SEC Form 10-Q filed by Amplify Energy Corp.

5/8/24 4:28:23 PM ET

$AMPY

Oil & Gas Production

Energy

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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 March 31, 2024


☐	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

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

Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Sections 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court. þ Yes ☐ No

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 April 30, 2024, the registrant had 39,612,030 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 March 31, 2024 and December 31, 2023	8
	Unaudited Condensed Consolidated Statements of Operations for the Three Months Ended March 31, 2024 and 2023	9
	Unaudited Condensed Consolidated Statements of Cash Flows for the Three Months Ended March 31, 2024 and 2023	10
	Unaudited Condensed Consolidated Statements of Equity (Deficit) for the Three Months Ended March 31, 2024 and 2023	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 – Fair Value Measurements of Financial Instruments	13
	Note 5 – Risk Management and Derivative Instruments	15
	Note 6 – Asset Retirement Obligations	17
	Note 7 – Long-Term Debt	18
	Note 8 – Equity	19
	Note 9 – Earnings (Loss) per Share	20
	Note 10 – Long-Term Incentive Plans	20
	Note 11 – Leases	23
	Note 12 – Supplemental Disclosures to the Unaudited Condensed Consolidated Balance Sheets and Unaudited Condensed Consolidated Statements of Cash Flows	25
	Note 13 – Related Party Transactions	26
	Note 14 – Commitments and Contingencies	26
	Note 15 – Income Taxes	27
	Note 16 – Beta Pipeline Incident	27
	Note 17 – Subsequent Event	29

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	30
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	39
Item 4.	Controls and Procedures	40

PART II—OTHER INFORMATION
Item 1.	Legal Proceedings	41
Item 1A.	Risk Factors	41
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	41
Item 3.	Defaults Upon Senior Securities	41
Item 4.	Mine Safety Disclosures	41
Item 5.	Other Information	41
Item 6.	Exhibits	42

Signatures		43

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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.

ICE: Inter-Continental Exchange.

MBbl: One thousand Bbls.

MBbls/d: One thousand Bbls per day.

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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;

●	“Legacy Amplify” refers to Amplify Energy Holdings LLC (f/k/a Amplify Energy Corp.), the successor reporting company of Memorial Production Partners LP; 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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ongoing impact of the oil incident that occurred off the coast of Southern California resulting from the Company’s pipeline operations (the “Pipeline”) at the Beta Field (the “Incident”);

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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, 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 satisfy debt obligations;

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risks related to the Incident and the ongoing impact to the Company;

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volatility in the prices for oil, natural gas and NGLs;

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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 Russian invasion of Ukraine, the Israel-Hamas war and the potential destabilizing effect such conflict may pose for the European continent 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;

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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, 2023 filed with the SEC on March 7, 2024 (“2023 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)


	March 31,		December 31,
	2024		2023
ASSETS
Current assets:
Cash and cash equivalents	$	2,989	$	20,746
Accounts receivable, net (see Note 12)		36,540		39,096
Short-term derivative instruments		4,429		17,669
Prepaid expenses and other current assets		18,366		20,672
Total current assets		62,324		98,183
Property and equipment, at cost:
Oil and natural gas properties, successful efforts method		891,407		873,478
Support equipment and facilities		150,211		149,069
Other		11,038		10,359
Accumulated depreciation, depletion and amortization		(694,405)		(686,165)
Property and equipment, net		358,251		346,741
Long-term derivative instruments		1,778		9,405
Restricted investments		22,392		19,935
Operating lease - long term right-of-use asset		5,407		5,756
Deferred tax asset		258,498		253,796
Other long-term assets		3,554		3,858
Total assets	$	712,204	$	737,674

LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	21,723	$	23,616
Revenues payable		20,809		21,944
Accrued liabilities (see Note 12)		36,776		50,871
Total current liabilities		79,308		96,431
Long-term debt (see Note 7)		115,000		115,000
Asset retirement obligations		124,062		122,001
Operating lease liability		4,704		5,090
Other long-term liabilities		8,115		8,116
Total liabilities		331,189		346,638
Commitments and contingencies (see Note 14)
Stockholders' equity (deficit):
Preferred stock, $0.01 par value: 50,000,000 shares authorized; no shares issued and outstanding at March 31, 2024 and December 31, 2023		—		—
Common stock, $0.01 par value: 250,000,000 shares authorized; 39,612,030 and 39,147,205 shares issued and outstanding at March 31, 2024 and December 31, 2023, respectively		398		393
Additional paid-in capital		434,465		435,095
Accumulated deficit		(53,848)		(44,452)
Total stockholders' equity (deficit)		381,015		391,036
Total liabilities and equity	$	712,204	$	737,674

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
	March 31,
	2024		2023
Revenues:
Oil and natural gas sales	$	75,322	$	66,284
Other revenues		977		13,586
Total revenues		76,299		79,870

Costs and expenses:
Lease operating expense		38,284		32,960
Gathering, processing and transportation		4,774		5,602
Taxes other than income		4,911		5,293
Depreciation, depletion and amortization		8,239		5,808
General and administrative expense		9,800		8,514
Accretion of asset retirement obligations		2,061		1,942
Loss (gain) on commodity derivative instruments		16,564		(15,159)
Pipeline incident loss		707		8,279
Other, net		41		26
Total costs and expenses		85,381		53,265
Operating income (loss)		(9,082)		26,605
Other income (expense):
Interest expense, net		(3,527)		(5,737)
Litigation settlement (See Note 16)		—		84,875
Other income (expense)		(95)		73
Total other income (expense)		(3,622)		79,211
Income (loss) before income taxes		(12,704)		105,816
Income tax (expense) benefit - current		(1,395)		(12,527)
Income tax (expense) benefit - deferred		4,703		259,470
Net income (loss)	$	(9,396)	$	352,759

Allocation of net income (loss) to:
Net income (loss) available to common stockholders	$	(9,396)	$	336,373
Net income (loss) allocated to participating securities		—		16,386
Net income (loss) available to Amplify Energy Corp.	$	(9,396)	$	352,759

