments are defined as components of an enterprise that engage in activities from which it may earn revenues and incur expenses for which separate operational financial information is available and is regularly evaluated by the chief operating decision maker (“CODM”). The Company’s Chief Executive Officer has been determined to be the Company’s CODM and as such, he allocates resources and assesses performance based upon consolidated financial information. See additional information in Note 15.
Note 2. Summary of Significant Accounting Policies
There have been no changes to the Company’s significant accounting policies as described in the Company’s annual financial statements included in its 2024 Form 10-K.
12
New Accounting Pronouncements
Improvements to Income Tax Disclosure. In December 2023, the Federal Accounting Standards Board (the “FASB”) issued an accounting standard update which requires that companies disclose the nature and magnitude of factors contributing to the difference between their effective tax rate and the statutory tax rate. The update will require companies to disclose specific categories in the rate reconciliation and provide additional information about items that meet a certain quantitative threshold. The guidance is effective for annual periods beginning after December 15, 2024. The Company plans to adopt the guidance during fiscal year 2025, with the first disclosure to be reflected in the Company’s Annual Report on Form 10-K for the year ended December 31, 2025. The Company is currently evaluating the impact of this guidance on the Company’s financial disclosures. Adoption of the update will not impact the Company’s financial position, results of operations or liquidity.
Income Statement –Expense Disaggregation Disclosures. In November 2024, the FASB issued an accounting standard update which requires disaggregated disclosures of income statement expenses for public business entities. The guidance will require companies to disclose disaggregated information about specific natural expense categories underlying certain income statement expense line items that are considered relevant because they include one or more of the five natural expense categories, as applicable: (1) purchase of inventory, (2) employee compensation, (3) depreciation, (4) intangible asset amortization and (5) depreciation, depletion and amortization (“DD&A”) recognized as part of oil and gas producing activities or other depletion expenses. The new guidance is effective for annual periods beginning after December 15, 2026 and interim periods within fiscal years beginning after December 31, 2027. The Company is currently evaluating the impact of this guidance on the Company’s financial disclosures. Adoption of the update will not impact the Company’s financial position, results of operations or liquidity.
Other accounting standards that have been issued by the FASB or other standards-setting bodies are not expected to have a material impact on the Company’s financial position, results of operations or cash flows.
Note 3. Revenue
Revenue from Contracts with Customers
Revenue is recognized when the following five steps are completed: (1) identify the contract with the customer, (2) identify the performance obligation (promise) in the contract, (3) determine the transaction price, (4) allocate the transaction price to the performance obligations in the contract and (5) recognize revenue when the reporting organization satisfies a performance obligation.
The Company has determined that its contracts for the sale of crude oil, unprocessed natural gas, residue gas and NGLs contain monthly performance obligations to deliver product at locations specified in the contract. Control is transferred at the delivery location, at which point the performance obligation has been satisfied and revenue is recognized. Fees included in the contract that are incurred prior to control transfer are classified as gathering, processing and transportation and fees incurred after control transfers are included as a reduction to the transaction price. The transaction price at which revenue is recognized consists entirely of variable consideration based on quoted market prices less various fees and the quantity of volumes delivered.
13
Disaggregation of Revenue
The Company has identified
|
| For the Three Months Ended | | For the Nine Months Ended | ||||||||
|
| September 30, | | September 30, | ||||||||
|
| 2025 |
| 2024 |
| 2025 |
| 2024 | ||||
|
| (In thousands) | ||||||||||
Revenues |
| |
|
| |
| | |
|
| |
|
Oil | | $ | | | $ | | | $ | | | $ | |
NGLs | | | | | | | | | | | | |
Natural gas | | | | | | | | | | | | |
Oil and natural gas sales | | $ | | | $ | | | $ | | | $ | |
Contract Balances
Under the Company’s sales contracts, the Company invoices customers once its performance obligations have been satisfied, at which point payment is unconditional. Accordingly, the Company’s contracts do not give rise to contract assets or liabilities. Accounts receivable attributable to the Company’s revenue contracts with customers were $
Note 4. Acquisitions and Divestitures
Sale of Non-Operated Eagle Ford Assets
On July 1, 2025, OLLC entered into a definitive agreement (the “Purchase and Sale Agreement”) with Murphy Exploration & Production Company – USA, a Delaware corporation (“Buyer”), the existing operator of the majority of OLLC’s Assets (as defined in the Purchase and Sale Agreement), pursuant to which OLLC sold to Buyer all of OLLC’s Assets, which include, among other things, OLLC’s right, title and interest in and to certain specified oil and gas Properties, Contracts, Equipment and Production (each, as defined in the Purchase and Sale Agreement) within or related to certain designated lands in Karnes County, Texas, for an aggregate cash purchase price of $
East Texas Haynesville Monetization
On January 15, 2025, the Company sold
On May 1, 2025, the Company sold
14
Contemplated Merger with Juniper Capital
On January 14, 2025, the Company entered into an Agreement and Plan of Merger, as subsequently amended (the “Merger Agreement”) with Amplify DJ Operating LLC, a Delaware limited liability company and indirect wholly owned subsidiary of the Company (“First Merger Sub”), Amplify PRB Operating LLC, a Delaware limited liability company and indirect wholly owned subsidiary of Amplify (“Second Merger Sub”), North Peak Oil & Gas, LLC, a Delaware limited liability company (“NPOG”), Century Oil and Gas Sub-Holdings, LLC, a Delaware limited liability company (“COG” and, together with NPOG, the “Acquired Companies”), and, solely for the limited purposes set forth in the Merger Agreement, Juniper Capital Advisors, L.P. (“Juniper Capital”) and the Specified Company Entities set forth on Annex A thereto, pursuant to which, at the effective time of the Contemplated Mergers (as defined below) (the “Effective Time”), it was contemplated that (i) NPOG would merge with and into First Merger Sub, with NPOG surviving the merger as an indirect, wholly owned subsidiary of the Company and (ii) COG would merge with and into Second Merger Sub, with COG surviving the merger as an indirect, wholly owned subsidiary of the Company, in each case, subject to the terms and conditions of the Merger Agreement (clauses (i) and (ii), together, the “Contemplated Mergers”).
On April 25, 2025, pursuant to Section 8.1(a) of the Merger Agreement, the Company and the Acquired Companies entered into a mutual termination agreement (the “Termination Agreement”) to terminate the Merger Agreement (the “Termination”), effective immediately. As a result of the Termination Agreement, the Merger Agreement is of no further force and effect.
Acquisition and Divesture Expenses
Acquisition and divestiture related expenses for third-party transactions are included in general and administrative expense in the accompanying Unaudited Condensed Statement of Consolidated Operations for the periods indicated below (in thousands):
For the Three Months Ended | | For the Nine Months Ended | ||||||||
September 30, | | September 30, | ||||||||
2025 | | 2024 | | 2025 | | 2024 | ||||
$ | | | $ | | | $ | | | $ | |
Note 5. Fair Value Measurements of Financial Instruments
Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at a specified measurement date. Fair value estimates are based on either (i) actual market data or (ii) assumptions that other market participants would use in pricing an asset or liability, including estimates of risk. A three-tier hierarchy has been established that classifies fair value amounts recognized or disclosed in the financial statements. The hierarchy considers fair value amounts based on observable inputs (Levels 1 and 2) to be more reliable and predictable than those based primarily on unobservable inputs (Level 3). All the derivative instruments reflected on the accompanying Unaudited Condensed Consolidated Balance Sheets were considered Level 2.
The carrying values of accounts receivables, accounts payables (including accrued liabilities), restricted investments and amounts outstanding under long-term debt agreements with variable rates included in the accompanying Unaudited Condensed Consolidated Balance Sheets approximated fair value at September 30, 2025 and December 31, 2024. The fair value estimates are based upon observable market data and are classified within Level 2 of the fair value hierarchy. These assets and liabilities are not presented in the following tables.
15
Assets and Liabilities Measured at Fair Value on a Recurring Basis
The fair market values of the derivative financial instruments reflected on the accompanying Unaudited Condensed Consolidated Balance Sheets as of September 30, 2025 and December 31, 2024 were based on estimated forward commodity prices. Financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement in its entirety. The significance of a particular input to the fair value measurement requires judgment and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels.
The following tables present the gross derivative assets and liabilities that are measured at fair value on a recurring basis at September 30, 2025 and December 31, 2024 for each of the fair value hierarchy levels:
|
| Fair Value Measurements at September 30, 2025 | ||||||||||
| | | | | | Significant | | | | |||
| | Quoted Prices in | | Significant Other | | Unobservable | | | | |||
| | Active Market | | Observable Inputs | | Inputs | | | | |||
|
| (Level 1) |
| (Level 2) |
| (Level 3) |
| Fair Value | ||||
| | (In thousands) | ||||||||||
Assets: |
| |
|
| |
|
| |
|
| |
|
Commodity derivatives | | $ | | | $ | | | $ | | | $ | |
Interest rate derivatives | |
| | |
| | |
| | |
| |
Total assets | | $ | | | $ | | | $ | | | $ | |
| | | | | | | | | | | | |
Liabilities: | |
|
| |
|
| |
|
| |
|
|
Commodity derivatives | | $ | | | $ | | | $ | | | $ | |
Interest rate derivatives | |
| | |
| | |
| | |
| |
Total liabilities | | $ | | | $ | | | $ | | | $ | |
|
| Fair Value Measurements at December 31, 2024 | ||||||||||
| | | | | | Significant | | | | |||
| | Quoted Prices in | | Significant Other | | Unobservable | | | | |||
| | Active Market | | Observable Inputs | | Inputs | | | | |||
|
| (Level 1) |
| (Level 2) |
| (Level 3) |
| Fair Value | ||||
| | (In thousands) | ||||||||||
Assets: | |
| | |
| | |
| | |
| |
Commodity derivatives | | $ | | | $ | | | $ | | | $ | |
Interest rate derivatives | |
| | |
| | |
| | |
| |
Total assets | | $ | | | $ | | | $ | | | $ | |
| | | | | | | | | | | | |
Liabilities: | |
|
| |
|
| |
|
| |
|
|
Commodity derivatives | | $ | | | $ | | | $ | | | $ | |
Interest rate derivatives | |
| | |
| | |
| | |
| |
Total liabilities | | $ | | | $ | | | $ | | | $ | |
See Note 6 for additional information regarding the Company’s derivative instruments.
