Amplify Energy Corp._September 30, 2025

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UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q


☑	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2025


☐	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: 001-35512

Amplify Energy Corp.

(Exact name of registrant as specified in its charter)


Delaware		82-1326219
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

500 Dallas Street, Suite 1700, Houston, TX		77002
(Address of principal executive offices)		(Zip Code)

Registrant’s telephone number, including area code: (832) 219-9001

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. Yes þ No ☐

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). Yes þ No ☐

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 ☐	Accelerated filer þ
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 ☐ No þ

Securities Registered Pursuant to Section 12(b):


Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock	AMPY	NYSE

As of October 31, 2025, the registrant had 40,475,997 outstanding shares of common stock, $0.01 par value outstanding.

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AMPLIFY ENERGY CORP.

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		Page
	Glossary of Oil and Natural Gas Terms	1
	Names of Entities	4
	Cautionary Note Regarding Forward-Looking Statements	5

PART I—FINANCIAL INFORMATION
Item 1.	Financial Statements	8
	Unaudited Condensed Consolidated Balance Sheets as of September 30, 2025 and December 31, 2024	8
	Unaudited Condensed Consolidated Statements of Operations for the Three and Nine Months Ended September 30, 2025 and 2024	9
	Unaudited Condensed Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 2025 and 2024	10
	Unaudited Condensed Consolidated Statements of Equity (Deficit) for the Three and Nine Months Ended September 30, 2025 and 2024	11
	Notes to Unaudited Condensed Consolidated Financial Statements	12
	Note 1 – Organization and Basis of Presentation	12
	Note 2 – Summary of Significant Accounting Policies	12
	Note 3 – Revenue	13
	Note 4 – Acquisition and Divestitures	14
	Note 5 – Fair Value Measurements of Financial Instruments	15
	Note 6 – Risk Management and Derivative Instruments	17
	Note 7 – Asset Retirement Obligations	19
	Note 8 – Long-Term Debt	19
	Note 9 – Equity	21
	Note 10 – Earnings (Loss) per Share	21
	Note 11 – Long-Term Incentive Plans	21
	Note 12 – Leases	24
	Note 13 – Supplemental Disclosures to the Unaudited Condensed Consolidated Balance Sheets and Unaudited Condensed Consolidated Statements of Cash Flows	26
	Note 14 – Related Party Transactions	27
	Note 15 – Segment Reporting	27
	Note 16 – Commitments and Contingencies	27
	Note 17 – Income Taxes	29
	Note 18 – Subsequent Events	30

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	31
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	43
Item 4.	Controls and Procedures	43

PART II—OTHER INFORMATION
Item 1.	Legal Proceedings	44
Item 1A.	Risk Factors	44
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	44
Item 3.	Defaults Upon Senior Securities	45
Item 4.	Mine Safety Disclosures	45
Item 5.	Other Information	45
Item 6.	Exhibits	46

Signatures		48

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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.

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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.

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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.

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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:

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business strategies;

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acquisition and disposition strategy;

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cash flows and liquidity;

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financial strategy;

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ability to replace the reserves we produce through drilling;

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drilling locations;

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oil and natural gas reserves;

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technology;

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realized oil, natural gas and NGL prices;

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production volumes;

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lease operating expense;

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gathering, processing and transportation;

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general and administrative expense;

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future operating results;

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ability to procure drilling and production equipment;

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ability to procure oil field labor;

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planned capital expenditures and the availability of capital resources to fund capital expenditures;

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ability to access capital markets;

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marketing of oil, natural gas and NGLs;

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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;

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acts of God, fires, earthquakes, storms, floods, other adverse weather conditions, war, acts of terrorism, cybersecurity breaches, military operations or national emergency;

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the occurrence or threat of epidemic or pandemic diseases, or any government response to such occurrence or threat;

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expectations regarding general economic conditions, including inflation;

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competition in the oil and natural gas industry;

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effectiveness of risk management activities;

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environmental liabilities;

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counterparty credit risk;

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expectations regarding governmental regulation and taxation;

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expectations regarding developments in oil-producing and natural-gas producing countries; and

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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:

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risks related to a redetermination of the borrowing base under our senior secured reserve-based revolving credit facility (the “Revolving Credit Facility”);

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our ability to access funds on acceptable terms, if at all, because of the terms and conditions governing our indebtedness, including financial covenants;

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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;

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our ability to satisfy debt obligations;

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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;

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the potential for additional impairments due to continuing or future declines in oil, natural gas and NGL prices;

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the uncertainty inherent in estimating quantities of oil, natural gas and NGL reserves;