Earnings (loss) per share: (See Note 9)
Basic and diluted earnings (loss) per share	$	(0.24)	$	8.69
Weighted average common shares outstanding:
Basic and diluted		39,410		38,694

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 Three Months Ended
	March 31,
	2024		2023
Cash flows from operating activities:
Net income (loss)	$	(9,396)	$	352,759
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization		8,239		5,808
Loss (gain) on derivative instruments		16,564		(15,159)
Cash settlements (paid) received on expired derivative instruments		4,303		(2,709)
Deferred income tax expense (benefit)		(4,703)		(259,470)
Accretion of asset retirement obligations		2,061		1,942
Share-based compensation (see Note 10)		1,531		941
Amortization and write-off of deferred financing costs		304		461
Bad debt expense		26		—
Changes in operating assets and liabilities:
Accounts receivable		2,530		14,476
Prepaid expenses and other assets		2,306		2,450
Payables and accrued liabilities		(16,053)		(10,940)
Other		—		(246)
Net cash provided by operating activities		7,712		90,313
Cash flows from investing activities:
Additions to oil and gas properties		(20,589)		(8,187)
Additions to other property and equipment		(679)		(150)
Additions to restricted investments		(2,456)		(2,080)
Net cash used in investing activities		(23,724)		(10,417)
Cash flows from financing activities:
Advances on Revolving Credit Facility		25,000		10,000
Payments on Revolving Credit Facility		(25,000)		(75,000)
Shares withheld for taxes		(1,745)		(2,141)
Net cash used in financing activities		(1,745)		(67,141)
Net change in cash and cash equivalents		(17,757)		12,755
Cash and cash equivalents, beginning of period		20,746		—
Cash and cash equivalents, end of period	$	2,989	$	12,755

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, 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


	Stockholders' Equity (Deficit)
			Additional		Accumulated
	Common		Paid-in		Earnings
	Stock		Capital		(Deficit)		Total
Balance at December 31, 2022	$	386	$	432,251	$	(437,202)	$	(4,565)
Net income (loss)		—		—		352,759		352,759
Share-based compensation expense		—		941		—		941
Shares withheld for taxes		—		(2,141)		—		(2,141)
Other		5		(5)		—		—
Balance at March 31, 2023	$	391	$	431,046	$	(84,443)	$	346,994

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 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 consist 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 2023 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.

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 2023 Form 10-K.

New Accounting Pronouncements

The Company has implemented all new accounting pronouncements that are in effect. These pronouncements did not have any material impact on the financial statements unless otherwise disclosed, and the Company does not believe that there are any other new accounting pronouncements that have been issued that might have a material impact on its financial position or results of operations.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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, (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.

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
	March 31,
	2024		2023

	(In thousands)
Revenues
Oil	$	57,422	$	38,816
NGLs		7,525		7,785
Natural gas		10,375		19,683
Oil and natural gas sales	$	75,322	$	66,284

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 $31.6 million at March 31, 2024 and $31.1 million at December 31, 2023.

Note 4. 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.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 March 31, 2024 and December 31, 2023. 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.

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 March 31, 2024 and December 31, 2023 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 March 31, 2024 and December 31, 2023 for each of the fair value hierarchy levels:


	Fair Value Measurements at March 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	$	—	$	25,306	$	—	$	25,306
Interest rate derivatives		—		—		—		—
Total assets	$	—	$	25,306	$	—	$	25,306

Liabilities:
Commodity derivatives	$	—	$	19,099	$	—	$	19,099
Interest rate derivatives		—		—		—		—
Total liabilities	$	—	$	19,099	$	—	$	19,099


	Fair Value Measurements at December 31, 2023
					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	$	—	$	39,439	$	—	$	39,439
Interest rate derivatives		—		—		—		—
Total assets	$	—	$	39,439	$	—	$	39,439

Liabilities:
Commodity derivatives	$	—	$	12,365	$	—	$	12,365
Interest rate derivatives		—		—		—		—
Total liabilities	$	—	$	12,365	$	—	$	12,365

See Note 5 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 6 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).

●

No impairment expense was recorded on proved oil and natural gas properties during the three months ended March 31, 2024 and 2023.

Note 5. 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 $7.6 million against amounts outstanding under our Revolving Credit Facility at March 31, 2024. See Note 7 for additional information regarding the Company’s Revolving Credit Facility.

Commodity Derivatives

The Company may use a combination of commodity derivatives (e.g., floating-for-fixed swaps, put options, costless collars and three-way collars) to manage exposure to commodity price volatility. The Company recognizes all derivative instruments at fair value.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

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 March 31, 2024, the Company had the following open commodity positions:



	2024		2025		2026
Natural Gas Derivative Contracts:
Fixed price swap contracts:
Average monthly volume (MMBtu)		716,667		675,000		291,667
Weighted-average fixed price	$	3.72	$	3.74	$	3.72

Collar contracts:
Two-way collars
Average monthly volume (MMBtu)		544,444		500,000		291,667
Weighted-average floor price	$	3.46	$	3.50	$	3.50
Weighted-average ceiling price	$	4.15	$	4.10	$	4.10

Crude Oil Derivative Contracts:
Fixed price swap contracts:
Average monthly volume (Bbls)		85,889		53,000		30,917
Weighted-average fixed price	$	74.04	$	70.68	$	70.68

Collar contracts:
Two-way collars
Average monthly volume (Bbls)		102,000		59,500		—
Weighted-average floor price	$	70.00	$	70.00	$	—
Weighted-average ceiling price	$	80.20	$	80.20	$	—

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 March 31, 2024 and December 31, 2023. 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.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS


		Asset		Liability		Asset		Liability
		Derivatives		Derivatives		Derivatives		Derivatives
		March 31,		March 31,		December 31,		December 31,
Type	Balance Sheet Location	2024		2024		2023		2023

		(In thousands)
Commodity contracts	Short-term derivative instruments	$	16,069	$	11,640	$	21,657	$	3,988
Interest rate swaps	Short-term derivative instruments		—		—		—		—
Gross fair value			16,069		11,640		21,657		3,988
Netting arrangements			(11,640)		(11,640)		(3,988)		(3,988)
Net recorded fair value	Short-term derivative instruments	$	4,429	$	—	$	17,669	$	—

