Amplify Energy (AMPY) 10-K 11 Mar 21 2020 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Feb. 26, 2021	Jun. 30, 2020
Cover [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2020
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	FY
Trading Symbol	AMPY
Entity Registrant Name	AMPLIFY ENERGY CORP.
Entity Central Index Key	0001533924
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Non-accelerated Filer
Entity Shell Company	false
Entity Small Business	true
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	false
Entity Tax Identification Number	82-1326219
Entity File Number	001-35512
Entity Incorporation, State or Country Code	DE
Entity Address, Address Line One	500 Dallas Street
Entity Address, Address Line Two	Suite 1700
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77002
City Area Code	713
Local Phone Number	490-8900
Security Exchange Name	NYSE
Title of 12(b) Security	Common Stock
Document Annual Report	true
Document Transition Report	false
Entity Interactive Data Current	Yes
Entity Common Stock, Shares Outstanding		37,943,167
Entity Public Float			$ 33.2
Documents Incorporated by Reference	Documents Incorporated By Reference :

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Current assets:
Cash	$ 10,364	$ 0
Restricted cash	0	325
Accounts receivable, net	30,901	33,145
Short-term derivative instruments	0	5,879
Prepaid expenses and other current assets	15,572	13,238
Total current assets	56,837	52,587
Property and equipment, at cost:
Oil and natural gas properties, successful efforts method	775,167	797,005
Support equipment and facilities	142,208	140,023
Other	9,102	8,045
Accumulated depreciation, depletion and impairment	(609,231)	(141,350)
Property and equipment, net	317,246	803,723
Long-term derivative instruments	873	6,364
Restricted investments	4,623	4,622
Operating lease - long term right-of-use asset	2,500	4,406
Other long-term assets	2,680	5,837
Total assets	384,759	877,539
Current liabilities:
Accounts payable	798	8,310
Revenues payable	22,563	29,167
Accrued liabilities (see Note 14)	22,677	23,358
Short-term derivative instruments	10,824	253
Total current liabilities	56,862	61,088
Long-term debt (see Note 9)	260,516	285,000
Asset retirement obligations	96,725	90,466
Long-term derivative instruments	847	305
Operating lease liability	266	2,720
Other long-term liabilities	3,280	3,753
Total liabilities	418,496	443,332
Commitments and contingencies (see Note 16)
Stockholders' equity (deficit):
Preferred stock, $0.01 par value: 50,000,000 shares authorized; no shares issued and outstanding at December 31, 2020 and 2019, respectively	0	0
Warrants, 2,173,913 and 9,153,522 warrants issued and outstanding at December 31, 2020 and 2019, respectively	4,788	4,790
Common stock, $0.01 par value: 250,000,000 shares authorized; 37,663,509 and 37,566,540 shares issued and outstanding at December 31, 2020 and 2019, respectively	378	209
Additional paid-in capital	424,104	424,399
Accumulated earnings (deficit)	(463,007)	4,809
Total stockholders' equity (deficit)	(33,737)	434,207
Total liabilities and equity	$ 384,759	$ 877,539

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Dec. 31, 2020	Dec. 31, 2019
Statement Of Financial Position [Abstract]
Preferred stock, par value	$ 0.01	$ 0.01
Preferred stock, shares authorized	50,000,000	50,000,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Warrants issued	2,173,913	9,153,522
Warrants outstanding	2,173,913	9,153,522
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	250,000,000	250,000,000
Common stock, shares issued	37,663,509	37,566,540
Common stock, shares outstanding	37,663,509	37,566,540

STATEMENTS OF CONSOLIDATED OPER

STATEMENTS OF CONSOLIDATED OPERATIONS - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Revenues:
Total revenues	$ 202,144	$ 275,575
Costs and expenses:
Lease operating expense	119,708	123,918
Exploration	56	51
Taxes other than income	12,944	18,668
Depreciation, depletion, and amortization	40,268	55,843
Impairment expense	476,936	2,246
General and administrative expense	27,789	55,288
Accretion of asset retirement obligations	6,206	5,559
(Gain) loss on commodity derivative instruments	(60,671)	6,700
Other, net	250	798
Total costs and expenses	644,033	287,546
Operating income (loss)	(441,889)	(11,971)
Other income (expense):
Interest expense, net	(20,522)	(16,855)
Other income (expense)	65	(1,117)
Loss on lease	0	(4,247)
Inventory valuation adjustment	(1,003)	0
Total other income (expense)	(21,460)	(22,219)
Income (loss) before reorganization items, net and income taxes	(463,349)	(34,190)
Reorganization items, net	(566)	(1,057)
Income tax benefit (expense)	(115)	50
Net income (loss)	(464,030)	(35,197)
Net (income) loss allocated to participating restricted stockholders	0	0
Net income (loss) available to common stockholders	$ (464,030)	$ (35,197)
Earnings (loss) per share: (See Note 11)
Basic and diluted earnings (loss) per share	$ (12.34)	$ (1.20)
Weighted average common shares outstanding:
Basic and diluted	37,612	29,301
Oil and Natural Gas Sales [Member]
Revenues:
Total revenues	$ 200,888	$ 274,607
Other Revenues [Member]
Revenues:
Total revenues	1,256	968
Gathering, Processing and Transportation [Member]
Costs and expenses:
Gathering, processing, and transportation	$ 20,547	$ 18,475

STATEMENTS OF CONSOLIDATED CASH

STATEMENTS OF CONSOLIDATED CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Cash flows from operating activities:
Net income (loss)	$ (464,030)	$ (35,197)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	40,268	55,843
Impairment expense	476,936	2,246
(Gain) loss on derivative instruments	(56,628)	6,476
Cash settlements (paid) received on expired derivative instruments	61,135	4,344
Cash settlements (paid) received on terminated derivative instruments	17,977	0
Bad debt expense	294	301
Amortization and write-off of deferred financing costs	3,272	1,174
Accretion of asset retirement obligations	6,206	5,559
Share-based compensation (see Note 12)	(112)	4,530
Settlement of asset retirement obligations	(327)	(259)
Write-off of other property, plant & equipment	0	1,325
Other	0	(8)
Changes in operating assets and liabilities:
Accounts receivable	1,950	10,701
Prepaid expenses and other assets	(2,334)	713
Payables and accrued liabilities	(9,803)	(13,592)
Other	(474)	3,127
Net cash provided by operating activities	74,330	47,283
Cash flows from investing activities:
Cash acquired from the Merger	0	19,250
Additions to oil and gas properties	(34,833)	(72,709)
Additions to other property and equipment	(1,057)	(1,081)
Additions to restricted investments	0	(155)
Withdrawals of restricted investments	0	90,000
Other	0	10
Net cash provided by (used in) investing activities	(35,890)	35,315
Cash flows from financing activities:
Advances on revolving credit facilities	25,000	125,000
Payments on revolving credit facilities	(55,000)	(134,000)
Proceeds from the paycheck protection program	5,516	0
Deferred financing costs	(115)	(882)
Dividends to stockholders	(3,786)	(15,889)
Common stock repurchased and retired under the share repurchase program	0	(26,203)
Treasury stock acquired and retired	0	(3,340)
Costs incurred in conjunction with tender offer	0	(107)
Restricted shares returned to plan and retired	(51)	(406)
Other	35	84
Net cash provided by (used in) financing activities	(28,401)	(132,302)
Net change in cash, cash equivalents and restricted cash	10,039	(49,704)
Cash, cash equivalents and restricted cash, beginning of period	325	50,029
Cash, cash equivalents and restricted cash, end of period	10,364	325
Midstates [Member]
Cash flows from financing activities:
Payments on revolving credit facilities	$ 0	$ (76,559)

STATEMENTS OF CONSOLIDATED EQUI

STATEMENTS OF CONSOLIDATED EQUITY - USD ($) $ in Thousands	Total	Common Stock [Member]	Warrants [Member]	Additional Paid in Capital [Member]	Treasury Stock [Member]	Accumulated Earnings (Deficit) [Member]
Balance at Dec. 31, 2018	$ 416,558	$ 3	$ 4,788	$ 355,872	$ 0	$ 55,895
Net income (loss)	(35,197)	0	0	0	0	(35,197)
Equity transactions related to the Merger	91,544	206	2	94,059	(2,723)	0
Acquisition of treasury stock	(618)	0	0	0	(618)	0
Retirement of treasury shares	0	0	0	(3,341)	3,341	0
Share-based compensation expense	4,530	0	0	4,530	0	0
Cost incurred in conjunction with tender offer	(107)	0	0	(107)	0	0
Common stock repurchased and retired under the share repurchase program	(26,203)	0	0	(26,203)	0	0
Dividends	(15,889)	0	0	0	0	(15,889)
Restricted shares returned to plan and retired	(406)	0	0	(406)	0	0
Other	(5)	0	0	(5)	0	0
Balance at Dec. 31, 2019	434,207	209	4,790	424,399	0	4,809
Net income (loss)	(464,030)	0	0	0	0	(464,030)
Share-based compensation expense	(112)	0	0	(112)	0	0
Dividends	(3,786)	0	0	0	0	(3,786)
Expiration Of Warrants	0	0	(2)	2	0	0
Restricted shares returned to plan and retired	(51)	0	0	(51)	0	0
Other	35	169	0	(134)	0	0
Balance at Dec. 31, 2020	$ (33,737)	$ 378	$ 4,788	$ 424,104	$ 0	$ (463,007)