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our substantial future capital requirements, which may be subject to limited availability of financing;

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the uncertainty inherent in the development and production of oil and natural gas;

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our need to make accretive acquisitions or substantial capital expenditures to maintain our declining asset base;

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the existence of unanticipated liabilities or problems relating to acquired or divested businesses or properties;

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potential acquisitions, including our ability to make acquisitions on favorable terms or to integrate acquired properties;

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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;

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potential shortages of, or increased costs for, drilling and production equipment and supply materials for production, such as CO₂;

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potential difficulties in the marketing of oil and natural gas;

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changes to the financial condition of counterparties;

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uncertainties surrounding the success of our secondary and tertiary recovery efforts;

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competition in the oil and natural gas industry;

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our results of evaluation and implementation of strategic alternatives;

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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;

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the impact of climate change and natural disasters, such as earthquakes, tidal waves, mudslides, fires and floods;

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the impact of local, state and federal governmental regulations, including those related to climate change and hydraulic fracturing, and potential changes in these regulations;

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the risk that our hedging strategy may be ineffective or may reduce our income;

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the cost and availability of insurance as well as operating risks that may not be covered by an effective indemnity or insurance;

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actions of third-party co-owners of interests in properties in which we also own an interest; and

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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.

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PART I—FINANCIAL INFORMATION

ITEM 1.FINANCIAL STATEMENTS.

AMPLIFY ENERGY CORP.

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except outstanding shares)


	September 30,		December 31,
	2025		2024
ASSETS
Current assets:
Cash and cash equivalents	$	—	$	—
Accounts receivable, net (see Note 13)		33,207		39,713
Short-term derivative instruments		10,983		6,385
Prepaid expenses and other current assets		26,168		25,679
Total current assets		70,358		71,777
Property and equipment, at cost:
Oil and natural gas properties, successful efforts method		903,217		942,981
Support equipment and facilities		154,844		150,511
Other		12,404		11,478
Accumulated depreciation, depletion and amortization		(711,469)		(718,752)
Property and equipment, net		358,996		386,218
Long-term derivative instruments		273		233
Restricted investments		37,684		29,993
Operating lease - long term right-of-use asset		3,730		4,540
Deferred tax asset		258,600		251,600
Other long-term assets		1,714		2,715
Total assets	$	731,355	$	747,076

LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	29,154	$	13,231
Revenues payable		10,145		11,494
Accrued liabilities (see Note 13)		29,698		43,413
Total current liabilities		68,997		68,138
Long-term debt (see Note 8)		123,000		127,000
Asset retirement obligations		133,276		129,700
Operating lease liability		2,985		3,683
Other long-term liabilities		10,123		9,643
Total liabilities		338,381		338,164
Commitments and contingencies (see Note 16)
Stockholders' equity (deficit):
Preferred stock, $0.01 par value: 50,000,000 shares authorized; no shares issued and outstanding at September 30, 2025 and December 31, 2024		—		—
Common stock, $0.01 par value: 250,000,000 shares authorized; 40,475,997 and 39,795,138 shares issued and outstanding at September 30, 2025 and December 31, 2024, respectively		405		399
Additional paid-in capital		444,480		439,981
Accumulated deficit		(51,911)		(31,468)
Total stockholders' equity (deficit)		392,974		408,912
Total liabilities and equity	$	731,355	$	747,076

See Accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

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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
	September 30,				September 30,
	2025		2024		2025		2024
Revenues:
Oil and natural gas sales	$	64,242	$	68,135	$	201,357	$	215,803
Other revenues		2,154		1,723		5,450		9,857
Total revenues		66,396		69,858		206,807		225,660

Costs and expenses:
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
Accretion of asset retirement obligations		2,219		2,125		6,612		6,282
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)		—
Other, net		33		38		86		187
Total costs and expenses		92,918		37,258		224,764		188,590
Operating income (loss)		(26,522)		32,600		(17,957)		37,070
Other income (expense):
Interest expense, net		(3,860)		(3,756)		(10,973)		(10,915)
Other income (expense)		72		(130)		(479)		(334)
Total other income (expense)		(3,788)		(3,886)		(11,452)		(11,249)
Income (loss) before income taxes		(30,310)		28,714		(29,409)		25,821
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

Allocation of net income (loss) to:
Net income (loss) available to common stockholders	$	(20,966)	$	21,569	$	(20,443)	$	19,392
Net income (loss) allocated to participating securities		—		1,083		—		983
Net income (loss) available to Amplify Energy Corp.	$	(20,966)	$	22,652	$	(20,443)	$	20,375