Commodity contracts	Long-term derivative instruments	$	9,237	$	7,459	$	17,782	$	8,377
Interest rate swaps	Long-term derivative instruments		—		—		—		—
Gross fair value			9,237		7,459		17,782		8,377
Netting arrangements			(7,459)		(7,459)		(8,377)		(8,377)
Net recorded fair value	Long-term derivative instruments	$	1,778	$	—	$	9,405	$	—

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
	Statements of	December 31,
	Operations Location	2024		2023
Commodity derivative contracts	Loss (gain) on commodity derivatives	$	16,564	$	(15,159)

Note 6. 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 three months ended March 31, 2024 (in thousands):


Asset retirement obligations at beginning of period	$	123,494
Liabilities added from acquisition or drilling		—
Liabilities settled		—
Liabilities removed upon sale of wells		—
Accretion expense		2,061
Revision of estimates		—
Asset retirement obligation at end of period		125,555
Less: Current portion		1,493
Asset retirement obligations - long-term portion	$	124,062

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 7. Long-Term Debt

The following table presents the Company’s consolidated debt obligations at the dates indicated:


	March 31,		December 31,
	2024		2023

	(In thousands)
Revolving Credit Facility (1)	$	115,000	$	115,000
Total long-term debt	$	115,000	$	115,000

(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, and is a replacement in full of the prior Revolving Credit Facility by and among OLLC, Acquisitionco, the guarantors party thereto, the lenders party thereto and KeyBank National Association, as the administrative agent (as amended, the “Prior Revolving Credit Facility”).

The aggregate principal amount of loans outstanding under the Revolving Credit Facility as of March 31, 2024, was $115.0 million. The borrowing base under the facility is $150.0 million with elected commitments of $135.0 million, and, consistent with the Prior Revolving Credit Facility, the Revolving Credit Facility borrowing base will be subject to redetermination on at least a semi-annual basis, primarily based on a reserve engineering report.

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, in each case commencing with the fiscal quarter ending December 31, 2023;

●

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.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

As noted above, the Company is required to maintain a minimum current ratio of 1.00 to 1.00, which is measured on the last day of each quarter. On March 31, 2024, the Company’s current ratio was 0.98 to 1.00. On May 2, 2024, the Company received a letter agreement from its lenders waiving any default or event of default as a result of such noncompliance related to the minimum current ratio requirement for the quarter ended March 31, 2024. As a result, the Company was in compliance with all financial covenants as of March 31, 2024.

Subsequent event. On May 2, 2024, OLLC completed its spring 2024 borrowing base redetermination, which reaffirmed the borrowing base of $150.0 million with elected commitments of $135.0 million. The next redetermination is expected in the fourth quarter of 2024.

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
	March 31,
	2024		2023
Revolving Credit Facility	9.37	%	9.73	%

Letters of Credit

At March 31, 2024, 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 $4.1 million at March 31, 2024.

Note 8. Equity

Common Stock

The Company’s authorized capital stock includes 250,000,000 shares of common stock, $0.01 par value per share. The following is a summary of the changes in the Company’s common stock issued for the three months ended March 31, 2024:


		Common Stock
Balance, December 31, 2023		39,147,205
Issuance of common stock		—
Restricted stock units vested		711,728
Shares withheld for taxes (1)		(246,903)
Balance, March 31, 2024		39,612,030

(1)

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

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 9. 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
	March 31,
	2024		2023
Net income (loss)	$	(9,396)	$	352,759
Less: Net income allocated to participating securities		—		16,386
Basic and diluted earnings available to common stockholders	$	(9,396)	$	336,373

Common shares:
Common shares outstanding — basic		39,410		38,694
Dilutive effect of potential common shares		—		—
Common shares outstanding — diluted		39,410		38,694

Net earnings (loss) per share:
Basic	$	(0.24)	$	8.69
Diluted	$	(0.24)	$	8.69

Note 10. Long-Term Incentive Plans

In May 2021, the shareholders approved a new Equity Incentive Plan (“EIP”) which replaced the Legacy Amplify Management Incentive Plan (the “Legacy Amplify MIP”). As such, no further awards have been granted under the Legacy Amplify MIP.

In April 2024, the board of directors of the Company (the “Board”) approved and adopted the Amplify Energy Corp. 2024 Equity Incentive Plan (the “2024 Plan”), subject to stockholder approval at the Company’s Annual Meeting of Stockholders to be held on May 15, 2024.

EIP awards are, and, under the Legacy Amplify MIP, were, 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 under the EIP or Legacy Amplify MIP is expired, 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 EIP. The EIP is administered by the Board.

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 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. 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.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The Company granted contingent cash-settlement awards in the form of TSUs (the “Contingent TSUs”) under the EIP in February 2024 that will be settled in shares of stock, subject to stockholder approval of the 2024 Plan. In the event the Company’s stockholders do not approve the 2024 Plan, the Contingent TSUs will be settled in cash pursuant to the terms of the applicable award agreement. The Contingent TSUs are accounted for as liability-classified awards and vest in substantially equal installments over a three-year period.

The unrecognized cost associated with the TSUs was $7.8 million at March 31, 2024. The Company expects to recognize the unrecognized compensation cost for these awards over a weighted average period of approximately 2.3 years. Of the unrecognized share-based compensation expense for TSUs, $4.1 million relates to liability-classified awards and will be subsequently remeasured at each reporting period. The Company recognized $0.3 million in liability-classified share-based compensation expense at March 31, 2024 for the Contingent TSUs.

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, 2023	1,331,456	$	5.77
Granted ⁽²⁾	709,402	$	6.09
Forfeited	(5,922)	$	5.04
Vested	(604,684)	$	4.95
TSUs outstanding at March 31, 2024 ⁽³⁾	1,430,252	$	6.28

(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 three months ended March 31, 2024 was $4.3 million based on a grant-date market price of $6.09 per share.

(3)

As of March 31, 2024, 709,402 of the unvested TSUs were accounted for as liability awards in “accrued liabilities” in the Unaudited Condensed Consolidated Balance sheet.