Organization and Basis of Prese

Organization and Basis of Presentation	12 Months Ended
	Dec. 31, 2020
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Organization and Basis of Presentation	Note 1. Organization and Basis of Presentation General On August 6, 2019, Midstates Petroleum Company, Inc., a Delaware corporation (“Midstates”), completed its business combination (the “Merger”) with Amplify Energy Corp. (“Legacy Amplify”), in accordance with the terms of that certain Agreement and Plan of Merger, dated May 5, 2019 (the “Merger Agreement”), by and among Midstates, Legacy Amplify and Midstates Holdings, Inc., a Delaware corporation and direct, wholly owned subsidiary of Midstates (“Merger Sub”). Pursuant to the terms of the Merger Agreement, Merger Sub merged with and into Legacy Amplify, with Legacy Amplify surviving the Merger as a wholly owned subsidiary of Midstates, and immediately following the Merger, Legacy Amplify merged with and into Alpha Mike Holdings LLC, a Delaware limited liability company and wholly owned subsidiary of Midstates (“LLC Sub”), with LLC Sub surviving as a wholly owned subsidiary of Midstates. On the effective date of the Merger, Midstates changed its name to “Amplify Energy Corp.” (the “Company”) and LLC Sub changed its name to “Amplify Energy Holdings LLC.” For financial reporting purposes, the Merger represented a “reverse merger” and Legacy Amplify was deemed to be the accounting acquirer in the transaction. Legacy Amplify’s historical results of operations replaced Midstates’ historical results of operations for all periods prior to the Merger and, for all periods following the Merger, the Company’s financial statements reflect the results of operations of the combined company. Accordingly, the financial statements for the Company included in this annual report for periods prior to the Merger are not the same as Midstates prior reported filings with the SEC, which were derived from the operations of Midstates. When referring to Legacy Amplify, the intent is to refer to Amplify Energy Corp. prior to the Merger, and its consolidated subsidiaries as a whole or on an individual basis, depending on the context in which the statements are made. 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 one reportable business segment as there are not different economic environments within the operation of our oil and natural gas properties. Our assets consist primarily of producing oil and natural gas properties located in Oklahoma, the Rockies, federal waters offshore Southern California, East Texas/North Louisiana and the Eagle Ford. Most of our 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 Material intercompany transactions and balances have been eliminated in preparation of our Consolidated Financial Statements. The accompanying Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). The Consolidated Financial Statements have been prepared as if the Company is a going concern and reflect the application of Accounting Standards Codification 852 “Reorganizations” (“ASC 852”). Risk and Uncertainties In March 2020, the World Health Organization declared a global pandemic related to the proliferation of COVID-19. The impact of COVID-19 and efforts to mitigate its spread have caused significant volatility in U.S. and international markets and a substantial reduction in global and domestic demand for oil and natural gas. Actions by governmental authorities to mitigate the spread of COVID-19, such as imposing mandatory closures of all non-essential business facilities, seeking voluntary closures of business facilities, and imposing restrictions on, or advisories with respect to, travel, business operations and public gatherings or interactions, have further exacerbated the economic impact of the pandemic. As a result of the pandemic, there has also been a sharp reduction in the demand for oil and natural gas and a precipitous decline in commodity prices, which were further impacted by disputes over production levels among oil-producing countries, the significant increase in production levels by such countries and limited storage capacity for natural gas, oil and refined products. The reductions in commodity prices have resulted in lower levels of cash flow from operating activities. In addition, the borrowing base under our Revolving Credit Facility (as defined below) is subject to redetermination on at least a semi-annual basis primarily based on an engineering report with respect to our estimated oil and natural gas reserves, which takes into account the prevailing oil and natural gas prices at such time, as adjusted for the impact of our commodity derivative contracts. Severely reduced commodity prices contributed to a reduction in our borrowing base during the Spring 2020 redetermination process, and continued low prices may adversely impact subsequent redeterminations. The reduction in commodity prices has directly led to an impairment of our oil and natural gas properties. There may be further impairments in future periods if commodity prices do not fully recover. Despite the gradual recover y in commodity prices in the second half of 2020, the expectation of a successful phased rollout of a vaccine in 2021, and the successful realization and execution of our liquidity enhancing initiatives and disciplined hedging program, there remains significant uncertainty around the breadth and duration of business disruptions related to COVID-19, as well as its impact on the U.S. and international economies and, as such, the Company is unable to determine the extent of the impact caused by the COVID-19 pandemic to the Company’s operations.