16
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Certain assets and liabilities are reported at fair value on a nonrecurring basis, as reflected on the accompanying Unaudited Condensed Consolidated Balance Sheets. The following methods and assumptions are used to estimate the fair values:
| ● | The fair value of asset retirement obligations (“AROs”) is based on discounted cash flow projections using numerous estimates, assumptions and judgments regarding factors such as the existence of a legal obligation for an ARO, amounts and timing of settlements, the credit-adjusted risk-free rate and inflation rates. The initial fair value estimates are based on unobservable market data and are classified within Level 3 of the fair value hierarchy. See Note 7 for a summary of changes in AROs. |
| ● | Proved oil and natural gas properties are reviewed for impairment when events and circumstances indicate a possible decline in the recoverability of the carrying value of such properties. The Company uses an income approach based on the discounted cash flow method, whereby the present value of expected future net cash flows is discounted by applying an appropriate discount rate, for purposes of placing a fair value on the assets. The future cash flows are based on management’s estimates for the future. The unobservable inputs used to determine fair value include, but are not limited to, estimates of proved reserves, estimates of probable reserves, future commodity prices, the timing of future production and capital expenditures and a discount rate commensurate with the risk reflective of the lives remaining for the respective oil and natural gas properties (some of which are Level 3 inputs within the fair value hierarchy). |
| o | The Company recorded an impairment expense of $ |
| o |
Note 6. Risk Management and Derivative Instruments
Derivative instruments are utilized to manage exposure to commodity price and interest rate fluctuations and to achieve a more predictable cash flow in connection with natural gas and oil sales and borrowing related activities. These instruments limit exposure to declines in prices but also limit the benefits that would be realized if prices increase.
Certain inherent business risks are associated with commodity derivative contracts, including market risk and credit risk. Market risk is the risk that the price of natural gas or oil will change, either favorably or unfavorably, in response to changing market conditions. Credit risk is the risk of loss from nonperformance by the counterparty to a contract. It is the Company’s policy to enter into derivative contracts only with creditworthy counterparties, which are generally financial institutions, deemed by management as competent and competitive market makers. Some of the lenders, or certain of their affiliates, under the Company’s current credit agreements are counterparties to its derivative contracts. While collateral is generally not required to be posted by counterparties, credit risk associated with derivative instruments is minimized by limiting exposure to any single counterparty and entering into derivative instruments only with creditworthy counterparties that are generally large financial institutions. Additionally, master netting agreements are used to mitigate risk of loss due to default with counterparties on derivative instruments. The Company has also entered into International Swaps and Derivatives Association Master Agreements (“ISDA Agreements”) with each of its counterparties. The terms of the ISDA Agreements provide the Company and each of its counterparties with rights of set-off upon the occurrence of defined acts of default by either the Company or its counterparty to a derivative, whereby the party not in default may set-off all liabilities owed to the defaulting party against all net derivative asset receivables from the defaulting party. As a result, had certain counterparties failed completely to perform according to the terms of the existing contracts, the Company would have the right to offset $
17
Commodity Derivatives
The Company may use a combination of commodity derivatives (e.g., floating-for-fixed swaps, put options and costless collars) to manage exposure to commodity price volatility. The Company recognizes all derivative instruments at fair value.
The Company enters into natural gas derivative contracts that are indexed to NYMEX-Henry Hub. The Company also enters into oil derivative contracts indexed to NYMEX-WTI.
At September 30, 2025, the Company had the following open commodity positions:
| | Remaining | | | | | | | | | ||
| | 2025 | | 2026 | | 2027 |
| 2028 | ||||
Natural Gas Derivative Contracts: | | |
| | | | | | |
| |
|
Fixed price swap contracts: | | |
| | | | | | |
| |
|
Average monthly volume (MMBtu) | | | | | | | | | |
| | |
Weighted-average fixed price | | $ | | | $ | | | $ | | | $ | |
| | | | | | | | | | | | |
Collar contracts: | |
| | |
| | |
| | |
| |
Two-way collars | |
| | |
| | |
| | |
| |
Average monthly volume (MMBtu) | |
| | |
| | |
| | |
| |
Weighted-average floor price | | $ | | | $ | | | $ | | | $ | |
Weighted-average ceiling price | | $ | | | $ | | | $ | | | $ | |
| | | | | | | | | | | | |
Crude Oil Derivative Contracts: | |
| | |
| | |
| | |
| |
Fixed price swap contracts: | |
| | |
| | |
| | |
| |
Average monthly volume (Bbls) | |
| | |
| | |
| | |
| — |
Weighted-average fixed price | | $ | | | $ | | | $ | | | $ | — |
Balance Sheet Presentation
The following table summarizes both: (i) the gross fair value of derivative instruments by the appropriate balance sheet classification even when the derivative instruments are subject to netting arrangements and qualify for net presentation in the balance sheet and (ii) the net recorded fair value as reflected on the balance sheet at September 30, 2025 and December 31, 2024. There was
|
| |
| Asset |
| Liability |
| Asset |
| Liability | ||||
| | | | Derivatives | | Derivatives | | Derivatives | | Derivatives | ||||
| | | | September 30, | | September 30, | | December 31, | | December 31, | ||||
Type |
| Balance Sheet Location |
| 2025 |
| 2025 |
| 2024 |
| 2024 | ||||
| | | | (In thousands) | ||||||||||
Commodity contracts |
| Short-term derivative instruments | | $ | | | $ | | | $ | | | $ | |
Interest rate swaps |
| Short-term derivative instruments | |
| | |
| | |
| | |
| |
Gross fair value |
| | |
| | |
| | |
| | |
| |
Netting arrangements |
| | |
| ( | |
| ( | |
| ( | |
| ( |
Net recorded fair value |
| Short-term derivative instruments | | $ | | | $ | | | $ | | | $ | |
| | | | | | | | | | | | | | |
Commodity contracts |
| Long-term derivative instruments | | $ | | | $ | | | $ | | | $ | |
Interest rate swaps |
| Long-term derivative instruments | |
| | |
| | |
| | |
| |
Gross fair value |
| | |
| | |
| | |
| | |
| |
Netting arrangements |
| | |
| ( | |
| ( | |
| ( | |
| ( |
Net recorded fair value |
| Long-term derivative instruments | | $ | | | $ | | | $ | | | $ | |
18
Loss (Gain) on Derivative Instruments
The Company does not designate derivative instruments as hedging instruments for accounting and financial reporting purposes. Accordingly, all gains and losses, including changes in the derivative instruments’ fair values, have been recorded in the accompanying Unaudited Condensed Consolidated Statements of Operations.
|
| |
| For the Three Months Ended | | For the Nine Months Ended | ||||||||
| | Statements of |
| September 30, |
| September 30, | ||||||||
|
| Operations Location | | 2025 |
| 2024 | | 2025 |
| 2024 | ||||
Commodity derivative contracts |
| Loss (gain) on commodity derivatives | | $ | ( | | $ | ( | | $ | ( | | $ | ( |
Note 7. Asset Retirement Obligations
The Company’s asset retirement obligations primarily relate to the Company’s portion of future plugging and abandonment costs for wells and related facilities.
Asset retirement obligations at beginning of period | | $ | |
Liabilities added from acquisition or drilling | |
| |
Liabilities settled | |
| ( |
Liabilities removed upon sale of wells | |
| ( |
Accretion expense | |
| |
Revision of estimates | |
| |
Asset retirement obligation at end of period | |
| |
Less: Current portion | |
| |
Asset retirement obligations - long-term portion | | $ | |
Note 8. Long-Term Debt
The following table presents the Company’s consolidated debt obligations at the dates indicated:
|
| September 30, | | December 31, | ||
| | 2025 | | 2024 | ||
| | (In thousands) | ||||
Revolving Credit Facility (1) | | $ | | | $ | |
Total long-term debt | | $ | | | $ | |
| (1) | The carrying amount of the Company’s Revolving Credit Facility approximates fair value because the interest rates are variable and reflective of market rates. |
Amended and Restated Credit Agreement
On July 31, 2023, OLLC and Amplify Acquisitionco LLC (“Acquisitionco”), as the direct parent of OLLC and wholly owned subsidiary of the Company, entered into the Amended and Restated Credit Agreement, providing for a senior secured reserve-based revolving credit facility. The Revolving Credit Facility is guaranteed by the Company and all of its material subsidiaries and secured by substantially all of its assets. The Revolving Credit Facility matures on July 31, 2027. KeyBank National Association is the administrative agent.
The aggregate principal amount of loans outstanding under the Revolving Credit Facility as of September 30, 2025, was $
19
Certain key terms and conditions under the Revolving Credit Facility include (but are not limited to):
| ● | A maturity date of July 31, 2027; |
| ● | The loans shall bear interest at a rate per annum equal to (i) adjusted SOFR or (ii) an adjusted base rate, plus an applicable margin based on a utilization ratio of the lesser of the borrowing base and the aggregate commitments. The applicable margin ranges from |
| ● | The unused commitments under the Revolving Credit Facility will accrue a commitment fee of |
| ● | Certain financial covenants, including the maintenance of (i) a net debt leverage ratio not to exceed |
| ● | Certain events of default, including, without limitation: non-payment; breaches of representations and warranties; non-compliance with covenants or other agreements; cross-default to material indebtedness; judgments; change of control; and voluntary and involuntary bankruptcy; and |
| ● | Initial minimum hedging requirements covering |
On May 29, 2025, the Company completed the spring redetermination which affirmed the borrowing base at $
On July 2, 2025, subsequent to the Asset Sale, the Company’s borrowing base was reduced to $
As of September 30, 2025, the Company was in compliance with all the financial covenants (current ratio and total leverage ratio) and nonfinancial covenants associated with the Revolving Credit Facility.
Weighted-Average Interest Rates
The following table presents the weighted-average interest rates paid, excluding commitment fees, on the Company’s consolidated variable-rate debt obligations for the periods presented:
| | For the Three Months Ended | | For the Nine Months Ended | | ||||
| | September 30, | | September 30, | | ||||
| | 2025 | | 2024 | | 2025 | | 2024 | |
Revolving Credit Facility | | | % | | % | | % | | % |
Letters of Credit
At September 30, 2025, the Company had
Unamortized Deferred Financing Costs
Unamortized deferred financing costs associated with the Company’s Revolving Credit Facility were $
20
Note 9. Equity
Common Stock
The Company’s authorized capital stock includes
|
| Common Stock |
Balance, December 31, 2024 |
| |
Issuance of Common Stock |
| — |
Restricted stock units vested |
| |
Shares withheld for taxes (1) | | ( |
Balance, September 30, 2025 |
| |
| (1) |
Note 10. Earnings (Loss) per Share
The following sets forth the calculation of earnings (loss) per share, or EPS, for the periods indicated (in thousands, except per share amounts):
|
| For the Three Months Ended | | For the Nine Months Ended | ||||||||
| | September 30, | | September 30, | ||||||||
| | 2025 | | 2024 | | 2025 | | 2024 | ||||
Net income (loss) | | $ | ( | | $ | | | $ | ( | | $ | |
Less: Net income allocated to participating securities | |
| | |
| | |
| | |
| |
Basic and diluted earnings available to common stockholders | | $ | ( | | $ | | | $ | ( | | $ | |
| | | | | | | | | | | | |
Common shares: | |
|
| |
|
| |
|
| |
|
|
Common shares outstanding — basic | |
| | |
| | |
| | |
| |
Dilutive effect of potential common shares | |
| | |
| | |
| | |
| |
Common shares outstanding — diluted | |
| | |
| | |
| | |
| |
| | | | | | | | | | | | |
Net earnings (loss) per share: | |
|
| |
|
| |
|
| |
|
|
Basic | | $ | ( | | $ | | | $ | ( | | $ | |
Diluted | | $ | ( | | $ | | | $ | ( | | $ | |
Note 11. Long-Term Incentive Plans
On May 15, 2024, the Company’s shareholders approved the Amplify Energy Corp. 2024 Equity Incentive Plan (the “2024 EIP”), which had previously been approved by the board of directors of the Company. No further awards will be granted under the prior Legacy Equity Incentive Plan (“EIP,” and together with the 2024 EIP, the “EIP Plans”).