Earnings (loss) per share: (See Note 10)
Basic and diluted earnings (loss) per share	$	(0.52)	$	0.54	$	(0.51)	$	0.49
Weighted average common shares outstanding:
Basic and diluted		40,471		39,783		40,337		39,608

See Accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

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AMPLIFY ENERGY CORP.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)


	For the Nine Months Ended
	September 30,
	2025		2024
Cash flows from operating activities:
Net income (loss)	$	(20,443)	$	20,375
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization		27,263		24,168
Impairment expense		42,450		—
Loss (gain) on derivative instruments		(14,767)		(7,258)
Cash settlements (paid) received on expired derivative instruments		10,129		13,564
Cash settlements received (paid) on terminated derivative instruments		—		793
Deferred income tax expense (benefit)		(9,346)		3,082
Accretion of asset retirement obligations		6,612		6,282
(Gain) loss on sale of properties		(1,190)		—
Share-based compensation (see Note 11)		6,536		5,113
Settlement of asset retirement obligations		(974)		(750)
Amortization and write-off of deferred financing costs		1,119		918
Bad debt expense		87		52
Changes in operating assets and liabilities:
Accounts receivable		6,419		6,749
Prepaid expenses and other assets		4,389		(2,798)
Payables and accrued liabilities		4,181		(31,452)
Other		173		—
Net cash provided by operating activities		62,638		38,838
Cash flows from investing activities:
Additions to oil and gas properties		(79,285)		(54,102)
Additions to other property and equipment		(926)		(1,037)
Additions to restricted investments		(7,692)		(7,516)
Proceeds from the sale of oil and natural gas properties		31,346		—
Net cash used in investing activities		(56,557)		(62,655)
Cash flows from financing activities:
Advances on Revolving Credit Facility		99,000		85,000
Payments on Revolving Credit Facility		(103,000)		(80,000)
Deferred financing costs		(50)		(76)
Shares withheld for taxes		(2,031)		(1,853)
Net cash used in financing activities		(6,081)		3,071
Net change in cash and cash equivalents		—		(20,746)
Cash and cash equivalents, beginning of period		—		20,746
Cash and cash equivalents, end of period	$	—	$	—

See Accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

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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	$	399	$	439,981	$	(31,468)	$	408,912
Net income (loss)		—		—		(5,861)		(5,861)
Share-based compensation expense		—		1,890		—		1,890
Shares withheld for taxes		—		(2,004)		—		(2,004)
Other		5		(5)		—		—
Balance at March 31, 2025		404		439,862		(37,329)		402,937
Net income (loss)		—		—		6,384		6,384
Share-based compensation expense		—		1,990		—		1,990
Shares withheld for taxes		—		(6)		—		(6)
Other		—		—		—		—
Balance at June 30, 2025		404		441,846		(30,945)		411,305
Net income (loss)		—		—		(20,966)		(20,966)
Share-based compensation expense		—		2,656		—		2,656
Shares withheld for taxes		—		(21)		—		(21)
Other		1		(1)		—		—
Balance at September 30, 2025	$	405	$	444,480	$	(51,911)	$	392,974


	Stockholders' Equity (Deficit)
			Additional		Accumulated
	Common		Paid-in		Earnings
	Stock		Capital		(Deficit)		Total
Balance at December 31, 2023	$	393	$	435,095	$	(44,452)	$	391,036
Net income (loss)		—		—		(9,396)		(9,396)
Share-based compensation expense		—		1,120		—		1,120
Shares withheld for taxes		—		(1,745)		—		(1,745)
Other		5		(5)		—		—
Balance at March 31, 2024		398		434,465		(53,848)		381,015
Net income (loss)		—		—		7,119		7,119
Share-based compensation expense		—		2,140		38		2,178
Shares withheld for taxes		—		(23)		—		(23)
Balance at June 30, 2024		398		436,582		(46,691)		390,289
Net income (loss)		—		—		22,652		22,652
Share-based compensation expense		—		1,815		—		1,815
Shares withheld for taxes		—		(86)		—		(86)
Other		2		(2)		—		—
Balance at September 30, 2024	$	400	$	438,309	$	(24,039)	$	414,670

See Accompanying Notes to Unaudited Condensed Consolidated Financial Statements.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 $0.01 per share (“Common Stock”), is listed on the NYSE under the symbol “AMPY.”