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2020
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Note 2. Summary of Significant Accounting Policies Use of Estimates The preparation of 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; depreciation, depletion and amortization of proved oil and natural gas properties; future cash flows from oil and natural gas properties; impairment of long-lived assets; fair value of derivatives; fair value of equity compensation; fair values of assets acquired and liabilities assumed in business combinations and asset retirement obligations. Business Combinations Accounting for the acquisition of a business requires the identifiable assets and liabilities acquired to be recorded at fair value. The most significant assumptions in a business combination include those used to estimate the fair value of the oil and gas properties acquired. The fair value of proved natural gas properties is determined using a risk-adjusted after-tax discounted cash flow analysis based upon significant assumptions including commodity prices; projections of estimated quantities of reserves; projections of future rates of production; timing and amount of future development and operating costs; projected reserve recovery factors; and a weighted average cost of capital. The Company utilizes a market approach to estimate the fair value of unproved properties acquired in a business combination which requires the Company to use judgment in considering the value per undeveloped acre in recent comparable transactions to estimate the value of unproved properties. Cash and Cash Equivalents Cash and cash equivalents represent unrestricted cash on hand and all highly liquid investments with original contractual maturities of three months or less. Concentrations of Credit Risk Cash balances, accounts receivable, restricted investments and derivative financial instruments are financial instruments potentially subject to credit risk. Cash and cash equivalents are maintained in bank deposit accounts which, at times, may exceed the federally insured limits. Management periodically reviews and assesses the financial condition of the banks to mitigate the risk of loss. Various restricted investment accounts fund certain long-term contractual and regulatory asset retirement obligations and collateralize certain regulatory bonds associated with the offshore Southern California oil and gas properties. These restricted investments consist of money market deposit accounts which are held with credit-worthy financial institutions. Derivative financial instruments are generally executed with major financial institutions that expose us to market and credit risks and which may, at times, be concentrated with certain counterparties. The credit worthiness of the counterparties is subject to continual review. We rely upon netting arrangements with counterparties to reduce credit exposure. Oil and natural gas are sold to a variety of purchasers, including intrastate and interstate pipelines or their marketing affiliates and independent marketing companies. Accounts receivable from joint operations are from a number of oil and natural gas companies, individuals and others who own interests in the properties operated by us. Generally, operators of crude oil and natural gas properties have the right to offset future revenues against unpaid charges related to operated wells, minimizing the credit risk associated with these receivables. An allowance for doubtful accounts is recorded after all reasonable efforts have been exhausted to collect or settle the amount owed. Any amounts outstanding longer than the contractual terms are considered past due. We recorded $1.5 million as an allowance for doubtful accounts at December 31, 2020 and 2019. If we were to lose any one of our customers, the loss could temporarily delay the production and the sale of oil and natural gas in the related producing region. If we were to lose any single customer, we believe that a substitute customer to purchase the impacted production volumes could be identified. The following individual customers each accounted for 10% or more of total reported revenues for the period indicated: For the Year Ended December 31, 2020 2019 Major customers: Phillips 66 23% 27% Sinclair Oil & Gas Company 21% 21% BP America Production Company 17% 13% Oil and Natural Gas Properties Oil and natural gas exploration, development and production activities are accounted for in accordance with the successful efforts method of accounting. Under this method, costs of acquiring properties, costs of drilling successful exploration wells and development costs are capitalized. The costs of exploratory wells are initially capitalized pending a determination of whether proved reserves have been found. At the completion of drilling activities, the costs of exploratory wells remain capitalized if determination is made that proved reserves have been found. If no proved reserves have been found, the costs of each of the related exploratory wells are charged to expense. In some cases, a determination of proved reserves cannot be made at the completion of drilling, requiring additional testing and evaluation of the wells. The costs of such exploratory wells are expensed if a determination of proved reserves has not been made within a twelve-month period after drilling is complete. Exploration costs such as geological, geophysical, seismic costs and delay rental payments attributable to unproved locations are expensed as incurred. As exploration and development work progresses and the reserves on these properties are proven, capitalized costs attributed to the properties are subject to depreciation and depletion. Depletion of capitalized costs is provided using the units-of-production method based on proved oil and gas reserves related to the associated field. Capitalized drilling and development costs of producing oil and natural gas properties are depleted over proved developed reserves and leasehold costs are depleted over total proved reserves. Support equipment and facilities, which are primarily related to our Wyoming and California assets, are depreciated using the straight-line method generally based on estimated useful lives of twelve to twenty-four years. On the sale or retirement of a complete or partial unit of a proved property or pipeline and related facilities, the cost and related accumulated depreciation, depletion, and amortization are removed from the property accounts, and any gain or loss is recognized. There were no material capitalized exploratory drilling costs pending evaluation at December 31, 2020 and 2019. Oil and Natural Gas Reserves The estimates of proved oil and natural gas reserves utilized in the preparation of the Consolidated Financial Statements are estimated in accordance with the rules established by the SEC and the Financial Accounting Standards Board (“FASB”). These rules require that reserve estimates be prepared under existing economic and operating conditions using a trailing 12-month average price with no provision for price and cost escalations in future years except by contractual arrangements. The development of the Company’s oil and natural gas reserve quantities require management to make significant estimates and assumptions related to the intent and ability to complete undeveloped proved reserves within a five-year development period, as prescribed by SEC guidelines. Additionally, none of our PUDs are scheduled to be developed on a date more than five years from the date the reserves were initially booked as PUD as prescribed by the SEC guidelines. PUDs are converted from undeveloped to developed as applicable wells begin production. We engaged Cawley, Gillespie and Associates, Inc. (“CG&A”), our independent reserve engineers, to prepare our reserves estimates for all of our estimated proved reserves at December 31, 2020 and 2019. Reserve estimates are inherently imprecise. Accordingly, the estimates are expected to change as more current information becomes available. It is possible that, because of changes in market conditions or the inherent imprecision of reserve estimates, the estimates of future cash inflows, future gross revenues, the amount of oil and natural gas reserves, the remaining estimated lives of oil and natural gas properties, or any combination of the above may be increased or decreased. Increases in recoverable economic volumes generally reduce per unit depletion rates while decreases in recoverable economic volumes generally increase per unit depletion rates. Other Property & Equipment Other property and equipment is stated at historical cost and is comprised primarily of vehicles, furniture, fixtures, office build-out cost and computer hardware and software. Depreciation of other property and equipment is calculated using the straight-line method generally based on estimated useful lives of three to seven years. Restricted Investments Various restricted investment accounts fund certain long-term contractual and regulatory asset retirement obligations and collateralize certain regulatory bonds associated with the offshore Southern California oil and gas properties. These investments are classified as held-to-maturity and such investments are stated at amortized cost. Interest earned on these investments is included in interest expense, net in the statement of operations. These restricted investments may consist of money market deposit accounts and U.S. Government securities. See Note 8 and Note 16 for additional information. Debt Issuance Costs Debt issuance costs are recorded in prepaid expenses and other current assets line item on the balance sheet and amortized over the term of the associated debt using the straight-line method which generally approximates the effective yield method. Amortization expense, including write-off of debt issuance costs, for the years ended December 31, 2020 and 2019 was approximately $3.3 million and $1.2 million, respectively. Impairments Proved oil and natural gas properties are reviewed for impairment when events and circumstances indicate the carrying value of such properties may not be recoverable. This may be due to a downward revision of the reserve estimates, less than expected production, drilling results, higher operating and development costs, or lower commodity prices. The estimated undiscounted future cash flows expected in connection with the property are compared to the carrying value of the property to determine if the carrying amount is recoverable. If the carrying value of the property exceeds its estimated undiscounted future cash flows, the carrying amount of the property is reduced to its estimated fair value using Level 3 inputs. The factors used to determine fair value include, but are not limited to, estimates of proved and 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 gas properties. We recorded $427.6 million of impairment expense related to our proved properties for the year ended December 31, 2020. No impairment expense related to our proved properties was recorded for the year ended December 31, 2019. Unproved oil and natural gas properties are reviewed for impairment based on time or geologic factors. Information such as drilling results, reservoir performance, seismic interpretation or future plans to develop acreage is also considered. When unproved property investments are deemed to be impaired, the expense is reported in impairment expense. We recognized $49.3 million and $2.2 million in impairment expense related to our unproved properties for the years ended December 31, 2020 and 2019, respectively. For the year ended December 31, 2020 the impairment was related to expiring leases and the evaluation of qualitative and quantitative factors related to the current decline in commodity prices. For the year ended December 31, 2019, the impairment was for certain unproved leasehold costs. Significant declines in commodity prices, further changes to the Company’s drilling or development plans, reduction of proved and probable reserve estimates, or increases in drilling or operating costs could result in other additional future impairments to proved and unproved oil and gas properties. Asset Retirement Obligations An asset retirement obligation associated with retiring long-lived assets is recognized as a liability on a discounted basis in the period in which the legal obligation is incurred and becomes determinable, with an equal amount capitalized as an addition to oil and natural gas properties, which is allocated to expense over the useful life of the asset. Generally, oil and gas producing companies incur such a liability upon acquiring or drilling a well. Accretion expense is recognized over time as the discounted liabilities are accreted to their expected settlement value. Upon settlement of the liability, a gain or loss is recognized in net income (loss) to the extent the actual costs differ from the recorded liability. See Note 7 for further discussion of asset retirement obligations. Book Overdrafts Book overdrafts, representing outstanding checks in excess of funds on deposit, are classified as accounts payable and the change in the related balance is reflected in operating activities in the statement of cash flows. Revenue Recognition Revenue from the sale of oil and natural gas is recognized when title passes, net of royalties due to third parties. Oil and natural gas revenues are recorded using the sales method. Under this method, revenues are recognized based on actual volumes of oil and natural gas sold to purchasers, regardless of whether the sales are proportionate to our ownership in the property. An asset or a liability is recognized to the extent there is an imbalance in excess of the proportionate share of the remaining recoverable reserves on the underlying properties. No significant imbalances existed at December 31, 2020 and 2019. Derivative Instruments Commodity derivative financial instruments (e.g., swaps, collars and puts) are used to reduce the impact of natural gas and oil price fluctuations. Every derivative instrument is recorded on the balance sheet as either an asset or liability measured at its fair value. Changes in the derivative’s fair value are recognized in earnings as we have not elected hedge accounting for any of our derivative positions. Capitalized Interest We capitalize interest costs to oil and gas properties on expenditures made in connection with certain projects such as drilling and completion of new oil and natural gas wells and major facility installations. Interest is capitalized only for the period that such activities are in progress. Interest is capitalized using a weighted average interest rate based on our outstanding borrowings. These capitalized costs are included with intangible drilling costs and amortized using the units of production method. We had $0.2 million in capitalized interest for the years ended December 31, 2020 and 2019, respectively. Income Tax We are a corporation subject to federal and certain state income taxes. We use the asset and liability method of accounting for income taxes, under which deferred tax assets and liabilities are recognized for the future tax consequences of (1) temporary differences between the tax basis of assets and liabilities and their reported amounts in the financial statements and (2) operating loss and tax credit carryforwards. Deferred income tax assets and liabilities are based on enacted tax rates applicable to the future period when those temporary differences are expected to be recovered or settled. Deferred tax assets are reduced by a valuation allowance if, based on the weight of available evidence, it is more likely than not that some portion or all of deferred tax assets will not be realized. We recognize a tax benefit from an uncertain tax position when it is more likely than not that the position will be sustained upon examination by taxing authorities, based on the technical merits of the position. The tax benefit recorded is equal to the largest amount that is greater than 50% likely to be realized through effective settlement with a taxing authority. We recognize interest and penalties accrued to unrecognized tax benefits in other income (expense) in our Statement of Consolidated Operations. Although we believe our assumptions, judgements and estimates are reasonable, changes in tax laws or our interpretation of tax laws and the resolution of any tax audits could significantly impact the amounts provided for income taxes in our consolidated financial statements. Earnings (loss) Per Share Basic and diluted earnings (loss) per share (“EPS”) is determined by dividing net income (loss) available to the common stockholders by the weighted average number of outstanding shares during the period. Diluted earnings (loss) per common share is calculated under the two-class method and the treasury stock method by dividing net income (loss) available to common stockholders by the weighted average number of diluted common shares outstanding, which includes the effect of potentially dilutive securities. When a loss from continuing operations exists, all potentially dilutive securities are anti-dilutive and are therefore excluded from the computation of diluted earnings per share. See Note 11 for additional information. Equity Compensation The fair value of equity-classified awards (e.g., restricted common unit awards, restricted stock units or stock options) is amortized to earnings over the requisite service or vesting period. Compensation expense for liability-classified awards (e.g., phantom units awards) are recognized over the requisite service or vesting period of an award based on the fair value of the award re-measured at each reporting period. We currently have awards subject to performance criteria; such awards would vest when it is probable that the performance criteria will be met and the requisite service period has been met. Generally, no compensation expense is recognized for equity instruments that do not vest. See Note 12 for further information. Lease Recognition In February 2016, the FASB issued guidance regarding the accounting for leases. The FASB retained a dual model, requiring leases to be classified as either direct financing or operating leases. The classification will be based on criteria that are similar to the current lease accounting treatment. The Company is the lessee under various agreements for office space, compressors, equipment, vehicles and surface rentals (right of use assets) that are currently accounted for as operating leases. The Company applied the revised lease rules for our interim and annual reporting periods starting January 1, 2019 using the modified retrospective approach with a cumulative impact to retained earnings in that period, and including several optional practical expedients relating to leases commenced before the effective date. The practical expedients the Company adopted are: (1) the original correct assessment of a contract containing a lease will be accepted without further review on all existing or expired contracts; (2) the original lease classification as an operating lease will convert as an operating lease under the new guidance; (3) initial direct costs for any existing leases will not be reassessed; (4) existing land easements or right of use agreements will continue under current accounting policy and only new agreements will be evaluated in the future; and (5) short-term leases for twelve months or less will not be evaluated under the guidance. See Note 13 for additional information regarding the adoption of the leases standard. Recently Adopted Accounting Pronouncements Current Expected Credit Losses In May 2019, the FASB issued an accounting standard update to provide entities with an option to irrevocably elect the fair value option applied on an instrument-by-instrument basis for certain financial assets upon the adoption of the guidance. The fair value option election does not apply to held-to-maturity debt securities. The Company adopted the guidance as of January 1, 2020. The Company has evaluated the impact of this guidance and concluded that the current and historical evaluation of estimated credit losses falls within the acceptable guidance. The provisions of the standard were interpreted to relate only to the Company’s accounts receivable, net. Trade receivables relate to one common pool, revenue earned on the sale of oil, natural gas and natural gas liquids. The performance obligation is satisfied at a point in time and revenue is recognized and a trade receivable is recorded from the sale when production is delivered to, and title has transferred to, the purchaser. The majority of the Company’s purchasers have been large major companies in the industry with the wherewithal to pay. The Company, as operator on most of our wells, also records receivables on billings to our joint interest owners who participate in the operating costs of the wells they have an interest in. Historically, an allowance for doubtful accounts has been set up to recognize credit losses on joint interest billing (“JIB”) receivables based upon an aging analysis, which is an appropriate method to estimate credit losses under the guidance. The Company will continue to assess the expected credit loss in the future as economic conditions change. Considering the recent drop in commodity prices, we believe the majority of our revenue purchasers have the size and financial condition to currently meet their obligations. There could be added risk on the JIB accounts receivable as some wells could become uneconomic, with the revenue not enough to cover operating expenses billed, which could result in additional write-offs. The Company will continue to closely monitor trade receivables. Based upon the analysis performed there was no impact to beginning retained earnings upon the adoption of the guidance. The Company’s monitoring activities include timely account reconciliation and balances are written off when determined to be uncollectible. The Company considered the market conditions surrounding the COVID-19 pandemic and determined that the estimate of credit losses was not significantly impacted. Fair Value Measurement . In August 2018, the FASB issued an amendment to modify the disclosure requirements on fair value measurements in Topic 820, Fair Value Measurement. Certain disclosure requirements were removed, modified and added and primarily relate to Level 3 hierarchy measurements and changes to non-public entities disclosures. The guidance is effective for all entities for fiscal years and interim periods within those fiscal years, beginning after December 15, 2019. The adoption of this guidance had no material impact on our consolidated financial statements. New Accounting Pronouncements Income Taxes – Simplifying the Accounting for Income Taxes . In December 2019, the FASB issued an accounting standards update which simplifies the accounting for income taxes by removing certain exceptions to the general principles in Topic 740. This accounting standards update removes the following exceptions: (i) exception to the incremental approach for intraperiod tax allocation when there is a loss continuing operations and income or a gain from other items; (ii) exception to the requirements to recognize a deferred tax liability for equity method investments when a foreign subsidiary becomes an equity method investment; (iii) exception to the ability not to recognize a deferred tax liability for a foreign subsidiary when a foreign equity method investment becomes a subsidiary; and (iv) exception to the general methodology for calculating income taxes in an interim period when a year-to-date loss exceeds the anticipated loss for the year. The amendments in the accounting standards update also improve consistency and simplify other areas of Topic 740 by clarifying and amending existing guidance. The new guidance is effective for fiscal years and interim periods within those fiscal years, beginning after December 15, 2020. The Company is expecting to adopt the guidance January 1, 2021, with all of the anticipated and applicable effects to be required on a prospective basis. The adoption of this guidance does not expect to have a material impact on our consolidated financial statements. Reference Rate Reform . In March 2020, the FASB issued an accounting standard update which provides optional expedients and expectations for applying GAAP to contracts, hedging relationships, and other transactions to ease financial reporting burdens to the expected market transition from the London Interbank Offered Rate (“LIBOR”) or another reference rate to alternative reference rates. The amendments in this accounting standards update are effective beginning March 12, 2020, and an entity may elect to apply the amendments prospectively through December 31, 2022. The Company is currently evaluating the impact this guidance may have on the Company’s consolidated financial statements. Other accounting standards that have been issued by the FASB or other standards-setting bodies are not expected to have a material impact on the Company’s financial position, results of operations and cash flows.