The 2024 EIP provides for awards that can be granted in the form of nonqualified stock options, incentive stock options, restricted stock awards, restricted stock units, stock appreciation rights, performance awards, stock awards and other incentive awards. To the extent that an award, other than stock options or stock appreciation rights, under the 2024 EIP has expired or been forfeited or canceled for any reason without having been exercised in full, the unexercised award would then be available again for future grants under the 2024 EIP. The 2024 EIP is administered by the board of directors of the Company.
21
Restricted Stock Units
Restricted Stock Units with Service Vesting Condition
Restricted stock units with service vesting conditions (“TSUs”) are accounted for as either equity-classified awards or liability-classified awards. The Company considered its intent and ability to settle awards in cash or shares of stock in determining whether to classify the awards as equity or liability awards. Compensation costs for equity-classified awards are recorded as general and administrative expense. The fair value of liability-classified awards is determined on a quarterly basis beginning at the grant date until final vesting. Changes in the fair value of liability-classified awards are recorded to general administrative expense and are remeasured at fair value each reporting period.
As of September 30, 2025, TSU grants are accounted for as equity-classified awards. The grant-date fair value is recognized as compensation cost on a straight-line basis over the requisite service period and forfeitures are accounted for as they occur. The unrecognized cost associated with the TSUs was $
The following table summarizes information regarding the TSUs activity for the period presented:
|
| |
| Weighted- | |
| | | | Average Grant- | |
| | Number of | | Date Fair Value | |
| | Units | | per Unit (1) | |
TSUs outstanding at December 31, 2024 |
| | | $ | |
Granted (2) |
| | | $ | |
Forfeited |
| ( | | $ | |
Vested |
| ( | | $ | |
TSUs outstanding at September 30, 2025 |
| | | $ | |
| (1) |
| (2) |
Restricted Stock Units with Market and Service Vesting Conditions
Restricted stock units with market and service vesting conditions (“PSUs”) are accounted for as either equity-classified or liability-classified awards. The grant-date fair value is recognized as compensation cost on a graded-vesting basis. The fair value of the awards is estimated on their grant dates using a simulation. The Company recognizes compensation cost over the requisite service or performance period. The Company accounts for forfeitures as they occur. Vesting of PSUs can range from
The 2023, 2024 and 2025 PSU awards are accounted for as equity-classified awards and were issued with a
22
In connection with Mr. Daniel Furbee’s appointment as Chief Executive Officer, he received a grant of
Compensation costs related to PSU awards are recorded as general and administrative expense. The unrecognized cost associated with PSU awards was $
The below table reflects the ranges for the assumptions used in the Monte Carlo model for the 2025 PSUs:
| | February 2025 | | July 2025 | |
Expected volatility | | % | % | ||
Dividend yield | | % | % | ||
Risk-free interest rate | | % | % |
The following table summarizes information regarding the PSU activity for the period presented:
|
| |
| Weighted- | |
| | | | Average Grant- | |
| | Number of | | Date Fair Value | |
| | Units | | per Unit (1) | |
PSUs outstanding at December 31, 2024 |
| | | $ | |
Granted (2) |
| | | $ | |
Forfeited |
| | | $ | |
Vested |
| ( | | $ | |
PSUs outstanding at September 30, 2025 |
| | | $ | |
| (1) | Determined by dividing the aggregate grant-date fair value of awards by the number of awards issued. |
| (2) |
Compensation Expense
The following table summarizes the amount of recognized compensation expense associated with the EIP Plans, which are reflected in the accompanying Unaudited Condensed Consolidated Statements of Operations for the periods presented (in thousands):
|
| For the Three Months Ended |
| For the Nine Months Ended | ||||||||
| | September 30, | | September 30, | ||||||||
| | 2025 | | 2024 | | 2025 | | 2024 | ||||
Share-based compensation costs | |
| | |
| | |
| | |
| |
TSUs | | $ | | | $ | | | $ | | | $ | |
PSUs | |
| | |
| | |
| | |
| |
| | $ | | | $ | | | $ | | | $ | |
23
Note 12. Leases
The Company has leases for office space, warehouse space and equipment in its corporate office and operating regions as well as vehicles, compressors and surface rentals related to its business operations. In addition, the Company has right-of-way leases to operate the San Pedro Bay Pipeline. Most of the Company’s leases, other than its corporate office lease, have an initial term and may be extended on a month-to-month basis after expiration of the initial term. Most of the Company’s
The Company’s corporate office lease does not provide an implicit rate. To determine the present value of the lease payments, the Company uses an incremental borrowing rate based on the information available at the inception date. To determine the incremental borrowing rate, the Company applies a portfolio approach based on the applicable lease terms and the current economic environment. The Company uses a reasonable market interest rate for its office equipment and vehicle leases.
For the nine months ended September 30, 2025 and 2024, the Company recognized approximately $
Supplemental cash flow information related to the Company’s lease liabilities is included in the table below:
| | For the Nine Months Ended | ||||
| | September 30, | ||||
| | 2025 | | 2024 | ||
| | (In thousands) | ||||
Non-cash amounts included in the measurement of lease liabilities: | |
| | |
| |
Operating cash flows from operating leases |
| $ | | | $ | |
The following table presents the Company’s right-of-use assets and lease liabilities for the period presented:
|
| September 30, | | December 31, | ||
| | 2025 | | 2024 | ||
| | (In thousands) | ||||
Right-of-use asset | | $ | | | $ | |
| | | | | | |
Lease liabilities: |
| |
|
| |
|
Current lease liability |
| | |
| | |
Long-term lease liability |
| | |
| | |
Total lease liability | | $ | | | $ | |
24
The following table reflects the Company’s maturity analysis of the minimum lease payment obligations under non-cancelable operating leases with a remaining term in excess of one year (in thousands):
| | | Office and | | Leased vehicles | | | | |
| | | warehouse | | and office | | | | |
|
| leases |
| equipment |
| Total | |||
2025 | | $ | | | $ | | | $ | |
2026 | | | | | | | | | |
2027 | | | | | | | | | |
2028 | | | | | | | | | |
2029 and thereafter |
| | |
| | |
| | |
Total lease payments |
| | |
| | |
| | |
Less: interest |
| | |
| | |
| | |
Present value of lease liabilities | | $ | | | $ | | | $ | |
The weighted average remaining lease terms and discount rate for all of the Company’s operating leases for the period presented:
|
| September 30, |
| ||
| | 2025 | | 2024 |
|
Weighted average remaining lease term (years): | |
| |
|
|
Office and warehouse space |
|
| | ||
Vehicles |
|
| | ||
Office equipment |
| — |
| — | |
Weighted average discount rate: |
| |
| | |
Office and warehouse space |
| | % | | % |
Vehicles |
| | % | | % |
Office equipment |
| — | % | | % |
25
Note 13. Supplemental Disclosures to the Unaudited Condensed Consolidated Balance Sheets and Unaudited Condensed Consolidated Statements of Cash Flows
Accrued Liabilities
Current accrued liabilities consisted of the following at the dates indicated (in thousands):
|
| September 30, | | December 31, | ||
| | 2025 | | 2024 | ||
Accrued lease operating expense | | $ | | | $ | |
Accrued capital expenditures | | | | | | |
Accrued general and administrative expense | |
| | |
| |
Accrued production and ad valorem tax | |
| | |
| |
Accrued commitment fee and other expense | |
| | |
| |
Operating lease liability | | | | | | |
Asset retirement obligations | |
| | |
| |
Accrued interest payable | | | | | | |
Accrued liability - pipeline incident | | | | | | |
Accrued current income tax payable | | | | | | |
Other | |
| | |
| |
Accrued liabilities | | $ | | | $ | |
Accounts Receivable
Accounts receivable consisted of the following at the dates indicated (in thousands):
|
| September 30, | | | December 31, | ||
| | 2025 | | | 2024 | ||
Oil and natural gas receivables | | $ | | | | $ | |
Insurance receivable - pipeline incident | | | | | | | |
Joint interest owners and other | | | | | | | |
Total accounts receivable | |
| | | |
| |
Less: allowance for doubtful accounts | |
| ( | | |
| ( |
Total accounts receivable, net | | $ | | | | $ | |
Supplemental Cash Flows
Supplemental cash flows for the periods presented (in thousands):
|
| For the Nine Months Ended | ||||
| | September 30, | ||||
| | 2025 | | 2024 | ||
Supplemental cash flows: | | |
| | |
|
Cash paid for interest, net of amounts capitalized | | $ | | | $ | |
Cash paid for taxes |
|
| |
| | |
| | | | | | |
Noncash investing and financing activities: |
|
| |
| | |
Increase (decrease) in capital expenditures in payables and accrued liabilities |
|
| ( |
| | ( |
26
Note 14. Related Party Transactions
Related Party Agreements
There have been
Note 15. Segment Reporting
The Company’s operations are all related to the exploration, development and production of oil and natural gas in the United States, from which the Company derives all of its revenues. The Company manages its business as a single reportable segment, as its operations are focused on assets with similar economic characteristics, production processes, types of purchasers, regulatory environment and customers which are consistent across the Company. Therefore, the Company aggregates its operating regions into
The CODM uses consolidated net income to assess financial performance, allocating capital and other resources. The CODM uses consolidated net income in the annual budgeting and monthly forecasting process. Additionally, the CODM is regularly provided information on lease operating expense, gathering, processing and transportation and taxes other than income. Other segment items primarily consist of DD&A, accretion expense, general and administrative expense, pipeline incident loss, loss (gain) on commodity derivative, interest expense and income tax expense (benefit). Our significant segment expenses and other segment items are derived from and can be found within the Unaudited Consolidated Statement of Operations.
| | For the Three Months Ended | | For the Nine Months Ended | ||||||||
| | September 30, | | September 30, | ||||||||
| | 2025 |
| 2024 | | 2025 |
| 2024 | ||||
| | (In thousands) | ||||||||||
Revenue | | $ | | | $ | | | $ | | | $ | |
Less: | | | | | | | | | | | | |
Lease operating expense | | | | | | | | | | | | |
Gathering, processing and transportation | | | | | | | | | | | | |
Taxes other than income | | | | | | | | | | | | |
Other segment items | | | | | | | | | | | | |
Net income (loss) | | $ | ( | | $ | | | $ | ( | | $ | |
Note 16. Commitments and Contingencies
Litigation and Environmental
As part of our normal business activities, we may be named as defendants in litigation and legal proceedings, including those arising from regulatory and environmental matters.