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 zero 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 2022 and 2023 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 2022 awards is January 1, 2022 through December 31, 2024. The three-year performance period for the 2023 awards is January 1, 2023 through December 31, 2025.

The Company granted contingent cash-settlement awards in the form of PSUs (the “Contingent PSUs”) in February 2024 that will be settled in shares of stock, subject to stockholder approval of the 2024 Plan. In the event the Company’s stockholders do not approve the 2024 Plan, the Contingent PSUs will be settled in cash pursuant to the terms of the applicable award agreement. The Contingent PSUs are accounted for as liability-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 Contingent PSUs is January 1, 2024 through December 31, 2026.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Compensation costs related to the awards are recorded as general and administrative expense. The unrecognized cost associated with these awards was $4.3 million at March 31, 2024. The Company expects to recognize the unrecognized compensation cost for these awards over a weighted-average period of approximately 2.3 years. Of the unrecognized share-based compensation expense, $2.3 million relates to liability-classified awards and will be subsequently remeasured at each reporting period. The Company recognized $0.2 million in liability-classified share-based compensation expense at March 31, 2024 for the Contingent PSUs.

The below table reflects the ranges for the assumptions used in the Monte Carlo model for the Contingent PSU awards:


	February 2024
Expected volatility	75.8	%
Dividend yield	0.00	%
Risk-free interest rate	4.19	%

The following table summarizes information regarding the PSUs activity for the period presented:


		Weighted-
		Average Grant-
	Number of	Date Fair Value
	Units	per Unit (1)
PSUs outstanding at December 31, 2023	402,701	$	9.31
Granted ⁽²⁾	312,843	$	8.28
Forfeited	—	$	—
Vested	(107,044)	$	2.63
PSUs outstanding at March 31, 2024 ⁽³⁾	608,500	$	9.95

(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 three months ended March 31, 2024 was $2.6 million based on a calculated fair value price ranging from $2.63 to $9.18 per share.

(3)

As of March 31, 2024, 269,897 of the unvested PSUs were accounted for as liability awards in “accrued liabilities” in the Unaudited Condensed Consolidated Balance sheet.

Compensation Expense

The following table summarizes the amount of recognized compensation expense associated with the EIP, which are reflected in the accompanying Unaudited Condensed Consolidated Statements of Operations for the periods presented (in thousands):


	For the Three Months Ended
	March 31,
	2024		2023
Share-based compensation costs
Share-based compensation - equity awards	$	1,120	$	941
Share-based compensation - liability awards		411		—
	$	1,531	$	941

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 11. 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 March 31, 2024, 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 three months ended March 31, 2024 and 2023, the Company recognized approximately $0.5 million and $0.5 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 Three Months Ended
	March 31,
	2024		2023

	(In thousands)
Non-cash amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	349	$	288

The following table presents the Company’s right-of-use assets and lease liabilities for the period presented:


	March 31,		December 31,
	2024		2023

	(In thousands)
Right-of-use asset	$	5,407	$	5,756

Lease liabilities:
Current lease liability		1,740		1,737
Long-term lease liability		4,704		5,090
Total lease liability	$	6,444	$	6,827

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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
2024	$	1,066	$	568	$	1,634
2025		1,421		573		1,994
2026		1,200		87		1,287
2027		832		4		836
2028 and thereafter		1,790		—		1,790
Total lease payments		6,309		1,232		7,541
Less: interest		1,014		83		1,097
Present value of lease liabilities	$	5,295	$	1,149	$	6,444

The weighted average remaining lease terms and discount rate for all of the Company’s operating leases for the period presented:


	March 31,
	2024		2023
Weighted average remaining lease term (years):
Office and warehouse space	4.17		4.60
Vehicles	0.36		0.37
Office equipment	0.01		0.03
Weighted average discount rate:
Office and warehouse space	5.30	%	4.90	%
Vehicles	1.19	%	1.33	%
Office equipment	0.06	%	0.10	%

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 12. 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):


	March 31,		December 31,
	2024		2023
Accrued lease operating expense	$	11,440	$	14,239
Accrued liability - pipeline incident		2,670		9,331
Accrued liability - current portion of pipeline incident settlement		2,000		2,000
Accrued capital expenditures		6,500		8,019
Accrued general and administrative expense		2,159		5,335
Accrued production and ad valorem tax		3,659		3,502
Accrued commitment fee and other expense		2,478		2,626
Operating lease liability		1,740		1,737
Asset retirement obligations		1,493		1,493
Accrued current income tax payable		1,395		—
Accrued interest payable		284		1,792
Other		958		797
Accrued liabilities	$	36,776	$	50,871

Accounts Receivable

Accounts receivable consisted of the following at the dates indicated (in thousands):


	March 31,		December 31,
	2024		2023
Oil and natural gas receivables	$	31,570	$	31,131
Insurance receivable - pipeline incident		1,437		3,571
Joint interest owners and other		5,207		6,042
Total accounts receivable		38,214		40,744
Less: allowance for doubtful accounts		(1,674)		(1,648)
Total accounts receivable, net	$	36,540	$	39,096

Supplemental Cash Flows

Supplemental cash flows for the periods presented (in thousands):


	For the Three Months Ended
	March 31,
	2024		2023
Supplemental cash flows:
Cash paid for interest, net of amounts capitalized	$	3,920	$	4,502

Noncash investing and financing activities:
Increase (decrease) in capital expenditures in payables and accrued liabilities		(1,520)		1,966

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 13. 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 months ended March 31, 2024 and 2023.

Note 14. 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.

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 March 31, 2024 and December 31, 2023, the Company had no environmental reserves recorded in its Unaudited Condensed Consolidated Balance Sheet.

Beta Pipeline Incident

Please refer to “Note 16. Beta Pipeline Incident” for details.

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 March 31, 2024, the account balance included in restricted investments was approximately $4.5 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.