Revenue

Revenue	12 Months Ended
	Dec. 31, 2020
Revenue From Contract With Customer [Abstract]
Revenue	Note 3. Revenues Revenue from contracts with customers 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. Oil and natural gas revenues are recorded using the sales method. Under this method, revenues are recognized based on actual volumes of oil and natural gas sold to purchasers, regardless of whether the sales are proportionate to our ownership in the property. An asset or a liability is recognized to the extent there is an imbalance in excess of the proportionate share of the remaining recoverable reserves on the underlying properties. No significant imbalances existed at December 31, 2020 and 2019. Disaggregation of Revenue We have identified three material revenue streams in our business: oil, natural gas and NGLs. The following table present our revenues disaggregated by revenue stream. For the Year Ended December 31, 2020 2019 (in thousands) Revenues Oil $ 138,273 $ 192,944 NGLs $ 20,064 $ 22,347 Natural gas $ 42,551 $ 59,316 Oil and natural gas sales $ 200,888 $ 274,607 Contract Balances Under our sales contracts, we invoice customers once our performance obligations have been satisfied, at which point payment is unconditional. Accordingly, our contracts do not give rise to contract assets or liabilities. Accounts receivable attributable to our revenue contracts with customers was $25.6 million and $31.9 million at December 31, 2020 and 2019, respectively. Transaction Price Allocated to Remaining Performance Obligations For our contracts that have a contract term greater than one year, we have utilized the practical expedient in ASC 606, which states that a company is not required to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under our contracts, each unit of product delivered to the customer represents a separate performance obligation; therefore, future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required. For our contracts that have a contract term of one year or less, we have utilized the practical expedient in ASC 606, which states that a company is not required to disclose the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of one year or less.

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2020
Business Combinations [Abstract]
Acquisitions and Divestitures	Note 4. Acquisitions and Divestitures The third party acquisitions discussed below were accounted for under the acquisition method of accounting. Accordingly, we conducted assessments of net assets acquired and recognized amounts for identifiable assets acquired and liabilities assumed at their estimated acquisition date fair values, while acquisition costs associated with the acquisitions were expensed as incurred. The operating revenues and expenses of acquired properties are included in the accompanying financial statements from their respective closing dates forward. The transactions were financed through capital contributions and borrowings under our revolving credit facility. The fair values of oil and natural gas properties are measured using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation of oil and natural properties include estimates of: (i) economic reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a market-based weighted average cost of capital. Acquisition and Divestiture related expenses Acquisition and divestiture related expenses for third party transactions are included in general and administrative expenses in the accompanying statements of operations for the periods indicated below (in thousands): For the Year Ended December 31, 2020 2019 $ 1,092 $ 17,305 There were no material acquisition or divestitures during the year ended December 31, 2020. The acquisition expenses incurred for the year ended December 31, 2019 were primarily related to the Merger discussed below. Business Combination As discussed in Note 2, the most significant assumptions in a business combination include those used to estimate the fair value of the oil and gas properties acquired. The fair value measurements of the oil and natural gas properties acquired, and asset retirement obligations assumed were derived utilizing an income approach and based, in part, on significant inputs not observable in the market. These inputs represent Level 3 measurements in the fair value hierarchy and include, but are not limited to, estimates of reserves, future operating and development costs, estimated future cash flows and appropriate discount rates. These inputs required significant judgments and estimates at the time of the valuation. Merger On May 5, 2019, Midstates, Legacy Amplify and Merger Sub entered into the Merger Agreement pursuant to which, Merger Sub merged with and into Legacy Amplify, with Legacy Amplify surviving the Merger as a wholly owned subsidiary of Midstates. At the effective time of the Merger, each share of Legacy Amplify common stock issued and outstanding immediately prior to the effective time (other than excluded shares) were cancelled and converted into the right to receive 0.933 shares of Midstates common stock, par value $0.01 per share. On August 6, 2019, the effective date of the Merger, Midstates changed its name to “Amplify Energy Corp.” Purchase Price Allocation The Merger had been accounted for using the acquisition method, with Legacy Amplify treated as the acquirer for accounting purposes. The following table represents the allocation of the total purchase price of Midstates to the identifiable assets acquired and the liabilities assumed based on the fair values as of the acquisition date. Purchase Price Allocation (In thousands) Consideration: Fair value of Midstates common stock issued in the Merger (a) $ 90,150 Fair value of Midstates warrants issued in the Merger 2 Value of shares to be issued 90,152 Fair value of Legacy Amplify restricted share consideration 832 Fair value of Legacy Amplify PSU consideration 557 Total consideration $ 91,541 Fair value of liabilities assumed: Current liabilities $ 24,135 Long-term debt 76,559 Long-term asset retirement obligation 9,440 Other long-term liabilities 5,067 Amounts attributable to liabilities assumed $ 115,201 Fair value of assets acquired: Cash and cash equivalents $ 19,250 Other current assets 17,862 Oil and natural gas properties 149,421 Other property and equipment 1,694 Long-term asset retirement cost 9,440 Other non-current assets 9,075 Amounts attributable to assets acquired $ 206,742 Total identifiable net assets $ 91,541 (a) Based on 20,415,005 Midstates common shares issued at closing at $4.12 per share (closing price as of August 6, 2019). We included in our Consolidated Statements of Operations revenue of $31.8 million, direct operating expenses of $34.0 million, and other expenses of $0.4 million, for the Oklahoma properties acquired through the Merger for the period of August 6, 2019 through December 31, 2019. During the three months ended September 30, 2019, the Company completed an analysis of Midstates’ asset retirement obligations as of the acquisition date. Based on this analysis, the Company recorded a measurement period adjustment of $0.9 million to increase the asset retirement obligations liability. During the quarter ended September 30, 2019, the Company completed an analysis of Midstates’ leases under ASC 842 as of the acquisition date. Based on this analysis, the Company recorded an operating lease right of use asset and liability of approximately $0.3 million. Unaudited Pro Forma Financials The following unaudited pro forma financial information for the year ended December 31, 2019, is based on our historical consolidated financial statements adjusted to reflect as if the Merger had occurred on January 1, 2018. The information below reflects pro forma adjustments based on available information and certain assumptions that we believe are reasonable, including adjustments to the estimated tax impact of pro forma adjustments. The unaudited pro forma financial information is not necessarily indicative of what actually would have occurred if the acquisition had been completed as of the beginning of the period presented, nor is it necessarily indicative of future results. For the Year Ended December 31, 2019 (Unaudited) (In thousands, except per unit amounts) Revenues $ 336,326 Net income (loss) (22,926 ) Earnings per share: Basic $ (0.78 ) Diluted $ (0.78 )