Although the Company is insured against various risks to the extent it believes it is prudent, there is no assurance that the nature and amount of such insurance will be adequate, in every case, to indemnify it against liabilities arising from future legal proceedings.
27
Environmental costs for remediation are accrued based on estimates of known remediation requirements. Such accruals are based on management’s best estimate of the ultimate cost to remediate a site and are adjusted as further information and circumstances develop. Those estimates may change substantially depending on information about the nature and extent of contamination, appropriate remediation technologies and regulatory approvals. Expenditures to mitigate or prevent future environmental contamination are capitalized. Ongoing environmental compliance costs are charged to expense as incurred. In accruing for environmental remediation liabilities, costs of future expenditures for environmental remediation are not discounted to their present value, unless the amount and timing of the expenditures are fixed or reliably determinable. At September 30, 2025 and December 31, 2024, the Company had
Termination of Contemplated Merger with Juniper Capital
In connection with the Contemplated Mergers, on April 25, 2025, pursuant to Section 8.1(a) of the Merger Agreement, the Company and the Acquired Companies entered into the Termination Agreement to terminate the Merger Agreement, effective immediately. As a result of the Termination Agreement, the Merger Agreement is of no further force and effect.
In accordance with the terms of the Termination Agreement, the Company made a cash payment to the Acquired Companies in lieu of any termination fee which might have otherwise been payable pursuant to the Merger Agreement in the amount of $
Beta Pipeline Incident
There have been no material changes to the legal proceedings, insurance receivables and costs associated with the incident that occurred at our producing oil property located at Beta (the “Incident”) as described in the Company’s annual financial statements included in its 2024 Form 10-K, except with respect to that disclosed below:
On September 30, 2025, and December 31, 2024, the Company’s insurance receivables were $
Sinking Fund Trust Agreement
Beta Operating Company, LLC (“Beta LLC”), a wholly owned subsidiary, assumed an obligation with a third party to make payments into a sinking fund in connection with the Company’s properties in federal waters offshore Southern California, the purpose of which is to provide funds adequate to decommission the portion of the San Pedro Bay Pipeline that lies within state waters and the surface facilities. Interest earned in the account stays in the account. The obligation to fund ceases when the aggregate value of the account reaches $
Supplemental Bond for Decommissioning Liabilities Trust Agreement
Beta LLC has a decommissioning obligation with BOEM in connection with the Company’s properties in federal waters offshore Southern California. The Company supports its decommissioning obligation with $
28
In December 2021, the Company entered into
The below table outlines the updated funding commitment for these agreements at September 30, 2025 (in thousands):
|
| Payment Due by Period | |||||||||||||||||||
Funding commitment | | Total |
| Remaining 2025 |
| 2026 |
| 2027 |
| 2028 |
| 2029 |
| Thereafter (1) | |||||||
Federal escrow fund payments | | $ | | | $ | | | $ | | | $ | | | $ | | | $ | | | $ | |
State escrow fund payments | | | | | | | | | | | | | | | | | | | | | |
Total sinking fund payments | | $ | | | $ | | | $ | | | $ | | | $ | | | $ | | | $ | |
| (1) | The remaining payments will be made during the years 2030 through 2042. |
As of September 30, 2025, the Company has funded $
Note 17. Income Taxes
The Company’s current income tax benefit (expense) was $
The Company’s deferred income tax benefit (expense) was $
The effective tax rates for the three and nine months ended September 30, 2025 were
On July 4, 2025, the President signed into law the One Big Beautiful Bill Act (“OBBBA”), which introduces significant changes to U.S. federal tax law. Key provisions of the legislation include modifications to the limitation on the deductibility of business interest expense, changes to the treatment of research and development expenditures, full expensing of qualified capital expenditures, and modifications to the international tax framework.
The Company is still evaluating the impact of the OBBBA on its consolidated financial statements. While the full effects are still being assessed, the Company anticipates a reduction in current income tax expense for the year with no material impact to the effective tax rate.
29
Note 18. Subsequent Events
East Texas Haynesville Monetization
On October 2, 2025, the Company entered into a purchase and sale agreement to sell its remaining interest in certain units with rights in the Cotton Valley and Haynesville basins in Harrison County, Texas, generating $
EQV Purchase and Sale Agreement
On October 28, 2025, OLLC and Magnify Energy Services LLC, a Delaware limited liability company and indirect, wholly owned subsidiary of the Company (“Magnify” and together with OLLC, the “EQV Sellers”), entered into a purchase and sale agreement (the “EQV Purchase and Sale Agreement”) with EQV Alpha LLC, a Delaware limited liability company (“Alpha”), pursuant to which the EQV Sellers sold to Alpha certain assets of the EQV Sellers, which include, among other things, the EQV Sellers’ right, title and interest in and to certain specified oil and gas Properties and Equipment (each as defined in the EQV Purchase and Sale Agreement) within or related to certain designated lands in East Texas and Louisiana (the “EQV Asset Sale”) for a cash purchase price of $
Revolution Purchase and Sale Agreement
On November 4, 2025, Amplify Oklahoma Operating LLC, a Delaware limited liability company and indirect, wholly owned subsidiary of the Company (“Amplify Oklahoma”), Magnify (together with Amplify Oklahoma, the “Revolution Sellers”) and OLLC, for certain limited purposes, entered into a purchase and sale agreement (the “Revolution Purchase and Sale Agreement”) with Revolution Resources III, LLC, a Delaware limited liability company (“Revolution”), pursuant to which the Revolution Sellers sold to Revolution certain assets of the Revolution Sellers, which include, among other things, the Revolution Sellers’ right, title and interest in and to certain specified oil and gas Properties and Equipment (each as defined in the Revolution Purchase and Sale Agreement) within or related to certain designated lands in Oklahoma (the “Revolution Asset Sale”) for a cash purchase price of $
30
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.
Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the Unaudited Condensed Consolidated Financial Statements and accompanying notes in “Item 1. Financial Statements” contained herein and in “Item 1A. Risk Factors” of our 2024 Form 10-K. The following discussion contains forward-looking statements that reflect our future plans, estimates, beliefs and expected performance. The forward-looking statements are dependent upon events, risks and uncertainties that may be outside our control. Our actual results could differ materially from those discussed in these forward-looking statements. See “Cautionary Note Regarding Forward-Looking Statements” in the front of this report.
Overview
We operate in one reportable segment engaged in the acquisition, development, exploitation and production of oil and natural gas properties. Our management evaluates performance based on the reportable business segment as the economic environments are not different within the operation of our oil and natural gas properties. Our business activities are conducted through OLLC, our wholly owned subsidiary, and its wholly owned subsidiaries. Our assets have historically consisted primarily of producing oil and natural gas properties located in Oklahoma, the Rockies (“Bairoil”), federal waters offshore Southern California (“Beta”), East Texas/North Louisiana and the Eagle Ford (non-op). Amplify’s current operations are focused at Oklahoma, Bairoil and Beta. Most of our oil and natural gas properties are located in large, mature oil and natural gas reservoirs.
Industry Trends
We continue to monitor the impact of the actions of OPEC+ and other large producing nations, the Russia-Ukraine conflict, conflicts in the Middle East, the imposition of tariffs or other economic sanctions, global inventories of oil and natural gas and the uncertainty associated with recovering oil demand, inflation and future monetary policy and governmental policies aimed at transitioning towards lower carbon energy. In 2025, there has been continued volatility in oil, natural gas and NGL prices resulting from (i) trade tariff uncertainties driving concerns over an increase in inflation and (ii) OPEC+’s decision to increase production in May through September 2025, creating additional global supply and further downward pressure on oil prices. In October 2025, OPEC+ announced an additional production increase for November, which is expected to exacerbate these supply-side pressures on oil prices.
While U.S. inflation rates during 2025 have remained relatively stable, they continued to be slightly higher than historical averages. Such inflation, along with the effects of economic pressures from international military and trade conflicts, could, as a result, continue to raise the cost of borrowing, impact the demand for and price of oil and natural gas, increase the price of crucial supplies and raw materials and impact interest rates. In both September and October, the Federal Reserve reduced interest rates, and may lower rates further, though it remains uncertain at this time. Due to these factors, among others, we expect prices for some or all commodities to remain volatile. Thus, we cannot predict with reasonable certainty the extent to which these factors may impact our business, results of operations, financial condition and cash flows.
Recent Developments
East Texas Haynesville Monetization
On October 2, 2025, the Company entered into a purchase and sale agreement to sell its remaining interest in certain units with rights in the Cotton Valley and Haynesville basins in Harrison County, Texas, generating $5.5 million in net proceeds from the transactions. The sale closed on October 24, 2025 and has an effective date of October 1, 2025.
31
EQV Purchase and Sale Agreement
On October 28, 2025, OLLC and Magnify Energy Services LLC, a Delaware limited liability company and indirect, wholly owned subsidiary of the Company (“Magnify” and together with OLLC, the “EQV Sellers”), entered into a purchase and sale agreement (the “EQV Purchase and Sale Agreement”) with EQV Alpha LLC, a Delaware limited liability company (“Alpha”), pursuant to which the EQV Sellers sold to Alpha certain assets of the EQV Sellers, which include, among other things, the EQV Sellers’ right, title and interest in and to certain specified oil and gas Properties and Equipment (each as defined in the EQV Purchase and Sale Agreement) within or related to certain designated lands in East Texas and Louisiana (the “EQV Asset Sale”) for a cash purchase price of $122.0 million, which remains subject to customary adjustments under the EQV Purchase and Sale Agreement. The EQV Asset Sale contemplated by the EQV Purchase and Sale Agreement is expected to close in December 2025 with an effective date of October 1, 2025.
Revolution Purchase and Sale Agreement
On November 4, 2025, Amplify Oklahoma Operating LLC, a Delaware limited liability company and indirect, wholly owned subsidiary of the Company (“Amplify Oklahoma”), Magnify (together with Amplify Oklahoma, the “Revolution Sellers”) and OLLC, for certain limited purposes, entered into a purchase and sale agreement (the “Revolution Purchase and Sale Agreement”) with Revolution Resources III, LLC, a Delaware limited liability company (“Revolution”), pursuant to which the Revolution Sellers sold to Revolution certain assets of the Revolution Sellers, which include, among other things, the Revolution Sellers’ right, title and interest in and to certain specified oil and gas Properties and Equipment (each as defined in the Revolution Purchase and Sale Agreement) within or related to certain designated lands in Oklahoma (the “Revolution Asset Sale”) for a cash purchase price of $92.5 million, which remains subject to customary adjustments under the Revolution Purchase and Sale Agreement. The Revolution Asset Sale contemplated by the Revolution Purchase and Sale Agreement is expected to close in December 2025 with an effective date of October 1, 2025.
Business Environment and Operational Focus
We use a variety of financial and operational metrics to assess the performance of our oil and natural gas operations, including: (i) production volumes; (ii) realized prices on the sale of our production; (iii) cash settlements on our commodity derivatives; (iv) lease operating expense; (v) gathering, processing and transportation; (vi) general and administrative expense; and (vii) Adjusted EBITDA (as defined below).