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.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The below table outlines the updated funding commitment for these agreements at March 31, 2024 (in thousands):


	Payment Due by Period
Funding commitment	Total		Remaining 2024		2025		2026		2027		2028		Thereafter
Federal escrow fund payments	$	145,550	$	6,000	$	8,000	$	8,000	$	8,000	$	8,000	$	107,550
State escrow fund payments		10,079		775		1,034		1,034		1,034		1,034		5,168
Total sinking fund payments	$	155,629	$	6,775	$	9,034	$	9,034	$	9,034	$	9,034	$	112,718

As of March 31, 2024, the Company has funded $17.6 million into the escrow accounts which is reflected in “Restricted investments” on the Unaudited Condensed Consolidated Balance Sheet.

Note 15. Income Taxes

The Company’s current income tax expense was $1.4 million and $12.5 million for the three months ended March 31, 2024 and 2023, respectively. The Company’s deferred income tax benefit was $4.7 million and $259.5 million for the three months ended March 31, 2024 and 2023, respectively. The effective tax rates for the three months ended March 31, 2024 and 2023 were 26.0% and (233.4%), respectively. The item that had the most significant impact on the difference between the statutory U.S. federal income tax rate of 21% and the effective tax rate for the three months ended March 31, 2024 was the weighted state accrual rate. The items that had the most significant impact on the difference between the statutory U.S. federal income tax rate of 21% and the effective tax rate for the three months ended March 31, 2023 was the release of the valuation allowances.

Net deferred tax assets relate to net operating loss carryforwards, interest expense carryforwards, tax credits, and other temporary differences expected to produce tax deductions in future periods. The realization of these assets depends on recognition of sufficient future taxable income in specific federal and state tax jurisdictions in which those temporary differences are deductible. In assessing the need for a valuation allowance on its deferred tax assets, the Company considers whether it is more likely than not that all of its deferred tax assets will be realized. On December 31, 2023, the Company release all of its valuation allowance of $284.9 million, which increased net deferred tax assets as of such date.

Note 16. Beta Pipeline Incident

On October 2, 2021, contractors operating under the direction of Beta LLC observed an oil sheen on the water approximately four miles off the coast of Newport Beach, California. Beta LLC platform personnel were notified and promptly initiated the Company’s Oil Spill Response Plan. On October 3, 2021, a Unified Command, consisting of the Company, the U.S. Coast Guard and California Department of Fish and Wildlife’s Office of Spill Prevention and Response, was established to respond to the Incident. Reports from the Unified Command’s contracted commercial divers and Remotely Operated Vehicle footage indicated that a 4,000-foot section of the Company’s pipeline had been displaced and that the pipeline had a 13-inch split, running parallel to the pipe, releasing approximately 588 barrels of oil.

All operations were suspended and the pipeline was shut-in pending the Company’s receipt of the required regulatory approvals to restart operations, including but not limited to, approval of a written restart plan from the Pipeline and Hazardous Materials Safety Administration (“PHMSA”), Office of Pipeline Safety. On April 10, 2023, the Company announced that it received the required approvals from federal regulatory agencies to restart operations at the Beta Field. Since such date, the pipeline has been operated in accordance with the restart procedures that were reviewed and approved by PHMSA.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

On December 15, 2021, a federal grand jury in the Central District of California returned a federal criminal indictment against the Company, Beta LLC, and San Pedro Bay Pipeline Company in connection with the Incident. As previously disclosed, state authorities were conducting parallel criminal investigations. The Company reached court-approved agreements to resolve all criminal matters stemming from the Incident. As part of the resolution with the United States, the Company agreed to plead guilty to one count of misdemeanor negligent discharge of oil in violation of the Clean Water Act, and, agreed to pay a fine of approximately $7.1 million in installments over a period of three years, serve a term of four years’ probation and reimburse governmental agencies approximately $5.8 million for their response to this event. Additionally, as part of the resolution with the state of California, the Company agreed to enter a plea of No Contest to six misdemeanor charges, and, as a result, paid a fine in the amount of $4.9 million to be distributed among the state of California, including the State’s Fish and Game Preservation Fund, and Orange County, agreed to serve a one-year term of probation and agreed to certain compliance enhancements to its operations.

The Company is currently subject to a number of ongoing investigations related to the Incident by certain federal and state agencies and may be subject to new investigations and proceedings in the future, the results of which may have a material impact on the Company’s business and results of operations and could put pressure on its liquidity position going forward. With respect to PHMSA’s investigation, on April 6, 2023, PHMSA provided the Company notice of PHMSA’s positions regarding “probable violations of the Pipeline Safety Regulations” in connection with the Incident. The Company has responded to the notice and is conferring with PHMSA regarding a resolution. Amplify continues to comply with all regulatory requirements and investigations. The outcomes of these investigations and the nature of any remedies pursued will depend on the discretion of the relevant authorities and may result in regulatory or other enforcement actions, as well as civil liability.

The Company, Beta LLC, and San Pedro Bay Pipeline Company were named as defendants in a consolidated putative class action in the United States District Court for the Central District of California, asserting claims against the Company, Beta LLC, San Pedro Bay Pipeline Company, among others.

On August 25, 2022, the Company reached an agreement in principle with plaintiffs in the class action to resolve all civil claims against it and its subsidiaries. The settlement of $50.0 million, which also includes certain injunctive relief, has been and will continue to be funded under the Company’s insurance policies. The Court granted final approval of the settlement on April 24, 2023. Separately, on March 1, 2023, the Company announced that the vessels that struck and damaged the pipeline and their respective owners and operators agreed to pay the Company $96.5 million in a settlement. This settlement resolved Amplify’s affirmative claims related to the Incident, and as such, Amplify dismissed its legal claims against those parties.

Under the Oil Pollution Act of 1990, 33 U.S.C. § 2701 et seq. (“OPA 90”), the Company’s pipeline was designated by the U.S. Coast Guard as the source of the oil discharge and therefore the Company is financially responsible for remediation and for certain costs and economic damages as provided for in OPA 90, as well as certain natural resource damages associated with the spill and certain costs determined by federal and state trustees engaged in a joint assessment of such natural resource damages. The Company is currently processing covered claims under OPA 90 as expeditiously as possible. In addition, the Natural Resource Damage Assessment remains ongoing and therefore the extent, timing and cost related to such assessment are difficult to project. While the Company anticipates insurance will reimburse it for expenses related to the Natural Resource Damage Assessment, any potentially uncovered expenses may be material and could impact the Company’s business and results of operations and could put pressure on its liquidity position going forward.