The Company operates in one reportable segment that is engaged in the acquisition, development, exploitation and production of oil and natural gas properties. The Company’s management evaluates performance based on one reportable business segment as there are not different economic environments within the operation of the Company’s oil and natural gas properties. The Company’s 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). Most of the Company’s oil and natural gas properties are located in large, mature oil and natural gas reservoirs. The Company’s properties consist primarily of operated and non-operated working interests in producing and undeveloped leasehold acreage and working interests in identified producing wells.

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.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Disaggregation of Revenue

The Company has identified three material revenue streams in its business: oil, natural gas and NGLs. The following table presents the Company’s revenues disaggregated by revenue stream.


	For the Three Months Ended				For the Nine Months Ended
	September 30,				September 30,
	2025		2024		2025		2024

	(In thousands)
Revenues
Oil	$	45,543	$	54,353	$	145,230	$	169,563
NGLs		5,401		6,096		17,206		20,187
Natural gas		13,298		7,686		38,921		26,053
Oil and natural gas sales	$	64,242	$	68,135	$	201,357	$	215,803

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 $26.5 million at September 30, 2025 and $28.5 million at December 31, 2024.

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 $23.0 million, subject to certain post-closing adjustments (the “Asset Sale”). The Asset Sale closed simultaneously with the execution and delivery of the Purchase and Sale Agreement on July 1, 2025. Upon the Asset Sale, Amplify no longer holds any assets in the Eagle Ford. The Purchase and Sale Agreement became effective as of June 15, 2025. The Company recognized an impairment expense of approximately $8.4 million for the nine months ended September 30, 2025 in connection with the divestiture.

East Texas Haynesville Monetization

On January 15, 2025, the Company sold 90% of its interest in certain units with rights in the Cotton Valley and Haynesville basins in Harrison County, Texas and purchased a 10% interest in adjacent acreage, generating $6.3 million in net proceeds from the transactions. These transactions also established an area of mutual interest with the counterparty covering 10,000 gross acres. Amplify retained a 10% working interest in the units it divested and purchased a 10% working interest in the counterparty’s acreage. The net proceeds received from the purchase and sale transactions of $6.3 million is classified as a (gain) loss on sale of properties in our Unaudited Consolidated Statement of Operations.

On May 1, 2025, the Company sold 90% of its interest in three units with rights in the Haynesville basin in Panola and Shelby Counties, Texas to a third party. Amplify retained a 10% working interest in the units it divested. The net proceeds from the transaction of $1.5 million are classified as a (gain) loss on sale of properties in our Unaudited Consolidated Statement of Operations.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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
$	951	$	186	$	4,926	$	209

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.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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	$	—	$	21,362	$	—	$	21,362
Interest rate derivatives		—		—		—		—
Total assets	$	—	$	21,362	$	—	$	21,362

Liabilities:
Commodity derivatives	$	—	$	10,106	$	—	$	10,106
Interest rate derivatives		—		—		—		—
Total liabilities	$	—	$	10,106	$	—	$	10,106


	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	$	—	$	14,317	$	—	$	14,317
Interest rate derivatives		—		—		—		—
Total assets	$	—	$	14,317	$	—	$	14,317

Liabilities:
Commodity derivatives	$	—	$	7,699	$	—	$	7,699
Interest rate derivatives		—		—		—		—
Total liabilities	$	—	$	7,699	$	—	$	7,699

See Note 6 for additional information regarding the Company’s derivative instruments.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 $34.0 million and $42.5 million for the three and nine months ended September 30, 2025, respectively. The Company recognized an impairment charge due to the carrying value of the assets exceeding the fair market value of the assets.

o

No impairment expense was recorded on proved oil and natural gas properties during the three and nine months ended September 30, 2024.

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 $11.3 million against amounts outstanding under the Revolving Credit Facility at September 30, 2025. See Note 8 for additional information regarding the Company’s Revolving Credit Facility.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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)		560,000		515,000		197,500		20,000
Weighted-average fixed price	$	3.75	$	3.80	$	3.96	$	3.86

Collar contracts:
Two-way collars
Average monthly volume (MMBtu)		500,000		517,500		640,000		67,500
Weighted-average floor price	$	3.50	$	3.58	$	3.54	$	3.50
Weighted-average ceiling price	$	3.90	$	4.11	$	4.31	$	4.52

Crude Oil Derivative Contracts:
Fixed price swap contracts:
Average monthly volume (Bbls)		186,000		152,500		57,417		—
Weighted-average fixed price	$	70.21	$	65.63	$	62.53	$	—

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 no cash collateral received or pledged associated with the Company’s derivative instruments since most of its counterparties, or certain of its affiliates, to its derivative contracts are lenders under its Revolving Credit Facility.