Sources of Revenues
Our revenues are derived from the sale of natural gas and oil production, as well as the sale of NGLs that are extracted from natural gas during processing. Production revenues are derived entirely from the continental United States. Natural gas, NGL and oil prices are inherently volatile and are influenced by many factors outside our control. In order to reduce the impact of fluctuations in natural gas and oil prices on revenues, we intend to periodically enter into derivative contracts that fix the future prices received. At the end of each period, the fair value of these commodity derivative instruments is estimated and because hedge accounting is not elected, the changes in the fair value of unsettled commodity derivative instruments are recognized in earnings at the end of each accounting period.
Critical Accounting Policies and Estimates
Our critical accounting policies and estimates, including a discussion regarding the estimation uncertainty and the impact that our critical accounting estimates have had, or are reasonably likely to have, on our financial condition or results of operations, are described in “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our 2024 Form 10-K. Significant estimates include, but are not limited to, oil and natural gas reserves, fair value estimates, revenue recognition and contingencies and insurance accounting. These estimates, in our opinion, are subjective in nature, require the use of professional judgment and involve complex analysis.
When used in the preparation of our consolidated financial statements, such estimates are based on our current knowledge and understanding of the underlying facts and circumstances and may be revised as a result of actions we take in the future. Changes in these estimates will occur as a result of the passage of time and the occurrence of future events. Subsequent changes in these estimates may have a significant impact on our consolidated financial position, results of operations and cash flows.
32
Results of Operations
The results of operations for the three and nine months ended September 30, 2025 and 2024 have been derived from our unaudited condensed consolidated financial statements.
The following table summarizes certain of the results of operations for the periods indicated.
|
| For the Three Months Ended | | For the Nine Months Ended | ||||||||
|
| September 30, | | September 30, | ||||||||
|
| 2025 |
| 2024 | | 2025 |
| 2024 | ||||
|
| ($ In thousands except per unit amounts) | ||||||||||
Oil and natural gas sales | | $ | 64,242 | | $ | 68,135 | | $ | 201,357 | | $ | 215,803 |
Other revenues | | | 2,154 | | | 1,723 | | | 5,450 | | | 9,857 |
Lease operating expense | |
| 35,613 | |
| 33,255 | |
| 111,652 | |
| 107,850 |
Gathering, processing and transportation | |
| 5,237 | |
| 4,290 | |
| 14,246 | |
| 13,959 |
Taxes other than income | |
| 3,654 | |
| 5,997 | |
| 12,337 | |
| 15,539 |
Depreciation, depletion and amortization | |
| 9,004 | |
| 8,102 | |
| 27,263 | |
| 24,168 |
Impairment expense | |
| 34,002 | |
| — | |
| 42,450 | |
| — |
General and administrative expense | |
| 11,764 | |
| 8,251 | |
| 33,776 | |
| 26,409 |
Loss (gain) on commodity derivative instruments | |
| (6,922) | |
| (25,047) | |
| (14,767) | |
| (7,258) |
Pipeline incident loss | | | 54 | |
| 247 | |
| 645 | |
| 1,454 |
(Gain) loss on sale of properties | | | (1,740) | | | — | | | (9,536) | |
| — |
Interest expense, net | |
| 3,860 | |
| 3,756 | |
| 10,973 | |
| 10,915 |
Income tax (expense) benefit - current | | | 116 | | | (412) | | | (380) | |
| (2,364) |
Income tax (expense) benefit - deferred | |
| 9,228 | |
| (5,650) | |
| 9,346 | |
| (3,082) |
Net income (loss) | |
| (20,966) | |
| 22,652 | |
| (20,443) | |
| 20,375 |
| | | | | | | | | | | | |
Oil and natural gas revenues: | |
|
| |
|
| |
|
| |
|
|
Oil sales | | $ | 45,543 | | $ | 54,353 | | $ | 145,230 | | $ | 169,563 |
NGL sales | |
| 5,401 | |
| 6,096 | |
| 17,206 | |
| 20,187 |
Natural gas sales | |
| 13,298 | |
| 7,686 | |
| 38,921 | |
| 26,053 |
Total oil and natural gas revenues | | $ | 64,242 | | $ | 68,135 | | $ | 201,357 | | $ | 215,803 |
| | | | | | | | | | | | |
Production volumes: | |
|
| |
|
| |
|
| |
|
|
Oil (MBbls) | |
| 750 | |
| 758 | |
| 2,315 | |
| 2,300 |
NGLs (MBbls) | |
| 286 | |
| 301 | |
| 834 | |
| 979 |
Natural gas (MMcf) | |
| 4,648 | |
| 4,165 | |
| 12,055 | |
| 12,953 |
Total (MBoe) | |
| 1,811 | |
| 1,752 | |
| 5,158 | |
| 5,438 |
Average net production (MBoe/d) | |
| 19.7 | |
| 19.0 | |
| 18.9 | |
| 19.8 |
| | | | | | | | | | | | |
Average realized sales price (excluding commodity derivatives): | |
|
| |
|
| |
|
| |
|
|
Oil (per Bbl) | | $ | 60.72 | | $ | 71.74 | | $ | 62.73 | | $ | 73.73 |
NGL (per Bbl) | |
| 18.86 | |
| 20.29 | |
| 20.63 | |
| 20.62 |
Natural gas (per Mcf) | |
| 2.86 | |
| 1.85 | |
| 3.23 | |
| 2.01 |
Total (per Boe) | | $ | 35.47 | | $ | 38.88 | | $ | 39.03 | | $ | 39.69 |
| | | | | | | | | | | | |
Average unit costs per Boe: | |
|
| |
|
| |
|
| |
|
|
Lease operating expense | | $ | 19.67 | | $ | 18.98 | | $ | 21.65 | | $ | 19.83 |
Gathering, processing and transportation | |
| 2.89 | |
| 2.45 | |
| 2.76 | |
| 2.57 |
Taxes other than income | |
| 2.02 | |
| 3.42 | |
| 2.39 | |
| 2.86 |
General and administrative expense | |
| 6.50 | |
| 4.71 | |
| 6.55 | |
| 4.86 |
Depletion, depreciation and amortization | |
| 4.97 | |
| 4.62 | |
| 5.29 | |
| 4.44 |
33
For the Three Months Ended September 30, 2025 Compared to the Three Months Ended September 30, 2024
We reported a net loss of $21.0 million compared to net income of $22.7 million for the three months ended September 30, 2025 and 2024, respectively.
Oil, natural gas and NGL revenues were $64.2 million and $68.1 million for the three months ended September 30, 2025 and 2024, respectively. Average net production volumes were approximately 19.7 MBoe/d and 19.0 MBoe/d for the three months ended September 30, 2025 and 2024, respectively. The average realized sales prices were $35.47 per Boe and $38.88 per Boe for the three months ended September 30, 2025 and 2024, respectively. The change in realized sales price was due to lower realized sales prices for oil, partially offset by higher realized sales prices for natural gas.
Other revenues were $2.2 million and $1.7 million for the three months ended September 30, 2025 and 2024, respectively. The increase was primarily related to an increase of $0.3 million in rental income with respect to Magnify and interest income earned on our sinking fund escrow accounts.
Lease operating expenses were $35.6 million and $33.3 million for the three months ended September 30, 2025 and 2024, respectively. On a per Boe basis, lease operating expenses were $19.67 and $18.98 for the three months ended September 30, 2025 and 2024, respectively. The change in lease operating expense was primarily due to increased workover activity at Beta and Bairoil, partially offset by a decrease in costs associated with the divestiture of our non-operated Eagle Ford assets.
Gathering, processing and transportation expenses were $5.2 million and $4.3 million for the three months ended September 30, 2025 and 2024, respectively. On a per Boe basis, gathering, processing and transportation expenses were $2.89 and $2.45 for the three months ended September 30, 2025 and 2024, respectively. The change in gathering, processing and transportation expenses was primarily due to higher gas volumes during the quarter.
Taxes other than income were $3.7 million and $6.0 million for the three months ended September 30, 2025 and 2024, respectively. On a per Boe basis, taxes other than income were $2.02 and $3.42 for the three months ended September 30, 2025 and 2024, respectively. The reduction in taxes other than income was primarily related to a decrease in both emission charges and production taxes.
DD&A expenses were $9.0 million and $8.1 million for the three months ended September 30, 2025 and 2024, respectively. The change in DD&A expenses was primarily driven by increased production, partially offset by the divestiture of our non-operated Eagle Ford assets.
Impairment expense was $34.0 million for the three months ended September 30, 2025. The Company recognized an impairment charge due to the carrying value of the assets exceeding the fair market value of the assets. See Note 5 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report for additional information. No impairment expense was recorded for the three months ended September 30, 2024.
General and administrative expenses were $11.8 million and $8.3 million for the three months ended September 30, 2025 and 2024, respectively. The change in general and administrative expenses was primarily related to (i) an increase of $0.8 million in acquisition and divestiture costs incurred during the second quarter, (ii) an increase of $0.8 million in stock compensation expense and (iii) an increase in severance expense of $1.5 million.
Net loss (gain) on commodity derivative instruments of ($6.9) million was recognized for the three months ended September 30, 2025, consisting of a $2.1 million increase in the fair value of open positions and $4.8 million of cash settlements received on expired positions. Net gain on commodity derivative instruments of $25.0 million was recognized for the three months ended September 30, 2024, consisting of a $18.7 million increase in the fair value of open positions, $5.6 million of cash settlements received on expired positions and $0.8 million of cash settlements received on terminated derivative instruments.
Pipeline incident loss was less than $0.1 million and $0.2 million for the three months ended September 30, 2025 and 2024, respectively. The costs reflect certain expenses not expected to be recovered under an insurance policy. See Note 16 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report for additional information.
34
(Gain) loss on sale of properties was ($1.7) million for the three months ended September 30, 2025. See Note 4 of the Notes to Unaudited Condensed Consolidated Financial Statements under “Item 1. Financial Statements” of this quarterly report for additional information. There was no (gain) loss on sale of properties for the three months ended September 30, 2024.
Interest expense, net was $3.9 million for the three months ended September 30, 2025 and $3.8 million for the three months ended September 30, 2024.
Average outstanding borrowings under our Revolving Credit Facility were $124.9 million and $122.5 million for the three months ended September 30, 2025 and 2024, respectively.
Current income tax benefit (expense) was $0.1 million and ($0.4) million for the three months ended September 30, 2025 and 2024, respectively. See additional information discussed in Note 17 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report.
Deferred income tax benefit (expense) was $9.2 million and ($5.7) million for the three months ended September 30, 2025 and 2024, respectively. See additional information discussed in Note 17 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report.
For the Nine Months Ended September 30, 2025 Compared to the Nine Months Ended September 30, 2024
We reported a net loss of $20.4 million compared to a net income of $20.4 million for the nine months ended September 30, 2025 and 2024, respectively.