Fair Value Measurements of Fina

Fair Value Measurements of Financial Instruments	12 Months Ended
	Dec. 31, 2020
Fair Value Disclosures [Abstract]
Fair Value Measurements of Financial Instruments	Note 5. Fair Value Measurements of Financial Instruments Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at a specified measurement date. Fair value estimates are based on either (i) actual market data or (ii) assumptions that other market participants would use in pricing an asset or liability, including estimates of risk. A three-tier hierarchy has been established that classifies fair value amounts recognized or disclosed in the financial statements. The hierarchy considers fair value amounts based on observable inputs (Levels 1 and 2) to be more reliable and predictable than those based primarily on unobservable inputs (Level 3). The characteristics of fair value amounts classified within each level of the hierarchy are described as follows: Level 1 — Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. An active market is one in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 2 — Quoted prices in markets that are not active, or inputs that are observable, either directly or indirectly, for substantially the full term of the asset or liability. Substantially all of these inputs are observable in the marketplace throughout the full term of the derivative instrument, can be derived from observable data, or are supported by observable levels at which transactions are executed in the marketplace. At December 31, 2020 and 2019, all of the derivative instruments reflected on the accompanying balance sheets were considered Level 2. Level 3 — Measure based on prices or valuation models that require inputs that are both significant to the fair value measurement and are less observable from objective sources (i.e., supported by little or no market activity). Assets and Liabilities Measured at Fair Value on a Recurring Basis The carrying values of cash and cash equivalents (Level 1), accounts receivables, accounts payables (including accrued liabilities) and amounts outstanding under long-term debt agreements with variable rates included in the accompanying balance sheets approximated fair value at December 31, 2020 and 2019. 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. See Note 9 for the estimated fair value of our outstanding fixed-rate debt. The fair market values of the derivative financial instruments reflected on the balance sheets as of December 31, 2020 and December 31, 2019 were based on estimated forward commodity prices (including nonperformance risk). Nonperformance risk is the risk that the obligation related to the derivative instrument will not be fulfilled. 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 table presents the derivative assets and liabilities that are measured at fair value on a recurring basis at December 31, 2020 and December 31, 2019 for each of the fair value hierarchy levels: Fair Value Measurements at December 31, 2020 Using Quoted Prices in Significant Other Significant Active Market Observable Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Fair Value (In thousands) Assets: Commodity derivatives $ — $ 15,449 $ — $ 15,449 Interest rate derivatives — — — — Total assets $ — $ 15,449 $ — $ 15,449 Liabilities: Commodity derivatives $ — $ 23,495 $ — $ 23,495 Interest rate derivatives — 2,752 — 2,752 Total liabilities $ — $ 26,247 $ — $ 26,247 Fair Value Measurements at December 31, 2019 Using Quoted Prices in Significant Other Significant Active Market Observable Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Fair Value (In thousands) Assets: Commodity derivatives $ — $ 18,509 $ — $ 18,509 Interest rate derivatives — 595 — 595 Total assets $ — $ 19,104 $ — $ 19,104 Liabilities: Commodity derivatives $ — $ 6,861 $ — $ 6,861 Interest rate derivatives — 558 — 558 Total liabilities $ — $ 7,419 $ — $ 7,419 See Note 6 for additional information regarding our derivative instruments. 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 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 such factors as the existence of a legal obligation for an ARO; amounts and timing of settlements; the credit-adjusted risk-free rate; and inflation rates. The initial fair value estimates are based on unobservable market data and are classified within Level 3 of the fair value hierarchy. See Note 7 for a summary of changes in AROs. • If sufficient market data is not available, the determination of the fair values of proved and unproved properties acquired in transactions accounted for as business combinations are prepared by utilizing estimates of discounted cash flow projections. The factors to determine fair value include, but are not limited to, estimates of: (i) economic reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a market-based weighted average cost of capital. The fair value of supporting equipment, such as plant assets, acquired in transactions accounted for as business combinations is commonly estimated using the depreciated replacement cost approach. • Proved oil and natural gas properties are reviewed for impairment when events and circumstances indicate the carrying value of such properties may not be recoverable. The Company uses an income approach based on the discounted cash flow method, whereby the present value of expected future net cash flows are 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 gas properties (some of which are Level 3 inputs within the fair value hierarchy). (i) We recognized $427.6 million of impairment expense on our proved oil and natural gas properties for the year ended December 31, 2020. These impairments related to certain properties located in East Texas, the Rockies, offshore Southern California and the Eagle Ford. The estimated future cash flows expected from these properties were compared to their carrying values and determined to be unrecoverable primarily as a result of declining commodity prices. The impairments were due to a decline in the value of estimated proved reserves based on declining commodity prices. • Unproved oil and natural gas properties are reviewed for impairment based on time or geologic factors. Information such as drilling results, reservoir performance, seismic interpretation or future plans to develop acreage is also considered. (i) We recognized $49.3 million of impairment expense on unproved properties for the year ended December 31, 2020, which was related to expiring leases and the evaluation of qualitative and quantitative factors related to the current decline in commodity prices. (ii) We recognized a $2.2 million impairment expense on unproved properties for the year ended December 31, 2019, which was related to certain unproved leasehold costs in Oklahoma due to changes in development plans in the areas of Alfalfa, Major and Woods counties in Oklahoma.

Risk Management and Derivative

Risk Management and Derivative Instruments	12 Months Ended
	Dec. 31, 2020
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Risk Management and Derivative Instruments	Note 6. Risk Management and Derivative Instruments Derivative instruments are utilized to manage exposure to commodity price fluctuations and achieve a more predictable cash flow in connection with natural gas and oil sales from production. These transactions 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 and interest 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 our policy to enter into derivative contracts, only with creditworthy counterparties, which generally are financial institutions, deemed by management as competent and competitive market makers. Some of the lenders, or certain of their affiliates, under our previous and current credit agreement are counterparties to our 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. We have also entered into International Swaps and Derivatives Association Master Agreements (“ISDA Agreements”) with each of our counterparties. The terms of the ISDA Agreements provide us and each of our counterparties with rights of set-off upon the occurrence of defined acts of default by either us or our 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. At December 31, 2020, after taking into effect netting arrangements, we had no counterparty exposure related to our derivative instruments. As a result, had all counterparties failed completely to perform according to the terms of the existing contracts, we would have the right to offset $2.1 million against amounts outstanding under our Revolving Credit Facility at December 31, 2020. See Note 9 for additional information regarding our Revolving Credit Facility. Commodity Derivatives A combination of commodity derivatives (e.g., floating-for-fixed swaps, put options, costless collars, and three-way collars) is used to manage exposure to commodity price volatility. In April 2020, the Company monetized a portion of its 2021 crude oil hedges for total cash proceeds of approximately $18.0 million. We enter into natural gas derivative contracts that are indexed to NYMEX Henry Hub. We also enter into oil derivative contracts indexed to either NYMEX WTI or Inter-Continental Exchange (“ICE”) Brent. Our NGL derivative contracts are indexed to Oil Price Information Service Mont Belvieu. At December 31, 20 20 , the Company had the following open commodity positions: 2021 2022 Natural Gas Derivative Contracts: Fixed price swap contracts: Average monthly volume (MMBtu) 925,000 590,000 Weighted-average fixed price $ 2.49 $ 2.48 Collar contracts: Two-way collars Average monthly volume (MMBtu) 925,000 595,000 Weighted-average floor price $ 2.10 $ 2.37 Weighted-average ceiling price $ 3.28 $ 3.09 Natural Gas Basis Swaps: PEPL basis swaps: Average monthly volume (MMBtu) 500,000 — Weighted-average spread $ (0.40 ) $ — Crude Oil Derivative Contracts: Fixed price swap contracts: Average monthly volume (Bbls) 181,250 40,000 Weighted-average fixed price $ 45.84 $ 52.39 Collar contracts: Three-way collars Average monthly volume (Bbls) 42,500 76,000 Weighted-average ceiling price $ 50.61 $ 53.18 Weighted-average floor price $ 40.00 $ 40.00 Weighted-average sub-floor price $ 30.00 $ 31.32 NGL Derivative Contracts: Fixed price swap contracts: Average monthly volume (Bbls) 22,800 — Weighted-average fixed price $ 24.25 $ — Interest Rate Swaps Periodically, we enter into interest rate swaps to mitigate exposure to market rate fluctuations by converting variable interest rates such as those in our credit agreement to fixed interest rates. At December 31, 2020, we had the following interest rate swaps open positions: 2021 2022 Average Monthly Notional (in thousands) $ 125,000 $ 75,000 Weighted-average fixed rate 1.612 % 1.281 % Floating rate 1 Month LIBOR 1 Month LIBOR 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 December 31, 2020 and 2019. There was no cash collateral received or pledged associated with our derivative instruments since most of the counterparties, or certain of their affiliates, to our derivative contracts are lenders under our Credit Agreement (as defined below). Asset Derivatives Liability Derivatives Asset Derivatives Liability Derivatives December 31, December 31, December 31, December 31, Type Balance Sheet Location 2020 2020 2019 2019 (In thousands) Commodity contracts Short-term derivative instruments $ 6,088 $ 15,007 $ 11,518 $ 5,887 Interest rate swaps Short-term derivative instruments — 1,905 248 253 Gross fair value 6,088 16,912 11,766 6,140 Netting arrangements (6,088 ) (6,088 ) (5,887 ) (5,887 ) Net recorded fair value Short-term derivative instruments $ — $ 10,824 $ 5,879 $ 253 Commodity contracts Long-term derivative instruments $ 9,361 $ 8,488 $ 6,990 $ 973 Interest rate swaps Long-term derivative instruments — 847 347 305 Gross fair value 9,361 9,335 7,337 1,278 Netting arrangements (8,488 ) (8,488 ) (973 ) (973 ) Net recorded fair value Long-term derivative instruments $ 873 $ 847 $ 6,364 $ 305 (Gains) Losses on Derivatives We do 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 statements of operations. The following table details the gains and losses related to derivative instruments for the periods indicated (in thousands): For the Year Ended Statements of December 31, Operations Location 2020 2019 Commodity derivative contracts (Gain) loss on commodity derivatives $ (60,671 ) $ 6,700 (Gain) loss on interest rate derivatives Interest expense, net 4,044 (224 )

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2020
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Note 7. Asset Retirement Obligations The Company’s asset retirement obligations primarily relate to the Company’s portion of future plugging and abandonment of wells and related facilities. The following table presents the changes in the asset retirement obligations for the years ended December 31, 2020 and 2019 (in thousands): For the Year Ended December 31, 2020 2019 Asset retirement obligations at beginning of period $ 91,089 $ 76,344 Liabilities added from acquisition or drilling (1) 79 9,497 Liabilities removed upon sale of wells — — Liabilities settled (327 ) (259 ) Accretion expense 6,206 5,559 Revision of estimates 102 (52 ) Asset retirement obligation at end of period 97,149 91,089 Less: Current Portion 424 623 Asset retirement obligations - long-term portion $ 96,725 $ 90,466 (1) The increase in liabilities added from acquisition or drilling for the year ended December 31, 2019, is primarily due to the Merger with Midstates.