		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	$	14,003	$	3,020	$	9,499	$	3,114
Interest rate swaps	Short-term derivative instruments		—		—		—		—
Gross fair value			14,003		3,020		9,499		3,114
Netting arrangements			(3,020)		(3,020)		(3,114)		(3,114)
Net recorded fair value	Short-term derivative instruments	$	10,983	$	—	$	6,385	$	—

Commodity contracts	Long-term derivative instruments	$	7,359	$	7,086	$	4,818	$	4,585
Interest rate swaps	Long-term derivative instruments		—		—		—		—
Gross fair value			7,359		7,086		4,818		4,585
Netting arrangements			(7,086)		(7,086)		(4,585)		(4,585)
Net recorded fair value	Long-term derivative instruments	$	273	$	—	$	233	$	—

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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. The following table details the gains and losses related to derivative instruments for the periods indicated (in thousands):


		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	$	(6,922)	$	(25,047)	$	(14,767)	$	(7,258)

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. The following table presents the changes in the asset retirement obligations for the nine months ended September 30, 2025 (in thousands):


Asset retirement obligations at beginning of period	$	131,077
Liabilities added from acquisition or drilling		10
Liabilities settled		(974)
Liabilities removed upon sale of wells		(2,130)
Accretion expense		6,612
Revision of estimates		58
Asset retirement obligation at end of period		134,653
Less: Current portion		1,377
Asset retirement obligations - long-term portion	$	133,276

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⁾	$	123,000	$	127,000
Total long-term debt	$	123,000	$	127,000

(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 $123.0 million. As of September 30, 2025, the borrowing base under the facility was $135.0 million with elected commitments of $135.0 million. The Revolving Credit Facility borrowing base is subject to redetermination on at least a semi-annual basis, primarily based on a reserve engineering report.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 2.00% to 3.00% for adjusted base rate borrowings, and 3.00% to 4.00% for adjusted SOFR borrowings;

●

The unused commitments under the Revolving Credit Facility will accrue a commitment fee of 0.50%, payable quarterly in arrears;

●

Certain financial covenants, including the maintenance of (i) a net debt leverage ratio not to exceed 3.00 to 1.00, determined as of the last day of each fiscal quarter for the four fiscal-quarter period then ending and (ii) a current ratio of not less than 1.00 to 1.00, determined as of the last day of each fiscal quarter;

●

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 75% of the reasonably projected monthly production of hydrocarbons from proved developed producing reserves for the 24-month period following the effective date of the Revolving Credit Facility (the “First Period”) and (ii) 50% for the 12-month period immediately following the First Period.

On May 29, 2025, the Company completed the spring redetermination which affirmed the borrowing base at $145.0 million.

On July 2, 2025, subsequent to the Asset Sale, the Company’s borrowing base was reduced to $135.0 million.

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	8.48	%	9.28	%	8.45	%	9.34	%

Letters of Credit

At September 30, 2025, the Company had no letters of credit outstanding.

Unamortized Deferred Financing Costs

Unamortized deferred financing costs associated with the Company’s Revolving Credit Facility were $2.2 million at September 30, 2025.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 9. Equity

Common Stock

The Company’s authorized capital stock includes 250,000,000 shares of Common Stock. The following is a summary of the changes in the Company’s Common Stock issued for the nine months ended September 30, 2025:


		Common Stock
Balance, December 31, 2024		39,795,138
Issuance of Common Stock		—
Restricted stock units vested		1,002,236
Shares withheld for taxes ⁽¹⁾		(321,377)
Balance, September 30, 2025		40,475,997

(1)

Represents the net settlement on vesting of restricted stock to satisfy tax withholding requirements.

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)	$	(20,966)	$	22,652	$	(20,443)	$	20,375
Less: Net income allocated to participating securities		—		1,083		—		983
Basic and diluted earnings available to common stockholders	$	(20,966)	$	21,569	$	(20,443)	$	19,392

Common shares:
Common shares outstanding — basic		40,471		39,783		40,337		39,608
Dilutive effect of potential common shares		—		—		—		—
Common shares outstanding — diluted		40,471		39,783		40,337		39,608

Net earnings (loss) per share:
Basic	$	(0.52)	$	0.54	$	(0.51)	$	0.49
Diluted	$	(0.52)	$	0.54	$	(0.51)	$	0.49

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.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 $6.3 million at September 30, 2025. The Company expects to recognize the unrecognized compensation cost for these awards over a weighted average period of approximately 1.7 years.