Oil, natural gas and NGL revenues were $201.4 million and $215.8 million for the nine months ended September 30, 2025 and 2024, respectively. Average net production volumes were approximately 18.9 MBoe/d and 19.8 MBoe/d for the nine months ended September 30, 2025 and 2024, respectively. The average realized sales prices were $39.03 per Boe and $39.69 per Boe for the nine months ended September 30, 2025 and 2024, respectively. The change in realized sales price was due to lower realized sales prices for oil, partially offset by higher realized sales prices for natural gas.
Other revenues were $5.5 million and $9.9 million for the nine months ended September 30, 2025 and 2024, respectively. The change was primarily related to the revenue suspense release of $4.8 million for the nine months ended September 30, 2024.
Lease operating expenses were $111.7 million and $107.9 million for the nine months ended September 30, 2025 and 2024, respectively. On a per Boe basis, lease operating expenses were $21.65 and $19.83 for the nine months ended September 30, 2025 and 2024, respectively. The change in lease operating expense was primarily due to increased workover activity at Beta and an increase in electricity cost at Bairoil, partially offset by the decrease in cost associated with the divestiture of our non-operated Eagle Ford assets.
Gathering, processing and transportation expenses were $14.2 million and $14.0 million for the nine months ended September 30, 2025 and 2024, respectively. On a per Boe basis, gathering, processing and transportation expenses were $2.76 and $2.57 for the nine months ended September 30, 2025 and 2024, respectively. The change in gathering, processing and transportation expense was primarily due to lower gas volumes.
Taxes other than income were $12.3 million and $15.5 million for the nine months ended September 30, 2025 and 2024, respectively. On a per Boe basis, taxes other than income were $2.39 and $2.86 for the nine months ended September 30, 2025 and 2024. The change in taxes other than income was primarily related to a reduction in production taxes due to lower volumes and a decrease in emission charges.
DD&A expenses were $27.3 million and $24.2 million for the nine months ended September 30, 2025 and 2024, respectively. The change was primarily due to an increase in our depletion rate of $4.4 million, partially offset by a decrease of $1.2 million due to lower volumes of production.
35
Impairment expense was $42.5 million for the nine months ended September 30, 2025. The Company recognized an impairment charge due to the carrying value of the assets exceeding the fair market value of the assets. See Note 5 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report for additional information. No impairment expense was recorded for the nine months ended September 30, 2024.
General and administrative expenses were $33.8 million and $26.4 million for the nine months ended September 30, 2025 and 2024, respectively. The change in general and administrative expenses was primarily related to (i) an increase of $4.7 million in acquisition and divestiture costs, (ii) an increase of $1.4 million in stock compensation expense and (iii) an increase in severance expense of $1.2 million.
Net loss (gain) on commodity derivative instruments of ($14.8) million was recognized for the nine months ended September 30, 2025, consisting of a $4.6 million increase in the fair value of open positions and $10.1 million of cash settlements received on expired positions. A net gain on commodity derivative instruments of $7.3 million was recognized for the nine months ended September 30, 2024, consisting of a $13.6 million of cash settlements received on expired positions and $0.8 million of cash settlements received on terminated derivative instruments, partially offset by a decrease of $7.1 million in the fair value of open positions.
Pipeline incident loss was $0.6 million and $1.5 million for the nine months ended September 30, 2025 and 2024, respectively. The costs reflect certain expenses not expected to be recovered under an insurance policy. See Note 16 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report for additional information.
(Gain) loss on sale of properties was ($9.5) million for the nine months ended September 30, 2025. This primarily related to the sale of certain units with rights in the Cotton Valley and Haynesville basins in Harrison County, Texas. See Note 4 of the Notes to Unaudited Condensed Consolidated Financial Statements under “Item 1. Financial Statements” of this quarterly report for additional information. There was no (gain) loss on sale of properties for the nine months ended September 30, 2024.
Interest expense, net was $11.0 million and $10.9 million for the nine months ended September 30, 2025 and 2024, respectively. For the nine months ended September 30, 2025, we recognized a write-off of deferred financing cost of $0.2 million in connection with the decrease in our borrowing base.
Average outstanding borrowings under our Revolving Credit Facility were $127.5 million and $119.8 million for the nine months ended September 30, 2025 and 2024, respectively.
Current income tax benefit (expense) was ($0.4) million and ($2.4) million for the nine months ended September 30, 2025 and 2024, respectively. See additional information discussed in Note 17 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report.
Deferred income tax benefit (expense) was $9.3 million and ($3.1) million for the nine months ended September 30, 2025 and 2024, respectively. See additional information discussed in Note 17 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report.
Non-GAAP Financial Measures
We include in this report the non-GAAP financial measure of Adjusted Net Income (Loss) and Adjusted EBITDA and provide our reconciliation of net income (loss) to Adjusted Net Income (Loss), Adjusted EBITDA to net income (loss), and net cash flows from operating activities, our most directly comparable financial measures calculated and presented in accordance with GAAP.
36
Adjusted Net Income (Loss)
We define Adjusted Net Income (Loss) as net income (loss) adjusted for unrealized loss (gain) on commodity derivative instruments, acquisition and divestiture-related expenses, impairment expense, unusual and infrequent items, and the income tax expense or benefit of these adjustments using our federal statutory tax rate. This measure is not meant to disassociate these items from management’s performance but rather is intended to provide helpful information to investors interested in comparing our performance between periods. Adjusted Net Income (Loss) is not considered to be an alternative to net income (loss) reported in accordance with GAAP.
The following tables present our reconciliation of the Company’s net income (loss) to Adjusted Net Income (Loss), our most directly comparable GAAP financial measures, for each of the periods indicated.
|
| For the Three Months Ended | | For the Nine Months Ended | ||||||||
|
| September 30, | | September 30, | ||||||||
|
| 2025 |
| 2024 | | 2025 |
| 2024 | ||||
|
| (In thousands) | ||||||||||
Net (loss) income | | $ | (20,966) | | $ | 22,652 | | $ | (20,443) | | $ | 20,375 |
Unrealized loss (gain) on commodity derivative instruments | |
| (2,077) | | | (18,672) | | | (4,638) | | | 7,100 |
Acquisition and divestiture-related expenses | | | 951 | | | 186 | | | 4,926 | | | 209 |
Impairment expense | | | 34,002 | | | — | | | 42,450 | | | — |
Non-recurring costs: | | | | | | | | | | | | |
Income tax expense (benefit) - deferred | | | (9,228) | | | 5,650 | | | (9,346) | | | 3,082 |
(Gain) loss on sale of properties | | | (1,740) | | | — | | | (9,536) | | | — |
Tax effect of adjustments (1) | | | (6,975) | | | (39) | | | (7,946) | | | (44) |
Adjusted net income (loss) | | $ | (6,033) | | $ | 9,777 | | $ | (4,533) | | $ | 30,722 |
| (1) | The federal statutory rates were utilized for all periods presented. |
Adjusted EBITDA
Adjusted EBITDA is a supplemental non-GAAP financial measure that is used by management and external users of our consolidated financial statements, such as industry analysts, investors, lenders and rating agencies. Adjusted EBITDA is not a measure of net income or cash flows as determined by GAAP. We define Adjusted EBITDA as net income (loss):
Plus:
| ● | Interest expense; |
| ● | Income tax expense; |
| ● | DD&A; |
| ● | Impairment of goodwill and long-lived assets (including oil and natural gas properties); |
| ● | Accretion of AROs; |
| ● | Loss on commodity derivative instruments; |
| ● | Cash settlements received on expired commodity derivative instruments; |
| ● | Amortization of gain associated with terminated commodity derivatives; |
| ● | Losses on sale of assets; |
37
| ● | Share-based compensation expenses; |
| ● | Exploration costs; |
| ● | Acquisition and divestiture related expenses; |
| ● | Reorganization items, net; |
| ● | Severance payments; and |
| ● | Other non-routine items that we deem appropriate. |
Less:
| ● | Interest income; |
| ● | Income tax benefit; |
| ● | Gain on commodity derivative instruments; |
| ● | Cash settlements paid on expired commodity derivative instruments; |
| ● | Gains on sale of assets and other, net; and |
| ● | Other non-routine items that we deem appropriate. |
We believe Adjusted EBITDA is useful because it allows us to more effectively evaluate our operating performance and compare the results of our operations from period to period without regard to our financing methods or capital structure.
Adjusted EBITDA should not be considered as an alternative to, or more meaningful than, net income (loss) or cash flows from operating activities as determined in accordance with GAAP or as an indicator of our operating performance or liquidity. Certain items excluded from Adjusted EBITDA are significant components in understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax structure, as well as the historic costs of depreciable assets, none of which are components of Adjusted EBITDA. Our computations of Adjusted EBITDA may not be comparable to other similarly titled measures of other companies. We believe that Adjusted EBITDA is a widely followed measure of operating performance and may also be used by investors to measure our ability to meet debt service requirements.
In addition, we use Adjusted EBITDA as an additional measure to evaluate actual cash flow available to develop existing reserves or acquire additional oil and natural gas properties.
The following tables present our reconciliation of the Company’s net income (loss) to Adjusted EBITDA and cash flows from operating activities to Adjusted EBITDA, our most directly comparable GAAP financial measures, for each of the periods indicated.
38
Reconciliation of Net Income (Loss) to Adjusted EBITDA
|
| For the Three Months Ended |
| For the Nine Months Ended | ||||||||
|
| September 30, |
| September 30, | ||||||||
|
| 2025 |
| 2024 |
| 2025 |
| 2024 | ||||
|
| (In thousands) | ||||||||||
Net income (loss) | | $ | (20,966) | | $ | 22,652 | | $ | (20,443) | | $ | 20,375 |
Interest expense, net | |
| 3,860 | |
| 3,756 | |
| 10,973 | |
| 10,915 |
Income tax expense (benefit) - current | | | (116) | |
| 412 | | | 380 | |
| 2,364 |
Income tax expense (benefit) - deferred | |
| (9,228) | |
| 5,650 | |
| (9,346) | |
| 3,082 |
Impairment expense | |
| 34,002 | |
| — | |
| 42,450 | |
| — |
DD&A | |
| 9,004 | |
| 8,102 | |
| 27,263 | |
| 24,168 |
Accretion of AROs | |
| 2,219 | |
| 2,125 | |
| 6,612 | |
| 6,282 |
Loss (gain) on commodity derivative instruments | |
| (6,922) | |
| (25,047) | |
| (14,767) | |
| (7,258) |
Cash settlements (paid) received on expired commodity derivative instruments | |
| 4,845 | | | 5,582 | |
| 10,129 | |
| 13,565 |
(Gain) loss on sale of properties | | | (1,740) | |
| — | |
| (9,536) | |
| — |
Share-based compensation expense | |
| 2,656 | |
| 1,815 | |
| 6,536 | |
| 5,113 |
Acquisition and divestiture related expenses | |
| 951 | |
| 186 | |
| 4,926 | |
| 209 |
Severance payments | | | 1,464 | | | — | | | 1,464 | | | — |
Amortization of gain associated with terminated commodity derivatives | | | 159 | | | — | | | 477 | | | — |
Pipeline incident loss | |
| 54 | |
| 247 | |
| 645 | |
| 1,454 |
Loss on settlement of AROs | |
| 33 | |
| 38 | |
| 70 | |
| 136 |
Exploration costs | |
| (1) | |
| — | |
| 15 | |
| 51 |
Bad debt expense | |
| 34 | |
| 26 | |
| 87 | |
| 52 |
Other | | | — | | | — | | | 800 | | | 686 |
Adjusted EBITDA(1) | | $ | 20,308 | | $ | 25,544 | | $ | 58,735 | | $ | 81,194 |
(1) Adjusted EBITDA includes a revenue suspense release of $0.4 million and $8.4 million for the nine months ended September 30, 2025 and 2024, respectively.