Based on presently enacted laws and regulations and currently available facts, the Company estimates that the total costs it has incurred or will incur with respect to the Incident to be approximately $190.0 million to $210.0 million. The range of total costs is based on the Company’s assumptions regarding (i) settlement of costs associated with certain vendors for response and remediation expenses, (ii) resolution of certain third-party claims, excluding claims with respect to losses, which are not probable or reasonably estimable, and (iii) future claims and lawsuits. While the Company believes it has accurately reflected all probable and reasonably estimable costs incurred in the Company’s Unaudited Consolidated Statements of Operations, these estimates are subject to uncertainties associated with the underlying assumptions. Accordingly, as the Company’s assumptions and estimates may change in future periods based on future events, the Company can provide no assurance that total costs will not materially change in future periods.

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AMPLIFY ENERGY CORP.

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The Company’s estimates do not include (i) the nature, extent and cost of future legal services that will be required in connection with all lawsuits, claims and other matters requiring legal or expert advice associated with the Incident, (ii) any lost revenue associated with the suspension of operations at Beta, (iii) any liabilities or costs, including regulatory costs, that are not reasonably estimable at this time or that relate to contingencies where the Company currently regards the likelihood of loss as being only reasonably possible or remote and (iv) the costs associated with the permanent repair of the pipeline and the restart of operations at Beta.

In accordance with customary insurance practice, the Company maintains insurance policies, including loss of production insurance, against many potential losses or liabilities arising from its operations, which, in addition to the settlement amount disclosed, have covered a material portion of aggregate costs associated with the Incident. However, the Company can provide no assurance that its coverage will continue to adequately protect it against liability from all potential consequences, damages and losses related to the Incident and such view and understanding is preliminary and subject to change.

On March 31, 2024, and December 31, 2023, the Company’s insurance receivables were $1.4 million and $3.6 million, respectively. Excluding the costs associated with the resolution of the federal and state matters discussed above, for the three months ended March 31, 2024, the Company incurred response and remediation expenses and legal fees of $0.7 million, which primarily relates to certain legal costs that are not expected to be recovered under an insurance policy and are classified as “Pipeline Incident Loss” on the Company’s Unaudited Condensed Consolidated Statements of Operations. For more information, please see our annual report on Form 10-K for the year ended December 31, 2023 filed with the SEC on March 7, 2024.

Note 17. Subsequent Events

Borrowing Base Redetermination

See Note 7 for additional information relating to the Company’s borrowing base redetermination.

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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 Annual Report on the Form 10-K for the year ended December 31, 2023 (“2023 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 consist 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 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 the Organization of the Petroleum Exporting Countries and other large producing nations; the Russia-Ukraine conflict; conflicts in the Middle East; 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. 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

Borrowing Base Redetermination

On May 2, 2024, OLLC completed its spring 2024 borrowing base redetermination, which reaffirmed the borrowing base of $150.0 million with elected commitments of $135.0 million. The next redetermination is expected in the fourth quarter of 2024.

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.

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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 2023 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 months ended March 31, 2024 and 2023 have been derived from our unaudited condensed consolidated financial statements. The comparability of the results of operations among the periods presented below is impacted by the Incident and suspension of operations at our Beta properties during 2023.

The following table summarizes certain of the results of operations for the periods indicated.


	For the Three Months Ended
	March 31,
	2024		2023
($ In thousands except per unit amounts)
Oil and natural gas sales	$	75,322	$	66,284
Other revenues		977		13,586
Lease operating expense		38,284		32,960
Gathering, processing and transportation		4,774		5,602
Taxes other than income		4,911		5,293
Depreciation, depletion and amortization		8,239		5,808
General and administrative expense		9,800		8,514
Loss (gain) on commodity derivative instruments		16,564		(15,159)
Pipeline incident loss		707		8,279
Interest expense, net		3,527		5,737
Litigation settlement		—		84,875
Income tax (expense) benefit - current		(1,395)		(12,527)
Income tax (expense) benefit - deferred		4,703		259,470
Net income (loss)		(9,396)		352,759

Oil and natural gas revenues:
Oil sales	$	57,422	$	38,816
NGL sales		7,525		7,785
Natural gas sales		10,375		19,683
Total oil and natural gas revenues	$	75,322	$	66,284

Production volumes:
Oil (MBbls)		786		535
NGLs (MBbls)		333		325
Natural gas (MMcf)		4,335		5,303
Total (MBoe)		1,842		1,745
Average net production (MBoe/d)		20.2		19.4

Average realized sales price (excluding commodity derivatives):
Oil (per Bbl)	$	72.98	$	72.52
NGL (per Bbl)		22.61		23.92
Natural gas (per Mcf)		2.39		3.71
Total (per Boe)	$	40.89	$	37.99

Average unit costs per Boe:
Lease operating expense	$	20.78	$	18.89
Gathering, processing and transportation		2.59		3.21
Taxes other than income		2.67		3.03
General and administrative expense		5.32		4.88
Depletion, depreciation and amortization		4.47		3.33

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For the Three Months Ended March 31, 2024 Compared to the Three Months Ended March 31, 2023

We reported a net loss of $9.4 million compared to net income of $352.8 million for the three months ended March 31, 2024 and 2023, respectively.

Oil, natural gas and NGL revenues were $75.3 million and $66.3 million for the three months ended March 31, 2024 and 2023, respectively. Average net production volumes were approximately 20.2 MBoe/d and 19.4 MBoe/d for the three months ended March 31, 2024 and 2023, respectively. The change in production volumes was primarily driven by Beta returning to production in April 2023. For the first quarter of 2023 Beta was offline. The average realized sales prices were $40.89 per Boe and $37.99 per Boe for the three months ended March 31, 2024 and 2023, respectively. The increase in oil, natural gas and NGL revenues and average realized sales price was primarily due to Beta returning to production in April 2023.