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	1,379,356	$	6.43
Granted ⁽²⁾	983,549	$	4.99
Forfeited	(2,533)	$	5.34
Vested	(754,296)	$	6.06
TSUs outstanding at September 30, 2025	1,606,076	$	5.72

(1)

Determined by dividing the aggregate grant-date fair value of awards by the number of awards issued.

(2)

The aggregate grant-date fair value of TSUs issued for the nine months ended September 30, 2025 was $4.9 million based on a grant-date market price ranging from $3.28 per share to $5.34 per share.

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 Monte Carlo 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 0% to 200% of the target awards granted based on the Company’s relative total shareholder return as compared to the total shareholder return of the Company’s performance peer group over the applicable performance period.

The 2023, 2024 and 2025 PSU awards are accounted for as equity-classified awards and were issued with a three-year vesting period beginning on the grant date and ending on the third anniversary of the grant date. The three-year performance period for the 2023 awards is January 1, 2023 through December 31, 2025. The three-year performance period for the 2024 awards is January 1, 2024 through December 31, 2026. The three-year performance period for the 2025 awards is January 1, 2025 through December 31, 2027.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

In connection with Mr. Daniel Furbee’s appointment as Chief Executive Officer, he received a grant of 100,000 PSUs (the “Target PSUs”) on July 22, 2025. The Target PSUs are subject to a performance period that began on July 22, 2025 and ends on March 31, 2028 (the “Performance Period”). The Target PSUs will vest, subject to Mr. Furbee’s continued employment through the settlement date, as follows: (i) 50% of the Target PSUs will vest if the 20-day volume-weighted average closing price (“VWAP”) of a share of Company common stock for the 20 consecutive trading days immediately preceding the end of the Performance Period equals at least $6.00 but less than $8.00, (ii) 100% of the Target PSUs will vest if the 20-day VWAP of a share of Company common stock for the 20 consecutive trading days immediately preceding the end of the Performance Period equals at least $8.00, but less than $10.00, and (iii) 200% of the Target PSUs will vest if the 20-day VWAP of a share of the Company’s common stock for the 20 consecutive trading days immediately preceding the end of the Performance Period equals at least $10.00, with linear interpolation to apply for actual performance achieved between the foregoing thresholds.

Compensation costs related to PSU awards are recorded as general and administrative expense. The unrecognized cost associated with PSU awards was $3.4 million at September 30, 2025. The Company expects to recognize the unrecognized compensation cost for PSU awards over a weighted-average period of approximately 1.8 years.

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	58.6	%	60	%
Dividend yield	0.00	%	0.00	%
Risk-free interest rate	4.22	%	3.74	%

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	608,500	$	9.58
Granted ⁽²⁾	595,783	$	6.31
Forfeited	—	$	—
Vested	(247,940)	$	6.20
PSUs outstanding at September 30, 2025	956,343	$	8.42

(1)

Determined by dividing the aggregate grant-date fair value of awards by the number of awards issued.

(2)

The aggregate grant-date fair value of PSUs issued for the nine months ended September 30, 2025 was $3.8 million based on a calculated fair value price ranging from $3.68 to $7.05 per share.

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	$	1,476	$	1,322	$	4,099	$	3,685
PSUs		1,180		494		2,438		1,428
	$	2,656	$	1,816	$	6,537	$	5,113

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 leases can be terminated with 30-day prior written notice. The majority of its month-to-month leases are not included as a lease liability in its balance sheet because continuation of the lease is not reasonably certain. Additionally, the Company elected the short-term practical expedient to exclude leases with a term of twelve months or less. For the quarter ended September 30, 2025, all of the Company’s leases qualified as operating leases, and it did not have any existing or new leases qualifying as financing leases or variable leases.

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 $1.6 million and $1.5 million, respectively, of costs relating to the operating leases in the Unaudited Condensed Consolidated Statements of Operations.

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	$	810	$	1,143

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	$	3,730	$	4,540

Lease liabilities:
Current lease liability		1,546		1,784
Long-term lease liability		2,985		3,683
Total lease liability	$	4,531	$	5,467

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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	$	361	$	147	$	508
2026		1,220		441		1,661
2027		845		348		1,193
2028		726		18		744
2029 and thereafter		1,089		—		1,089
Total lease payments		4,241		954		5,195
Less: interest		582		82		664
Present value of lease liabilities	$	3,659	$	872	$	4,531

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	3.24		4.00
Vehicles	0.40		0.07
Office equipment	—		—
Weighted average discount rate:
Office and warehouse space	5.51	%	5.59	%
Vehicles	1.56	%	0.98	%
Office equipment	—	%	0.04	%