Restricted Investments

Restricted Investments	12 Months Ended
	Dec. 31, 2020
Investments Debt And Equity Securities [Abstract]
Restricted Investments	Note 8. Restricted Investments Various restricted investment accounts fund certain long-term contractual and regulatory asset retirement obligations and collateralize certain regulatory bonds associated with the offshore Southern California oil and gas properties. The components of the restricted investment balances are as follows: December 31, 2020 2019 (In thousands) BOEM platform abandonment (See Note 16) $ 313 $ 313 SPBPC Collateral: Contractual pipeline and surface facilities abandonment 4,310 4,309 Restricted investments $ 4,623 $ 4,622 On June 24, 2019, the Company received the release of $90.0 million from the Beta Decommissioning Trust Account. See Note 16 for additional information related to the Beta Decommissioning Trust Account.

Debt

Debt	12 Months Ended
	Dec. 31, 2020
Debt Disclosure [Abstract]
Debt	Note 9. Debt Our consolidated debt obligations consisted of the following at the dates indicated: December 31, December 31, 2020 2019 (In thousands) Revolving Credit Facility (1) $ 255,000 $ 285,000 Paycheck Protection Program loan 5,516 — Total long-term debt $ 260,516 $ 285,000 (1) The carrying amount of our Revolving Credit Facility approximates fair value because the interest rates are variable and reflective of market rates. Revolving Credit Facility On November 2, 2018, OLLC and Amplify Acquisitionco, Inc. (“Acquistionco”) entered into a credit agreement (the “Credit Agreement”), providing for a reserve-based revolving credit facility (the “Revolving Credit Facility”), subject to a borrowing base of $260.0 million as of December 31, 2020, which is guaranteed by us and all of our current subsidiaries. The Credit Agreement matures on November 2, 2023. The borrowing base under the Company’s Credit Agreement is subject to redetermination on at least a semi-annual basis based on an engineering report with respect to our estimated oil, NGL and natural gas reserves, which will take into account the prevailing oil, NGL and natural gas prices at such time, as adjusted for the impact of commodity derivative contracts. Unanimous approval by the lenders is required for any increase to the borrowing base. The terms and conditions under the original Credit Agreement include (but are not limited to) the following: • at OLLC’s option, borrowings under the Credit Agreement will bear interest at the base rate, LIBOR Market Index rate or LIBOR plus an applicable margin. Base rate loans bear interest at a rate per annum equal to the greatest of: (i) the federal funds effective rate plus 50 basis points, (ii) the rate of interest in effect for each day as publicly announced from time to time by the Agent as its “prime rate”; and (iii) the adjusted LIBOR rate for a one-month • the obligations under the Revolving Credit Facility are secured by mortgages on not less than 85% of the PV-9 value of oil and gas properties (and at least 85% of the PV-9 value of the proved, developed and producing oil and gas properties) included in the determination of the borrowing base. OLLC and its other subsidiaries entered into a pledge and security agreement in favor of the Agent for the secured parties, pursuant to which OLLC’s obligations under the Credit Agreement are secured by a first priority security interest in substantially all of our assets (subject to permitted liens). Additionally, the Company entered into a non-recourse pledge agreement in favor of the Agent for the secured parties, pursuant to which OLLC’s obligations under the Credit Agreement are secured by a pledge and security interest of 100% of the equity interests held by the Company in Acquisitionco; • 0.5 • certain financial covenants, including the maintenance of (i) as of the date of determination, a maximum total debt to EBITDAX ratio of 4.00 to 1.00, and (ii) a current ratio of not less than 1.00 to 1.00; and • 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. Borrowing Base Redetermination Agreement and Fourth Amendment On November 17, 2020, the Company entered into the Borrowing Base Redetermination Agreement and Fourth Amendment to Credit Agreement, among the Borrower, Amplify Acquisitionco LLC, a Delaware limited liability company, the guarantors party thereto, the lenders party thereto and Bank of Montreal, as administrative agent (the “Fourth Amendment”). The Fourth Amendment amended the parties’ existing Credit Agreement, to among other things: • reaffirm the borrowing base under the Credit Agreement at $260.0 million; and • modify the affirmative hedging covenant to include at least 65% and 45% hedge for calendar years 2021 and 2022 on a total proved developed producing reserves, respectively The foregoing description of the Fourth Amendment is qualified in its entirety by reference to the Fourth Amendment, which is attached as Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on November 18, 2020. Borrowing Base Redetermination Agreement and Third Amendment On June 12, 2020, the Company entered into the Borrowing Base Redetermination Agreement and Third Amendment to Credit Agreement, among the Borrower, Amplify Acquisitionco LLC, a Delaware limited liability company, the guarantors party thereto, the lenders party thereto and Bank of Montreal, as administrative agent (the “Third Amendment”). The Third Amendment amended the parties’ existing Credit Agreement, to among other things: • reduce the borrowing base under the Credit Agreement from $450.0 million to $285.0 million, with monthly reductions of $5.0 million thereafter until the borrowing base is reduced to $260.0 million, effective November 1, 2020; • increase the amount of first priority liens on all assets from at least 85% to 90%; • the applicable margin for LIBOR loans and LIBOR Market loans increased from 200 to 300 basis points to 250 to 350 basis points. • suspend certain financial covenants for the quarter ended June 30, 2020 • amend the definition of “Consolidated EBITDAX” in the Credit Agreement to decrease the limit of cash and cash equivalents permitted from $30.0 million to $25.0 million and increase the limit of transaction-related expense add-backs from $5.0 million to $20.0 million; • increase the minimum hedging requirements to at least 30% - 60% of our estimated production from total proved developed producing reserves; • incorporate a mandatory prepayment at times when cash and cash equivalents (as defined in the Credit Agreement) on hand exceed $25.0 million for five consecutive business days; and • amend certain other covenants and provisions. The foregoing description of the Third Amendment is qualified in its entirety by reference to the Third Amendment, which is attached as Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on June 15, 2020. Borrowing Base Redetermination On November 8, 2019, as part of the Company’s fall 2019 semiannual borrowing base redetermination, the borrowing base and lender commitments under the Company’s Credit Agreement among wholly owned subsidiaries of the Company, Bank of Montreal, as administrative agent, and other lenders party thereto was decreased from $530.0 million to $450.0 million. Joinder Agreement In connection with the Merger, on August 6, 2019, Amplify Energy Operating LLC and Amplify Acquisitionco LLC entered into a Borrowing Base Redetermination, Commitment Increase and Joinder Agreement to Credit Agreement, with the guarantors party thereto, the lenders party thereto and Bank of Montreal, as administrative agent (the “Joinder Agreement”). The Joinder Agreement amended the Revolving Credit Facility to, among other things: • redetermine the borrowing base of the Revolving Credit Facility, by increasing the borrowing base from $425.0 million to $530.0 million; • increase the commitments of certain of the original lenders under the Revolving Credit Facility; and • add additional lenders as parties to the Revolving Credit Facility. Upon closing of the Merger on August 6, 2019, Midstates’ existing reserve-based revolving credit facility was terminated, and all remaining borrowings were repaid by the Company. The foregoing description of the Joinder Agreement is qualified in its entirety by reference to the Joinder Agreement, which is attached as Exhibit 10.1 to Legacy Amplify’s Current Report on Form 8-K filed on August 6, 2019. Second Amendment to Revolving Credit Facility On July 16, 2019, OLLC entered into the Second Amendment to Credit Agreement (the “Second Amendment”), among OLLC, Acquisitionco, Amplify Energy, the guarantors party thereto, the lenders party thereto and the Administrative Agent. The Second Amendment amended the parties’ existing Credit Agreement, dated as of November 2, 2018, in connection with the completion of the Merger, following which Midstates may contribute, through a series of transactions, the equity interests it holds in Midstates Petroleum Company, LLC, a Delaware limited liability company, to the borrower (the “Contribution”), to, among other things, (i) provide that if the Merger and the Contribution are not consummated on or prior to August 31, 2019, the Administrative Agent and the lenders have the right (but not the obligation) to redetermine the borrowing base on or after September 1, 2019 and (ii) amend certain other provisions of the Revolving Credit Facility. The Second Amendment also contains customary representations, warranties and agreements of OLLC and the guarantors. All other material terms and conditions of the Revolving Credit Facility were unchanged by the Second Amendment. The foregoing description of the Second Amendment is qualified in its entirety by reference to the Second Amendment, which is attached as Exhibit 10.1 to Legacy Amplify’s current report on Form 8-K filed on July 17, 2019. First Amendment to Revolving Credit Facility On May 5, 2019, OLLC entered into the First Amendment to Credit Agreement (the “First Amendment”), among OLLC, Acquisitionco, Amplify Energy, the guarantors party thereto, the lenders party thereto and Bank of Montreal, as administrative agent. (the “Administrative Agent”). The First Amendment amended the Revolving Credit Facility to, among other things, (i) modify certain defined terms in connection with the completion of the transactions contemplated by the Merger Agreement, including the Merger; (ii) allow certain structural changes for tax planning activities; and (iii) modify certain covenants in the Revolving Credit Facility that restrict Amplify Energy’s ability to take certain actions or engage in certain business such that, once the First Amendment is effective, the occurrence of such actions or business in connection with the Merger Agreement or completion of the transactions contemplated thereby, including the Merger, will not be so restricted. Certain of the modifications to the Revolving Credit Facility, including those permitting pre-Merger tax restrictions, became effective upon the signing of the First Amendment. The remaining modifications become effective concurrently with the consummation of the Merger, subject to certain closing conditions. The First Amendment also contains customary representations, warranties and agreements of OLLC and the guarantors. All other material terms and conditions of the Revolving Credit Facility were unchanged by the First Amendment. The foregoing description of the First Amendment is qualified in its entirety by reference to the First Amendment, which is attached as Exhibit 10.1 to Legacy Amplify’s current report on Form 8-K filed on May 6, 2019. Debt Compliance As of December 31, 2020, we were in compliance with all the financial (current ratio and total leverage ratio) and other covenants associated with our Revolving Credit Facility. Paycheck Protection Program On April 24, 2020, the Company received a $5.5 million loan under the Paycheck Protection Program (the “PPP Loan”). The Paycheck Protection Program was established as part of the Coronavirus Aid, Relief, and Economic Security Act (“CARES Act”) to provide loans to qualifying businesses. The loans and accrued interest are potentially forgivable provided that the borrower uses the loan proceeds for eligible purposes. At this time, the Company anticipates that a substantial majority of the loan proceeds will be forgiven under the program. The term of the Company’s PPP Loan is two years with an annual interest rate of 1% and no payments of principal or interest due during the six-month period beginning on the date of the PPP Loan. Weighted-Average Interest Rates The following table presents the weighted-average interest rates paid on variable-rate debt obligations for the periods presented: For the Year Ended December 31, 2020 2019 Revolving Credit Facility 3.63% 4.76% Letters of credit At December 31, 2020, we had no letters of credit outstanding. Unamortized Deferred Financing Costs Unamortized deferred financing costs associated with our Revolving Credit Facility was $1.6 million at December 31, 2020. The unamortized deferred financing costs are amortized over the remaining life of our Revolving Credit Facility using the straight-line method which generally approximate the effective interest method. For the year ended December 31, 2020, we wrote-off $2.4 million of deferred financing costs in connection with the decrease in our borrowing base.