Other revenues were $1.0 million and $13.6 million for the three months ended March 31, 2024 and 2023, respectively. The decrease in other revenues was primarily related to our receipt of LOPI insurance proceeds of $13.5 million for the three months ended March 31, 2023. We have not received LOPI insurance proceeds since payments under the LOPI policy terminated on March 31, 2023.

Lease operating expenses were $38.3 million and $33.0 million for the three months ended March 31, 2024 and 2023, respectively. On a per Boe basis, lease operating expenses were $20.78 and $18.89 for the three months ended March 31, 2024 and 2023, respectively. The change in lease operating expense was primarily related to operating costs associated with Beta returning to production. During the first quarter of 2023, Beta was offline.

Gathering, processing and transportation expenses were $4.8 million and $5.6 million for the three months ended March 31, 2024 and 2023, respectively. On a per Boe basis, gathering, processing and transportation expenses were $2.59 and $3.21 for the three months ended March 31, 2024 and 2023, respectively. The change in gathering processing and transportation expense was primarily due to lower gas volumes and the expiration of minimum volume commitments for our Oklahoma properties.

Taxes other than income were $4.9 million and $5.3 million for the three months ended March 31, 2024 and 2023, respectively. On a per Boe basis, taxes other than income were $2.67 and $3.03 for the three months ended March 31, 2024 and 2023, respectively. The decrease was primarily related to a reduction in production taxes due to lower natural gas commodity prices.

DD&A expenses were $8.2 million and $5.8 million for the three months ended March 31, 2024 and 2023, respectively. The increase in DD&A expense was primarily driven by production at Beta. During the first quarter of 2023, Beta was offline.

General and administrative expenses were $9.8 million and $8.5 million for the three months ended March 31, 2024 and 2023, respectively. The change in general and administrative expenses was primarily related to (i) an increase of $0.6 million in stock compensation expense, (ii) an increase of $0.3 million in severance payments, (iii) and an increase of $0.4 million in office lease expense related to the early termination of our Oklahoma office lease.

Net loss on commodity derivative instruments of $16.6 million were recognized for the three months ended March 31, 2024, consisting of $20.8 million decrease in the fair value of open positions, partially offset by $4.3 million of cash settlements received on expired positions. Net gain on commodity derivative instruments of $15.2 million was recognized for the three months ended March 31, 2023, consisting of a $17.9 million increase in the fair value of open positions, partially offset by $2.7 million of cash settlements paid on expired positions.

Pipeline incident loss was $0.7 million and $8.3 million for the three months ended March 31, 2024 and 2023, 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.

Litigation settlement was $84.9 million for the three months ended March 31, 2023, related to the settlement with the shipping companies and the containerships whose anchors struck the Company’s pipeline. See additional information discussed in Note 16 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report. No litigation settlement was recorded for the three months ended March 31, 2024.

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Interest expense, net was $3.5 million and $5.7 million for the three months ended March 31, 2024 and 2023, respectively. The change in interest expense was primarily driven by lower outstanding borrowings, slightly lower interest rates and amortization of deferred issuance costs. In addition, in the first quarter of 2023, the Company wrote off $0.2 million in deferred issuance costs.

Average outstanding borrowings under our Revolving Credit Facility were $115.2 million and $192.4 million for the three months ended March 31, 2024 and 2023, respectively.

Current income tax expenses were $1.4 million and $12.5 million for the three months ended March 31, 2024 and 2023, respectively. See additional information discussed in Note 15 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report.

Deferred income tax benefits were $4.7 million and $259.5 million for the three months ended March 31, 2024 and 2023, respectively. Starting in the first quarter of 2023, we achieved three years of cumulative income which resulted in the release of the valuation allowance. See additional information discussed in Note 15 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report.

Adjusted EBITDA

We include in this report the non-GAAP financial measure of Adjusted EBITDA and provide our reconciliation of 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. 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;

●

Share-based compensation expenses;

●

Exploration costs;

●

Acquisition and divestiture related expenses;

●

Reorganization items, net;

●

Severance payments; and

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●

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 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) 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
	March 31,
	2024		2023

	(In thousands)
Net income (loss)	$	(9,396)	$	352,759
Interest expense, net		3,527		5,737
Income tax expense (benefit) - current		1,395		12,527
Income tax expense (benefit) - deferred		(4,703)		(259,470)
DD&A		8,239		5,808
Accretion of AROs		2,061		1,942
Losses (gains) on commodity derivative instruments		16,564		(15,159)
Cash settlements (paid) received on expired commodity derivative instruments		4,303		(2,709)
Pipeline incident loss		707		8,279
Litigation settlement		—		(84,875)
Share-based compensation expense		1,531		941
Exploration costs		41		26
Acquisition and divestiture related expenses		14		—
Bad debt expense		26		—
Other		592		—
Adjusted EBITDA	$	24,901	$	25,806

Reconciliation of Net Cash from Operating Activities to Adjusted EBITDA


	For the Three Months Ended
	March 31,
	2024		2023

	(In thousands)
Net cash provided by operating activities	$	7,712	$	90,313
Changes in working capital		11,217		(5,740)
Interest expense, net		3,527		5,737
Pipeline incident loss		707		8,279
Litigation settlement		—		(84,875)
Income tax expense (benefit) - current		1,395		12,527
Amortization and write-off of deferred financing fees		(304)		(461)
Exploration costs		41		26
Acquisition and divestiture related expenses		14		—
Other		592		—
Adjusted EBITDA	$	24,901	$	25,806

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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 have historically been cash flows generated by operating activities and borrowings under our Revolving Credit Facility. As we pursue reserve and production growth, 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 2024 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 2024, we expect our primary funding sources to be from internally generated cash flow but retain the flexibility to utilize borrowings under our Revolving Credit Facility and/or to access the debt and equity capital markets.