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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	$	9,635	$	13,845
Accrued capital expenditures		2,289		5,191
Accrued general and administrative expense		7,299		6,281
Accrued production and ad valorem tax		3,128		2,827
Accrued commitment fee and other expense		2,285		2,395
Operating lease liability		1,546		1,784
Asset retirement obligations		1,377		1,377
Accrued interest payable		207		292
Accrued liability - pipeline incident		—		5,534
Accrued current income tax payable		367		116
Other		1,565		3,771
Accrued liabilities	$	29,698	$	43,413

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	$	26,462	$	28,505
Insurance receivable - pipeline incident		388		4,722
Joint interest owners and other		8,172		8,214
Total accounts receivable		35,022		41,441
Less: allowance for doubtful accounts		(1,815)		(1,728)
Total accounts receivable, net	$	33,207	$	39,713

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	$	7,368	$	9,162
Cash paid for taxes		130		1,040

Noncash investing and financing activities:
Increase (decrease) in capital expenditures in payables and accrued liabilities		(2,903)		(1,323)

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 14. Related Party Transactions

Related Party Agreements

There have been no transactions between the Company and any related person in which the related person had a direct or indirect material interest for the three and nine months ended September 30, 2025 and 2024.

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 one reportable segment.

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	$	66,396	$	69,858	$	206,807	$	225,660
Less:
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
Other segment items		42,858		3,664		89,015		67,937
Net income (loss)	$	(20,966)	$	22,652	$	(20,443)	$	20,375

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.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 no environmental reserves recorded in its Unaudited Condensed Consolidated Balance Sheet.

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 $800,000 as payment for certain of the Acquired Companies’ expenses. The Company and the Acquired Companies also agreed to release each other from certain claims and liabilities arising out of or related to the Merger Agreement or the transactions contemplated therein or thereby. The Company incurred professional fees and expenses of approximately $3.5 million in connection with the Contemplated Mergers and the Termination.

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 $0.4 million and $4.7 million, respectively. Excluding the costs associated with the resolution of the federal and state matters discussed in the 2024 Form 10-K, for the nine months ended September 30, 2025, the Company incurred legal fees, loss load and other non-reimbursable expenses of $0.6 million that are classified as “Pipeline Incident Loss” on the Company’s Unaudited Condensed Consolidated Statements of Operations. For more information, please see the 2024 Form 10-K.

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 $4.3 million. As of September 30, 2025, the account balance included in restricted investments was approximately $4.6 million.

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 $161.3 million of A-rated surety bonds.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

In December 2021, the Company entered into two escrow funding agreements with its surety providers to fund interest-bearing escrow accounts on a quarterly basis to reimburse and indemnify the surety providers for any claims arising under the surety bonds related to the decommissioning of our Beta LLC properties. In March 2024, the Company amended one of the escrow funding agreements to decrease the amount funded from $14.8 million per year to $8.0 million per year. There were no changes made to the second escrow agreement. The obligation for these agreements ceases when the total aggregate value of the escrow accounts reaches $172.6 million.

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	$	131,168	$	2,000	$	8,000	$	8,000	$	8,000	$	8,000	$	97,168
State escrow fund payments		8,366		258		1,034		1,034		1,034		1,034		3,972
Total sinking fund payments	$	139,534	$	2,258	$	9,034	$	9,034	$	9,034	$	9,034	$	101,140

(1)	The remaining payments will be made during the years 2030 through 2042.

As of September 30, 2025, the Company has funded $33.1 million into the escrow accounts which is reflected in “Restricted investments” on the Unaudited Condensed Consolidated Balance Sheet.

Note 17. Income Taxes

The Company’s current income tax benefit (expense) was $0.1 million and ($0.4) million for the three and nine months ended September 30, 2025. The Company’s current income tax benefit (expense) was ($0.4) million and ($2.4) million for the three and nine months ended September 30, 2024, respectively.

The Company’s deferred income tax benefit (expense) was $9.2 million and $9.3 million for the three and nine months ended September 30, 2025, respectively. The Company’s deferred income tax benefit (expense) was ($5.7) million and ($3.1) million for the three and nine months ended September 30, 2024, respectively.