Reconciliation of Net Cash from Operating Activities to Adjusted EBITDA
|
| For the Three Months Ended | | For the Nine Months Ended | ||||||||
|
| September 30, | | September 30, | ||||||||
|
| 2025 |
| 2024 | | 2025 |
| 2024 | ||||
|
| (In thousands) | ||||||||||
Net cash provided by operating activities | | $ | 13,448 | | $ | 15,737 | | $ | 62,638 | | $ | 38,838 |
Changes in working capital | |
| 1,046 | |
| 5,937 | |
| (15,162) | |
| 27,502 |
Interest expense, net | |
| 3,860 | |
| 3,756 | |
| 10,973 | |
| 10,915 |
(Gain) loss on sale of property | | | (550) | |
| — | |
| (8,346) | |
| — |
Acquisition and divestiture related expenses | |
| 951 | |
| 186 | |
| 4,926 | |
| 209 |
Pipeline incident loss | |
| 54 | |
| 247 | |
| 645 | |
| 1,454 |
Severance payments | | | 1,464 | | | — | | | 1,464 | | | — |
Plugging and abandonment cost | |
| 482 | |
| 372 | |
| 1,044 | |
| 886 |
Amortization and write-off of deferred financing fees | |
| (489) | |
| (310) | |
| (1,119) | |
| (918) |
Cash settlements paid (received) on terminated derivatives | | | — | | | (793) | | | — | | | (793) |
Amortization of gain associated with terminated commodity derivatives | | | 159 | | | — | | | 477 | | | — |
Income tax expense (benefit) - current | |
| (116) | |
| 412 | |
| 380 | |
| 2,364 |
Exploration costs | |
| (1) | |
| — | |
| 15 | |
| 51 |
Other | |
| — | |
| — | |
| 800 | |
| 686 |
Adjusted EBITDA(1) | | $ | 20,308 | | $ | 25,544 | | $ | 58,735 | | $ | 81,194 |
(1) Adjusted EBITDA includes a revenue suspense release of $0.4 million and $8.4 million for the nine months ended September 30, 2025 and 2024, respectively.
39
Liquidity and Capital Resources
Overview. Our ability to finance our operations, including funding capital expenditures and acquisitions, to meet our indebtedness obligations, to refinance our indebtedness or to meet our collateral requirements will depend on our ability to generate cash in the future. Our primary sources of liquidity and capital resources are cash flows generated by operating activities, borrowings under our Revolving Credit Facility, equity and debt capital markets and potential proceeds from sales of assets. We plan to monitor which capital resources, including equity and debt financings, are available to us to meet our future financial obligations, planned capital expenditure activities and liquidity requirements. Based on our current oil and natural gas price expectations, we believe our cash flows provided by operating activities and availability under our Revolving Credit Facility will provide us with the financial flexibility necessary to meet our cash requirements, including normal operating needs, and to pursue our currently planned 2025 development activities. However, future cash flows are subject to a number of variables, including the level of our oil and natural gas production and the prices we receive for our oil and natural gas production, and significant additional capital expenditures will be required to more fully develop our properties. We cannot assure you that operations and other needed capital will be available on acceptable terms, or at all. For the remainder of 2025, we anticipate funding our 2025 capital program from internally generated cash flow but retain the flexibility to utilize borrowings under our Revolving Credit Facility, to access the debt and equity capital markets and continue to evaluate opportunities to optimize our portfolio to reduce debt and accelerate Beta development. We believe that existing cash and cash equivalents, any positive cash flows from operations and available borrowings under our Revolving Credit Facility will be sufficient to support working capital, capital expenditures and other cash requirements for at least the next 12 months and, based on our current expectations, for the foreseeable future thereafter.
Termination of Contemplated Merger with Juniper Capital. In connection with the Contemplated Mergers, on April 25, 2025, pursuant to Section 8.1(a) of the Merger Agreement, the Company and the Acquired Companies entered into the Termination Agreement to terminate the Merger Agreement, effective immediately. In accordance with the terms of the Termination Agreement, the Company made a cash payment to the Acquired Companies in lieu of any termination fee which might have otherwise been payable pursuant to the Merger Agreement in the amount of $800,000 as payment for certain of the Acquired Companies’ expenses. The Company incurred professional fees and expenses of approximately $3.5 million in connection with the Contemplated Mergers and the Termination. For additional information regarding the Termination, see Notes 4 and 16 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report.
Capital Markets. We do not currently anticipate any near-term capital markets activity, but we will continue to evaluate the availability of public debt and equity for funding capital needs.
Hedging. Commodity hedging has been and remains an important part of our strategy to reduce cash flow volatility. Our hedging activities are intended to support oil, NGL and natural gas prices at targeted levels and to manage our exposure to commodity price fluctuations. We intend to enter into commodity derivative contracts at times and on terms desired to maintain a portfolio of commodity derivative contracts covering at least 50% - 75% of our estimated production from total proved developed producing reserves over a one-to-three-year period at any given point of time. We may, however, from time to time, hedge more or less than this approximate amount. Additionally, we may take advantage of opportunities to modify our commodity derivative portfolio to change the percentage of our hedged production volumes when circumstances suggest that it is prudent to do so. Market conditions may also impact our ability to enter into future commodity derivative contracts.
We evaluate counterparty risks related to our commodity derivative contracts and trade credit. Should any of these financial counterparties not perform, we may not realize the benefit of some of our hedges under lower commodity prices. We sell our oil and natural gas to a variety of purchasers. Non-performance by a customer could also result in a loss.
Capital Expenditures. Our total capital expenditures were approximately $66.1 million for the nine months ended September 30, 2025, which were primarily related to the development program at Beta and non-operated drilling and completion activities in East Texas and the Eagle Ford.
40
Working Capital. Working capital is the amount by which current assets exceed current liabilities. Our working capital requirements are primarily driven by changes in accounts receivable and accounts payable, as well as the classification of our debt outstanding. These changes are impacted by changes in the prices of commodities that we buy and sell. In general, our working capital requirements increase in periods of rising commodity prices and decrease in periods of declining commodity prices. However, our working capital needs do not necessarily change at the same rate as commodity prices because both accounts receivable and accounts payable are impacted by the same commodity prices. In addition, the timing of payments received by our customers or paid to our suppliers can also cause fluctuations in working capital because we settle with most of our larger customers on a monthly basis and often near the end of the month. We expect that our future working capital requirements will be impacted by these same factors. From time-to-time, our working capital will reflect a deficit, while at other times it will reflect a surplus. This fluctuation is not unusual.
As of September 30, 2025, we had a working capital deficit (excluding commodity derivatives) of $9.6 million primarily due to accrued liabilities of $29.7 million, revenues payable of $10.1 million, and accounts payable of $29.2 million, partially offset by accounts receivable of $33.2 million and prepaid expenses of $26.2 million. As of September 30, 2025, although we had a working capital deficit, we had $12.0 million of available borrowings as of such date under our Revolving Credit Facility which provided additional liquidity. As such, we have met all debt covenant ratio requirements as of September 30, 2025.
Debt Agreement
Revolving Credit Facility. On July 31, 2023, OLLC and Acquisitionco entered into the Revolving Credit Facility. As of September 30, 2025, the borrowing base under the facility was $135.0 million with elected commitments of $135.0 million. The aggregate principal amount of loans outstanding under the Revolving Credit Facility as of September 30, 2025, was $123.0 million.
As of September 30, 2025, we had approximately $12.0 million of available borrowings under our Revolving Credit Facility.
As of September 30, 2025, we were in compliance with all the financial covenants (current ratio and total leverage ratio) and non-financial covenants associated with the Revolving Credit Facility.
For additional information regarding our Revolving Credit Facility, see Note 8 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report.
Material Cash Requirements
Contractual Commitments. We have contractual commitments under our debt agreements, including interest payments and principal payments. See Note 8 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report for additional information.
Lease Obligations. We have operating leases for office and warehouse spaces, office equipment, compressors and surface rentals related to our business obligations. See Note 12 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report for additional information.
Sinking Fund Payments. We have a funding requirement to fund two trust accounts to comply with supplemental regulatory bonding requirements related to our decommissioning obligations for the Beta production facilities. As of September 30, 2025, our future commitments under these agreements were $2.3 million for the remainder of 2025 and $9.0 million per year until the escrow accounts are fully funded. See Note 16 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report for additional information.
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Cash Flows from Operating, Investing and Financing Activities
The following table summarizes our cash flows from operating, investing and financing activities for the periods indicated. The cash flows for the nine months ended September 30, 2025 and 2024 have been derived from our Unaudited Condensed Consolidated Financial Statements. For information regarding the individual components of our cash flow amounts, see our Unaudited Condensed Consolidated Statements of Cash Flows included under “Item 1. Financial Statements” of this quarterly report.
|
| For the Nine Months Ended | ||||
|
| September 30, | ||||
|
| 2025 |
| 2024 | ||
|
| (In thousands) | ||||
Net cash provided by operating activities | | $ | 62,638 | | $ | 38,838 |
Net cash used in investing activities | |
| (56,557) | |
| (62,655) |
Net cash used in financing activities | |
| (6,081) | |
| 3,071 |
Operating Activities. Key drivers of net operating cash flows are commodity prices, production volumes and operating costs. Net cash provided by operating activities was $62.6 million and $38.8 million for the nine months ended September 30, 2025 and 2024, respectively.
Production volumes were approximately 18.9 MBoe/d and 19.8 MBoe/d for the nine months ended September 30, 2025 and 2024, respectively. The average realized sales price was $39.03 per Boe and $39.69 per Boe for the nine months ended September 30, 2025 and 2024, respectively. The change in realized sales price was due to lower realized sales prices for oil, partially offset by higher realized sales prices for natural gas.
Net cash provided by operating activities for the nine months ended September 30, 2025 included $10.1 million of cash received on expired commodity derivative instruments compared to $13.6 million of cash received on expired commodity derivatives for the nine months ended September 30, 2024. For the nine months ended September 30, 2025, we had a net gain on commodity derivative instruments of $14.8 million compared to a net gain on commodity derivative instruments of $7.3 million for the nine months ended September 30, 2024.