Equity (Deficit)

Equity (Deficit)	12 Months Ended
	Dec. 31, 2020
Equity [Abstract]
Equity (Deficit)	Note 10. Equity (Deficit) Equity Outstanding The Company’s authorized capital stock includes 250,000,000 shares of common stock, $0.01 par value per share. The following table summarizes the changes in the number of outstanding common units and shares of common stock: Common Shares Balance, December 31, 2018 22,181,881 Issuance of common stock — Restricted stock units vested 412,938 Repurchase of common shares (1) (120,163 ) Common stock repurchased and retired under share repurchase program (169,400 ) Balance, June 30, 2019 22,305,256 Restricted stock units vested 38,181 Repurchase of common shares (1) (9,427 ) Balance, August 5, 2019 22,334,010 Ratio to convert Amplify shares 0.933 Common stock issued to Legacy Amplify stockholders 20,837,633 Midstates stock outstanding and acquired with the Merger 20,415,005 Treasury shares acquired from the Merger 205,861 Restricted stock units vested 682,552 Repurchase of common shares (1) (31,697 ) Common stock repurchased and retired under share repurchase program (4,195,247 ) Cancelation and retirement of shares (347,567 ) Balance, December 31, 2019 37,566,540 Issuance of common stock — Restricted stock units vested 132,237 Repurchase of common shares (1) (35,268 ) Balance, December 31, 2020 37,663,509 (1) Represents the net settlement on vesting of restricted stock necessary to satisfy the minimum statutory tax withholding requirements. Warrants In connection with the Merger, Legacy Amplify entered into a warrant agreement (the “Warrant Agreement”) with American Stock Transfer & Trust Company, LLC, as warrant agent (“AST”), pursuant to which Legacy Amplify issued warrants to purchase up to 2,173,913 shares of Legacy Amplify’s common stock (representing 8% of Legacy Amplify’s outstanding common stock as of the Effective Date including shares of Legacy Amplify’s common stock issuable upon full exercise of the warrants, but excluding any common stock issuable under the Legacy Amplify’s Management Incentive Plan), exercisable for a five year period commencing on the Effective Date at an exercise price of $42.60 per share. The fair values for the warrants upon issuance on the Effective Date have been estimated using the Black-Scholes option pricing model using the following assumptions: Warrants Issued in Successor Period Risk-free interest rate 2.06 % Dividend yield — Expected life (in years) 5.0 Expected volatility 50.0 % Strike Price $ 42.60 Calculated fair value $ 2.20 On the effective date of the Merger, Legacy Amplify, Midstates and AST entered into an Assignment and Assumption Agreement, pursuant to which the Company agreed to assume Legacy Amplify’s Warrant Agreement. In connection with the Merger in August 2019, the Company assumed outstanding warrants of 4,647,520 Third Lien Notes Warrants at an exercise price of $22.78 per share (the “Third Lien Warrants”) and 2,332,089 Unsecured Creditor Warrants at an exercise price of $43.67 per share (the “Unsecured Creditor Warrants” and collectively with the Third Lien Warrants, the “Warrants”). The Warrants expired on April 21, 2020. Treasury Stock As of August 6, 2019, the Company assumed the outstanding treasury shares held by Midstates of 205,861 treasury shares outstanding. After the Merger closed, the Company retired and cancelled all treasury stock outstanding. No treasury stock remained outstanding at December 31, 2020 and 2019, respectively. Share Repurchase Program In connection, with the closing of the Merger, the board of directors approved the commencement of an open market share repurchase program of up to $25.0 million of the Company’s outstanding shares of common stock, with repurchases beginning on or after August 6, 2019. For the period from August 6, 2019 to December 31, 2019, the Company repurchased 4,195,247 shares of common stock at an average price of $6.28 per share for a total cost of approximately $24.9 million. The share repurchase program was terminated on December 31. 2019. On December 21, 2018, Legacy Amplify’s board of directors authorized the repurchase of up to $25.0 million of Legacy Amplify’s outstanding shares of common stock, with repurchases to begin on or after January 9, 2019. During the six months ended June 30, 2019, Legacy Amplify repurchased 169,400 shares of common stock at an average price of $7.35 per share for a total cost of approximately $1.3 million. On April 18, 2019, in anticipation of the Merger, Legacy Amplify terminated the repurchase program. Cash Dividend Payment On March 3, 2020, our board of directors approved a dividend of $0.10 per share of outstanding common stock or $3.8 million in aggregate, which was paid on March 30, 2020, to stockholders of record at the close of business on March 16, 2020. The board of directors subsequently suspended quarterly dividends. Future dividends, if any, are subject to debt covenants under our Revolving Credit Facility and discretionary approval by the board of directors. On November 5, 2019, our board of directors approved a dividend of $0.20 per share of outstanding common stock or $7.7 million in aggregate, which was paid on December 18, 2019, to stockholders of record at the close of business on December 4, 2019. On August 6, 2019, our board of directors approved a dividend of $0.20 per share of outstanding common stock or $8.2 million in aggregate, which was paid on September 18, 2019, to stockholders of record at the close of business on September 4, 2019.

Earnings per Share

Earnings per Share	12 Months Ended
	Dec. 31, 2020
Earnings Per Share [Abstract]
Earnings per Share	Note 11. Earnings 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 Year Ended December 31, 2020 2019 Net income (loss) $ (464,030 ) $ (35,197 ) Less: Net income (loss) allocated to participating restricted stockholders — — Basic and diluted earnings available to common stockholders $ (464,030 ) $ (35,197 ) Common shares: Common shares outstanding — basic 37,612 29,301 Dilutive effect of potential common shares — — Common shares outstanding — diluted 37,612 29,301 Net earnings (loss) per share: Basic $ (12.34 ) $ (1.20 ) Diluted $ (12.34 ) $ (1.20 ) Antidilutive warrants (1) 2,174 9,154 (1) Amount represents warrants to purchase common stock that are excluded from the diluted net earnings per share calculations because of their antidilutive effect.