The effective tax rates for the three and nine months ended September 30, 2025 were 30.8% and 30.5%, respectively. The effective tax rates for the three and nine months ended September 30, 2024 were both 21.1%. The difference between the statutory U.S. federal income tax rate of 21% and the effective tax rate for the three and nine months ended September 30, 2025 was primarily attributable to increased estimated marginal well production credits and higher book losses for 2025. Both items represent negative income drivers and moved in the same direction, resulting in an effective tax rate that exceeded the statutory rate. The difference between the statutory U.S. federal income tax rate of 21% and the effective tax rate for the three and nine months ended September 30, 2024 was caused by higher state taxes, partially offset by marginal well tax credits pursuant to Section 45I of the Internal Revenue Code and a windfall tax benefit from stock compensation.

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.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 $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.

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.

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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

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EQV Purchase and Sale Agreement

Revolution Purchase and Sale Agreement

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.

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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

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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.

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(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.

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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.

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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;

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●

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.

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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.

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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.

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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.

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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.

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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

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(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.

None.

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ITEM 6.EXHIBITS.

Exhibit Number		Description
2.1	—	Agreement and Plan of Merger, dated January 14, 2025, by and among Amplify Energy Corp., Amplify DJ Operating LLC, Alpha PRB Operating LLC, North Peak Oil & Gas, LLC, Century Oil and Gas Sub-Holdings, LLC, Juniper Capital Advisors, L.P. and the Specified Company Entities signatories thereto (incorporated by reference to Exhibit 2.1 to the Company’s Current Report on Form 8-K (File No. 001-35512) filed on January 15, 2025).

2.2	—	Amendment No.1 to Agreement and Plan of Merger, dated as of April 14, 2025, by and among Amplify Energy Corp., Amplify Operating LLC, Amplify PRB Operating LLC, North Peak Oil & Gas, LLC, Century Oil and Gas Sub-Holdings, LLC, Juniper Capital Advisors, L.P. and the Specified Company Entities signatories thereto (incorporated by reference to Exhibit 2.1 to the Company’s Current Report on Form 8-K (File No. 001-35512) filed on April 15, 2025).

2.3+	—	Purchase and Sale Agreement, dated July 1, 2025, by and between Amplify Energy Operating LLC and Murphy Exploration & Production Company – USA (incorporated by reference to Exhibit 2.1 of the Company’s Current Report on Form 8-K (File No. 001-35512) filed on July 1, 2025).

2.4+	—	Purchase and Sale Agreement, dated October 28, 2025, among Amplify Energy Operating LLC, Magnify Energy Services LLC and EQV Alpha LLC (incorporated by reference to Exhibit 2.1 of the Company’s Current Report on Form 8-K (File No. 001-35512) filed on October 29, 2025).

2.5+	—	Purchase and Sale Agreement, dated November 4, 2025, among Amplify Oklahoma Operating LLC, Magnify Energy Services LLC, Amplify Energy Operating LLC and Revolution Resources III, LLC (incorporated by reference to Exhibit 2.1 of the Company’s Current Report on Form 8-K (File No. 001-35512) filed on November 5, 2025).

3.1	—	Second Amended and Restated Certificate of Incorporation of Midstates Petroleum Company, Inc. (filed as Exhibit 3.1 to the Company’s Registration Statement on Form 8-A filed on October 21, 2016, and incorporated herein by reference).

3.2	—	Certificate of Amendment to the Second Amended and Restated Certificate of Incorporation of Midstates Petroleum Company, Inc., dated August 6, 2019 (incorporated by reference to Exhibit 3.1 of the Company’s Current Report on Form 8-K (File No. 001-35512) filed on August 6, 2019).

3.3	—	Third Amended and Restated Bylaws of Amplify Energy Corp. (incorporated by reference to Exhibit 3.3 of the Company’s Quarterly Report on Form 10-Q (File No. 001-35512) filed on November 15, 2021).

10.1	—	Transition and Separation Agreement, dated as of July 22, 2025, by and among Martyn Willsher, Amplify Energy Corp. and Amplify Energy Services LLC (incorporated by reference to Exhibit 10.4 of the Company’s Quarterly Report on Form 10-Q (File No. 001-35512) filed on August 6, 2025).

10.2	—	PRSU Award Agreement, dated as of July 22, 2025, by and between Daniel Furbee and Amplify Energy Corp. (incorporated by reference to Exhibit 10.5 of the Company’s Quarterly Report on Form 10-Q (File No. 001-35512) filed on August 6, 2025).

31.1*	—	Certification of Chief Executive Officer Pursuant to Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934.

31.2*	—	Certification of Chief Financial Officer Pursuant to Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934.

32.1**	—	Certifications of Chief Executive Officer and Chief Financial Officer pursuant to 18. U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

101.INS*	—	Inline XBRL Instance Document

101.SCH*	—	Inline XBRL Schema Document

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Exhibit Number		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.

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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