The Company recognized an impairment charge of $42.5 million for the nine months ended September 30, 2025, due to marketing its assets and reassessing the fair market value less costs to sell.
Investing Activities. Net cash used in investing activities for the nine months ended September 30, 2025 was $56.6 million, of which $65.2 million (on an accrual basis) was used for additions to oil and natural gas properties and $0.9 million for additions to other property and equipment. In addition, we had changes in our accounts payable and accrued expenses of $5.5 million for the nine months ended September 30, 2025. Net cash used in investing activities for the nine months ended September 30, 2024 was $62.7 million, of which $54.1 million was used for additions to oil and natural gas properties and $1.0 million for additions to other property and equipment.
During 2025, we purchased and sold certain rights, title and interest in assets in East Texas to a third party, whereby we received net proceeds of $7.8 million. In addition, we divested all of our non-operated working interests in the Eagle Ford for a contract price of $23.0 million. See additional information discussed in Note 4 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report.
Various restricted investment accounts fund certain long-term contractual and regulatory asset retirement obligations and collateralize certain regulatory bonds associated with our Beta properties. Additions to restricted investments were $7.7 million and $7.5 million for the nine months ended September 30, 2025 and 2024, respectively.
Financing Activities. We had net repayments of $4.0 million for the nine months ended September 30, 2025 related to our Revolving Credit Facility compared to net borrowings of $5.0 million for the nine months ended September 30, 2024. Shares withheld for taxes were $2.0 million and $1.9 million for the nine months ended September 30, 2025 and 2024, respectively.
42
Off–Balance Sheet Arrangements
As of September 30, 2025, we had no off–balance sheet arrangements.
Recently Issued Accounting Pronouncements
For a discussion of recent accounting pronouncements that will affect us, see Note 2 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report for additional information.
ITEM 3.QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.
We are a smaller reporting company as defined by Rule 12b-2 of the Exchange Act and are not required to provide the information under this item.
ITEM 4.CONTROLS AND PROCEDURES.
Evaluation of Disclosure Controls and Procedures
As required by Rules 13a-15(b) and 15d-15(b) of the Exchange Act, we have evaluated, under the supervision and with the participation of our management, including the principal executive officer and principal financial officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this quarterly report. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in reports that we file under the Exchange Act is accumulated and communicated to our management, including the principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure, and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Based upon the evaluation, the principal executive officer and principal financial officer have concluded that our disclosure controls and procedures were effective at the reasonable assurance level as of September 30, 2025. We believe that our internal controls and procedures are still functioning as designed and were effective for the most recent quarter.
Change in Internal Control Over Financial Reporting
No changes in our internal control over financial reporting occurred during the most recent quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
The certifications required by Section 302 of the Sarbanes-Oxley Act of 2002 are filed as Exhibits 31.1 and 31.2, respectively, to this quarterly report.
43
PART II—OTHER INFORMATION
ITEM 1.LEGAL PROCEEDINGS.
For a discussion of the legal proceedings associated with the Incident, see Note 16 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report and the annual financial statements and related notes included in our 2024 Form 10-K.
Future litigation may be necessary, among other things, to defend ourselves by determining the scope, enforceability, and validity of claims. The results of any current or future litigation cannot be predicted with certainty, and regardless of the outcome, litigation can have an adverse impact on us because of defense and settlement costs, diversion of management resources, and other factors.
ITEM 1A.RISK FACTORS.
Our business faces many risks. Any of the risks discussed elsewhere in this quarterly report and our other SEC filings could have a material impact on our business, financial position or results of operations. Additional risks and uncertainties not presently known to us or that we currently believe to be immaterial may also impair our business operations. Except as set forth below, there have been no material changes to the risk factors disclosed in Part I, Item 1A in our 2024 Form 10-K.
There are substantial risks with any divestitures we have completed or that we may choose to undertake.
We review our asset portfolio to ensure alignment with our strategic initiatives and may, as a result, seek to divest certain of our assets, such as in the case of the previously announced divestitures of our assets in East Texas and Oklahoma in 2025. We may not be able to complete divestitures on favorable terms, on a timely basis, or at all. Even if we do complete such transactions, our business and financial condition may be adversely impacted and/or the transactions may not result in the benefits anticipated due to various risks, including, but not limited to (i) the inability to dispose of certain of our assets on satisfactory terms and conditions; (ii) the discovery of unknown and unforeseen liabilities or other issues related to divested assets, for which contractual protections are inadequate or we lack insurance or indemnities, including environmental liabilities or (iii) claims by purchasers to whom we have provided contractual indemnification.
Additionally, the inability to complete pending or planned divestitures on the initial terms or within the expected time frame may adversely affect our business and financial condition. If a transaction fails to close as anticipated, or if we receive lower cash consideration than originally planned, the amount of cash available for repayment of outstanding borrowings, for funding our capital budget or for other purposes as determined by the Company, as well as the timing of such repayment or funding, may be negatively impacted. Uncertainties in the macro environment for the oil and gas industry, including changes to commodity prices and drilling and completion activity, may further increase the risk that divestiture transactions do not close as expected.
ITEM 2.UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS.
The following table summarizes our repurchase activity during the three months ended September 30, 2025:
|
| |
| | |
| Total Number of |
| Approximate Dollar |
| | | | | |
| Shares Purchased as |
| Value of Shares That |
| | | | | |
| Part of Publicly |
| May Yet Be |
|
| Total Number of |
| Average Price |
| Announced Plans |
| Purchased Under the | |
Period |
| Shares Purchased |
| Paid per Share |
| or Programs |
| Plans or Programs (1) | |
| | | | | | | |
| (In thousands) |
Common Shares Repurchased (1) |
|
|
| |
|
|
|
|
|
July 1, 2025 - July 31, 2025 |
| 1,837 | | $ | 3.28 |
| — |
| n/a |
August 1, 2025 - August 31, 2025 |
| 3,046 | | $ | 3.93 |
| — |
| n/a |
September 1, 2025 - September 30, 2025 |
| — | | $ | — |
| — |
| n/a |
44
| (1) | Common shares are generally net-settled by shareholders to cover the required withholding tax upon vesting. We repurchased the remaining vesting shares on the vesting date at current market price. See Note 9 of the Notes to the Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report for additional information. |
ITEM 3.DEFAULTS UPON SENIOR SECURITIES.
None.
ITEM 4.MINE SAFETY DISCLOSURES.
Not applicable.
ITEM 5.OTHER INFORMATION.
45
ITEM 6.EXHIBITS.
Exhibit |
|
| Description | |
|---|---|---|---|---|
2.1 | | — | | |
| | | | |
2.2 | | — | | |
| | | | |
2.3+ | | — | | |
| | | | |
2.4+ | | — | | |
| | | | |
2.5+ | | — | | |
| | | | |
3.1 | | — | | |
| | | | |
3.2 | | — | | |
| | | | |
3.3 | | — | | |
| | | | |
10.1 | | — | | |
| | | | |
10.2 | | — | | |
| | | | |
31.1* | | — |
| |
| | | | |
31.2* | | — |
| |
| | | | |
32.1** | — |
| ||
| | | | |
101.INS* | | — |
| Inline XBRL Instance Document |
| | | | |
101.SCH* | | — |
| Inline XBRL Schema Document |
46
Exhibit |
|
| Description | |
|---|---|---|---|---|
| | | | |
101.CAL* | | — |
| Inline XBRL Calculation Linkbase Document |
| | | | |
101.DEF* | | — |
| Inline XBRL Definition Linkbase Document |
| | | | |
101.LAB* | | — |
| Inline XBRL Labels Linkbase Document |
| | | | |
101.PRE* | | — |
| Inline XBRL Presentation Linkbase Document |
| | | | |
104* | | — | | Cover Page Interactive Data File (embedded within the Inline XBRL document) |
* | Filed as an exhibit to this Quarterly Report on Form 10-Q. |
** | Furnished as an exhibit to this Quarterly Report on Form 10-Q. |
+ | Certain schedules and exhibits to this agreement have been omitted in accordance with Item 601(a)(5) of Regulation S-K. A copy of any omitted schedule and/or exhibit will be furnished to the Securities and Exchange Commission on request. |
47
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
| Amplify Energy Corp. | ||
| (Registrant) | ||
| | ||
| | ||
Date: | November 5, 2025 | By: | /s/ James Frew |
| | Name: | James Frew |
| | Title: | President and Chief Financial Officer |
| | | |
| | | |
Date: | November 5, 2025 | By: | /s/ Eric Dulany |
| | Name: | Eric Dulany |
| | Title: | Vice President and Chief Accounting Officer |
48
Exhibit 31.1
CERTIFICATION OF CHIEF EXECUTIVE OFFICER
PURSUANT TO RULE 13A-14(A) AND RULE 15D-14(A)
OF THE SECURITIES EXCHANGE ACT OF 1934, AS AMENDED
I, Daniel Furbee, certify that:
1. | I have reviewed this Quarterly Report on Form 10-Q of Amplify Energy Corp. (the “registrant”); |
2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
4. | The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
a. | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
b. | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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; |
c. | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
d. | Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
5. | The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): |
a. | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
b. | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
Date: November 5, 2025 | /s/ Daniel Furbee |
Daniel Furbee | |
| Chief Executive Officer |
Amplify Energy Corp. |
Exhibit 31.2
CERTIFICATION OF PRINCIPAL FINANCIAL OFFICER
PURSUANT TO RULE 13A-14(A) AND RULE 15D-14(A)
OF THE SECURITIES EXCHANGE ACT OF 1934, AS AMENDED
I, James Frew, certify that:
1. | I have reviewed this Quarterly Report on Form 10-Q of Amplify Energy Corp. (the “registrant”); |
2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
4. | The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
a. | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
b. | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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; |
c. | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
d. | Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
5. | The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): |
a. | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
b. | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
Date:November 5, 2025 | /s/ James Frew |
James Frew | |
| President and Chief Financial Officer |
Amplify Energy Corp. |
Exhibit 32.1
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
In connection with the Quarterly Report on Form 10-Q of Amplify Energy Corp. (the “Company”), as filed with the Securities and Exchange Commission on the date hereof (the “Report”), the undersigned, Daniel Furbee, Chief Executive Officer and James Frew, President and Chief Financial Officer, of Amplify Energy Corp., certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to their knowledge:
(1) | the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and |
(2) | the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. |
Date: November 5, 2025 | /s/ Daniel Furbee |
| Daniel Furbee |
| Chief Executive Officer |
Amplify Energy Corp. | |
| |
| |
Date: November 5, 2025 | /s/ James Frew |
| James Frew |
| President and Chief Financial Officer |
| Amplify Energy Corp. |
| |
| |
| |
The foregoing certifications are being furnished as an exhibit to the Report pursuant to Item 601(b)(32) of Regulation S-K and Section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code) and, accordingly, are not being filed as part of the Report for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and are not incorporated by reference into any filing of the Company, whether made before or after the date hereof, regardless of any general incorporation language in such filing.