Impact of the Beta Pipeline Incident. There are remaining uncertainties surrounding the full impact that the Incident will have on our financial condition and cash flow generation going forward. We have incurred and will continue to incur certain costs as a result of the Incident. However, in addition to the settlement amount disclosed elsewhere in this Quarterly Report on Form 10-Q that we received from the vessels that struck and damaged the Pipeline and their respective owners and operators, we carry customary insurance policies, which have covered a material portion of aggregate costs, including loss of production income insurance to offset loss of revenue resulting from suspended operations. The loss of production income insurance related to the Incident expired on March 31, 2023. We restarted operations at Beta in April 2023. We can provide no assurance that our coverage will adequately protect us against liability from all potential consequences, damages and losses related to the Incident.

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 potential future growth projects and acquisition activity.

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. The current 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.

Capital Expenditures. Total capital expenditures were approximately $19.1 million for the three months ended March 31, 2024, which were primarily related to the development program at Beta, capital workovers and facilities upgrade projects at Beta and in Oklahoma and non-operated drilling and completion activities in the Eagle Ford.

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.

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As of March 31, 2024, we had a working capital deficit (excluding commodity derivatives) of $21.4 million primarily due to accrued liabilities of $36.8 million, revenues payable of $20.8 million, and accounts payable of $21.7 million partially offset by accounts receivable of $36.5 million, prepaid expenses of $18.4 million and cash on hand of $3.0 million.

Debt Agreement

Revolving Credit Facility. On July 31, 2023, OLLC and Acquisitionco entered into the Revolving Credit Facility. The Revolving Credit Facility is a replacement in full of the Prior Revolving Credit Facility. The aggregate principal amount of loans outstanding under the Revolving Credit Facility as of March 31, 2024, was $115.0 million.

As of March 31, 2024, we had approximately $20.0 million of available borrowings under our Revolving Credit Facility.

The Company is required to maintain a minimum current ratio of 1.00 to 1.00, which is measured on the last day of each quarter. On March 31, 2024, the Company’s current ratio was 0.98 to 1.00. On May 2, 2024, the Company received a letter agreement from its lenders waiving any default or event of default as a result of such noncompliance related to the minimum current ratio requirement for the quarter ended March 31, 2024. As a result, the Company was in compliance with all financial covenants as of March 31, 2024. The Company expects to maintain a current ratio of 1.0 to 1.0 in future quarters.

For additional information regarding our Revolving Credit Facility, see Note 7 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 7 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 11 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 a trust account to comply with supplemental regulatory bonding requirements related to our decommissioning obligations for the Beta production facilities. As of March 31, 2024, our future commitment under this agreement was $6.8 million for the remainder of 2024 and $9.0 million per year until the escrow account is fully funded. See Note 14 of the Notes to Unaudited Condensed Consolidated Financial Statements included under “Item 1. Financial Statements” of this quarterly report for additional information.

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 three months ended March 31, 2024 and 2023 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 Three Months Ended
	March 31,
	2024		2023

	(In thousands)
Net cash provided by operating activities	$	7,712	$	90,313
Net cash used in investing activities		(23,724)		(10,417)
Net cash used in financing activities		(1,745)		(67,141)

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Operating Activities. Key drivers of net operating cash flows are commodity prices, production volumes and operating costs. Net cash provided by operating activities was $7.7 million and $90.3 million for the three months ended March 31, 2024 and 2023, respectively. For the three months ended March 31, 2023, we received $84.9 million in connection with the settlement between the Company and the vessels that struck and damaged the pipeline and their respective owners and operators.

Production volumes were approximately 20.2 MBoe/d and 19.4 MBoe/d for the three months ended March 31, 2024 and 2023, respectively. The change in production volumes was primarily driven by Beta returning to production in April 2023. For the first quarter of 2023 Beta was offline. The average realized sales price was $40.89 per Boe and $37.99 per Boe for the three months ended March 31, 2024 and 2023, respectively. The change in average realized sales price was primarily due to higher oil commodity prices and Beta coming back online.

Net cash provided by operating activities for the three months ended March 31, 2024 included $4.3 million of cash received on expired commodity derivative instruments compared to $2.7 million of cash paid on expired commodity derivatives for the three months ended March 31, 2023. For the three months ended March 31, 2024, we had net losses on commodity derivative instruments of $16.6 million compared to a net gain of $15.2 million for the three months ended March 31, 2023.

Investing Activities. Net cash used in investing activities for the three months ended March 31, 2024 was $23.7 million, of which $19.1 million was used for additions to oil and natural gas properties. In addition, we had a decrease of $1.5 million in our capital expenditures payable account. Net cash provided by investing activities for the three months ended March 31, 2023 was $10.4 million, of which $8.2 million was used for additions to oil and natural gas properties.

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 $2.5 million and $2.1 million during the three months ended March 31, 2024 and 2023, respectively.

Financing Activities. We had repayments of $25.0 million, offset by $25.0 million in borrowings for the three months ended March 31, 2024 related to our Revolving Credit Facility compared to net repayments of $65.0 million for the three months ended March 31, 2023.

Off–Balance Sheet Arrangements

As of March 31, 2024, 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.

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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 March 31, 2024. 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 2023 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. There have been no material changes to the risk factors disclosed in Part I, Item 1A in our 2023 Form 10-K.

ITEM 2.UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS.

The following table summarizes our repurchase activity during the three months ended March 31, 2024:


				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)
January 1, 2024 - January 31, 2024	29,412	$	5.96	—	n/a
February 1, 2024 - February 29, 2024	137,637	$	6.04	—	n/a
March 1, 2024 - March 31, 2024	60,162	$	6.05	—	n/a

(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 8 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
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).

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

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

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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:	May 8, 2024	By:	/s/ James Frew
		Name:	James Frew
		Title:	Senior Vice President and Chief Financial Officer


Date:	May 8, 2024	By:	/s/ Eric Dulany
		Name:	Eric Dulany
		Title:	Vice President and Chief Accounting Officer

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Date	Price Target	Rating	Analyst
5/2/2024	$11.00	Buy	The Benchmark Company
1/22/2024	$9.00	Buy	Alliance Global Partners
10/28/2022	$12.00	Neutral → Buy	ROTH Capital
10/4/2021		Buy → Neutral	ROTH Capital
7/6/2021	$4.40 → $6.20	Buy	Roth Capital

SEC Form 10-Q filed by Amplify Energy Corp.

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