Equity-based Awards

Equity-based Awards	12 Months Ended
	Dec. 31, 2020
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Equity-based Awards	Note 12. Equity-based Awards Merger Impact As of August 6, 2019, each outstanding share of Legacy Amplify common stock, par value $0.0001 per share, available for issuance under the Amplify Energy Corp. 2017 Non-Employee Directors Compensation Plan (the “Legacy Amplify Non-Employee Directors Compensation Plan”) and the Amplify Energy Corp. Management Incentive Plan (the “Legacy Amplify MIP” and, together with the Legacy Amplify Non-Employee Directors Compensation Plan, the “Legacy Amplify Plans”) was converted and assumed by the Company and will be available for future issuance under the Legacy Amplify Plans in satisfaction of the vesting, exercise or other settlement of options and other equity awards that may be granted by the Company following the close of the Merger (after conversion of such shares and appropriate adjustment to reflect the terms of the Merger Agreement). Legacy Amplify stockholders received 0.933 shares of newly issued Company common stock for each share of Legacy Amplify common stock that they owned. The table below shows the activity related to the Legacy Amplify MIP prior to and after the closing of the Merger, which reflects the conversion of outstanding and unvested equity awards. Legacy Amplify MIP awards are 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 Legacy Amplify MIP is expired, forfeited or cancelled for any reason without having been exercised in full, the unexercised award would then be available again for future grants under the Legacy Amplify MIP. The Legacy Amplify MIP is administered by the board of directors of the Company. At December 31, 2020, 1,046,698 shares remain available for issuance under the Legacy Amplify MIP. On October 21, 2016, Midstates established the 2016 Long-term Incentive Plan (“Midstates 2016 LTIP”) shares for issuance under the terms of the Midstates 2016 LTIP to employees and directors. The types of awards that may be granted under the Midstates 2016 LTIP include stock options, restricted stock units, restricted stock, performance awards and other forms of awards granted or denominated in shares of common stock, as well as certain cash-based awards. To the extent that an award under the Midstates 2016 LTIP is expired, forfeited or are cancelled for any reason without having been exercised in full, the unexercised award would then be available again for future grants under the Midstates 2016 LTIP. After the effective date of the Merger, the Midstates 2016 LTIP shares are available for issuance to employees and directors of the Company. At December 31, 2020, 2,167,996 shares remain available for issuance under the Midstates 2016 LTIP. Restricted Stock Units Restricted Stock Units with Service Vesting Condition Restricted stock units with service vesting conditions (“TSUs”) are accounted for as equity-classified awards. The grant-date fair value is recognized as compensation cost on a straight-line basis over the requisite service period and forfeitures are accounted for as they occur. Compensation costs are recorded as general and administrative expense. The unrecognized cost associated with TSUs was $0.3 million at December 31, 2020. We expect to recognize the unrecognized compensation cost for these awards over a weighted-average period of 1.3 years. The following table summarizes information regarding the TSUs granted under the Legacy Amplify MIP for the period presented: Weighted- Average Grant Number of Date Fair Value Units per Unit (1) TSUs outstanding at December 31, 2018 598,024 $ 11.35 Granted (2) 300,517 $ 6.80 Forfeited (38,151 ) $ 11.13 Vested (437,834 ) $ 8.71 TSUs outstanding at August 5, 2019 422,556 $ 10.87 Ratio to convert TSUs (3) 0.933 Converted TSUs 394,245 TSUs outstanding at August 6, 2019 (4) 394,245 $ 5.12 Granted (5) 17,500 $ 6.14 Forfeited (38,652 ) $ 5.12 Vested (81,723 ) $ 5.12 TSUs outstanding at December 31, 2019 291,370 $ 5.18 Granted (6) 43,250 $ 3.10 Forfeited (93,845 ) $ 5.12 Vested (124,978 ) $ 5.17 TSUs outstanding at December 31, 2020 115,797 $ 4.47 (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 period from January 1, 2019 through August 5, 2019 was $2.0 million based on a grant date market price ranging from $4.48 to $8.70 per share. ( 3 ) The merger ratio used to convert Legacy Amplify TSUs into newly issued TSUs. ( 4 ) This reflects the unvested TSUs converted into newly issued Company’s TSUs at August 6, 2019 at a stock price of $5.12 per share. ( 5 ) The aggregate grant date fair value of TSUs issued for the period August 6, 2019 through December 31, 2019 was $0.1 million based on a grant date market price of $6.14 per share. ( 6 ) The aggregate grant date fair value of TSUs issued for the year ended December 31, 2020 was $0.1 million based on a grant date market price ranging from $0.54 to $6.61 per share. Restricted Stock Units with Market and Service Vesting Conditions Restricted stock units with market and service vesting conditions (“PSUs”) are accounted for as equity-classified awards. The grant-date fair value is recognized as compensation cost on a graded-vesting basis. As such, the Company recognizes compensation cost over the requisite service period for each separately vesting tranche of the award as though the award were, in substance, multiple awards. The Company accounts for forfeitures as they occur. Compensation costs are recorded as general and administrative expense. The unrecognized cost related to the PSUs was $0.1 million at December 31, 2020. We expect to recognize the unrecognized compensation cost for these awards over a weighted-average period of approximately 1.4 years. The PSUs will vest based on the satisfaction of service and market vesting conditions with market vesting based on the Company’s achievement of certain share price targets. The PSUs are subject to service-based vesting such that 50% of the PSUs service vest on the applicable market vesting date and an additional 25% of the PSUs service vest on each of the first and second anniversaries of the applicable market vesting date. In the event of a qualifying termination, subject to certain conditions, (i) all PSUs that have satisfied the market vesting conditions will fully service vest, upon such termination, and (ii) if the termination occurs between the second and third anniversaries of the grant date, then PSUs that have not market vested as of the termination will market vest to the extent that the share targets (in each case, reduced by $0.25) are achieved as of such termination. Subject to the foregoing, any unvested PSUs will be forfeited upon termination of employment. A Monte Carlo simulation was used to determine the fair value of these awards at the grant date. The assumptions used to estimate the fair value of the PSUs are as follows: Share price targets $ 12.50 $ 15.00 $ 17.50 Risk-free interest rate: Awards Issued on January 1, 2020 and April 1, 2020 1.61 % 1.61 % 1.61 % Dividend yield Awards Issued on January 1, 2020 and April 1, 2020 12.1 % 12.1 % 12.1 % Expected volatility: Awards Issued on January 1, 2020 and April 1, 2020 60.0 % 60.0 % 60.0 % Calculated fair value per PSU: Awards Issued on January 1, 2020 and April 1, 2020 $ 3.66 $ 2.98 $ 2.46 Share price targets $ 12.50 $ 15.00 $ 17.50 Risk-free interest rate: Awards Issued on January 1, 2019 2.44 % 2.44 % 2.44 % Awards Issued on April 1, 2019 2.28 % 2.28 % 2.28 % Awards Issued on July 1, 2019 1.73 % 1.73 % 1.73 % Awards Issued on October 1, 2019 1.50 % 1.50 % 1.50 % Dividend yield — — — Expected volatility: Awards Issued on January 1, 2019 54.0 % 54.0 % 54.0 % Awards Issued on April 1, 2019 50.0 % 50.0 % 50.0 % Awards Issued on July 1, 2019 57.0 % 57.0 % 57.0 % Awards Issued on October 1, 2019 65.0 % 65.0 % 65.0 % Calculated fair value per PSU: Awards Issued on January 1, 2019 $ 6.76 $ 5.86 $ 5.11 Awards Issued on April 1, 2019 $ 4.22 $ 3.43 $ 2.80 Awards Issued on July 1, 2019 $ 2.63 $ 2.05 $ 1.64 Awards Issued on October 1, 2019 $ 3.40 $ 2.83 $ 2.38 The following table summarizes information regarding the PSUs granted under the Legacy Amplify MIP for the period presented: Weighted- Average Grant Number of Date Fair Value Units per Unit (1) PSUs outstanding at December 31, 2018 393,500 $ 8.14 Granted (2) 17,750 $ 4.06 Forfeited (22,750 ) $ 7.59 Vested — $ — PSUs outstanding at August 5, 2019 388,500 $ 7.98 Ratio to convert PSUs (3) 0.933 Converted PSUs 362,471 PSUs outstanding on August 6, 2019 (4) 362,471 $ 2.11 Granted (5) 17,500 $ 2.87 Forfeited (74,078 ) $ 2.11 Vested — $ — PSUs outstanding at December 31, 2019 305,893 $ 2.15 Granted (6) 43,250 $ 3.03 Forfeited (134,589 ) $ 2.11 Vested — $ — PSUs outstanding at December 31, 2020 214,554 $ 2.36 (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 period January 1, 2019 through August 5, 2019 was less than $0.1 million based on a calculated fair value price ranging from $1.64 to $6.76 per share. ( 3 ) The merger ratio used to convert Legacy Amplify PSUs into newly issued Company PSUs. ( 4 ) This reflects the unvested PSU awards converted into newly issued PSUs at August 6, 2019 based on a calculated fair value price ranging from $1.64 to $2.63 per share. ( 5 ) The aggregate grant date fair value of PSUs issued for the period August 6, 2019 through December 31, 2019 was less than $0.1 million based on a calculated fair value price ranging from $2.38 to $3.40 per share. ( 6 ) The aggregate grant date fair value of PSUs issued for the year ended December 31, 2020 was $0.1 million based on a calculated fair value price ranging from $2.46 to $3.66 per share. 2017 Non-Employee Directors Compensation Plan In June 2017, in connection with the Plan, Legacy Amplify implemented the Legacy Amplify Non-Employee Directors Compensation Plan to attract and retain services of experienced non-employee directors of the Company or its subsidiaries. At December 31, 2020, 104,503 shares remain available for issuance under the Legacy Amplify Non-Employee Directors Compensation Plan. The Legacy Amplify Non-Employee Directors Compensation Plan awards are granted in the form of nonqualified stock options, restricted stock awards, restricted stock units, and other cash-based awards and stock-based awards. To the extent that an award under the Legacy Amplify Non-Employee Directors Compensation Plan is expired, forfeited or cancelled for any reason without having been exercised in full, the unexercised award would then be available again for grant under the Legacy Amplify Non-Employee Directors Compensation Plan. Awards granted generally vest annually in three equal installments on each of the first three anniversaries of the grant date, subject to the grantee’s continued employment through each such vesting date. The restricted stock units with a service vesting condition (“Board RSUs”) granted are accounted for as equity-classified awards. The grant-date fair value is recognized as compensation cost on a straight-line basis over the requisite service period and forfeitures are accounted for as they occur. Compensation costs are recorded as general and administrative expense. The unrecognized cost associated with Board RSUs was less than $0.1 million at December 31, 2020. We expect to recognize the unrecognized compensation cost for these awards over a weighted-average period of 1.3 years. The following table summarizes information regarding the Board RSUs granted under the Director Compensation Plan for the period presented: Weighted- Average Grant Number of Date Fair Value Units per Unit (1) Board RSUs outstanding at December 31, 2018 39,604 $ 11.36 Granted (2) 42,933 $ 6.95 Forfeited — $ — Vested (49,723 ) $ 9.54 Board RSUs outstanding at August 5, 2019 32,814 $ 8.35 Ratio to convert Board RSUs (3) 0.933 Converted Board RSUs 30,616 Board RSUs outstanding on August 6, 2019 (4) 30,616 $ 5.12 Granted — $ — Forfeited — $ — Vested (14,459 ) $ 5.12 Board RSUs outstanding at December 31, 2019 16,157 $ 5.12 Granted — $ — Forfeited — $ — Vested (7,259 ) $ 5.12 Board RSUs outstanding at December 31, 2020 8,898 $ 5.12 (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 Board RSUs issued for the period from January 1, 2019 through August 5, 2019 was $0.3 million based on a grant date market price of $6.95 per share. (3) The merger ratio used to convert Legacy Amplify Board RSUs into newly issued Company Board RSUs. (4) This reflects the unvested Board RSU awards converted into newly issued Board RSUs at August 6, 2019 in which the stock price was at $5.12 per share. Midstates Restricted Stock Units Midstates restricted stock units are accounted for as equity-classified awards. Restricted stock units granted to employees in 2019 under the Midstates 2016 LTIP would have vested in full on March 1, 2021, or upon the occurrence of a change in control. Upon the closing of the Merger all restricted stock units outstanding vested. On August 5, 2019 Midstates had 585,547 restricted stock units outstanding related to employees and certain executive management and in connection with the Merger all outstanding restricted stock units vested. No restricted stock units were outstanding at December 31, 2019. Midstates 2019 Performance Stock Units Issued to Certain Members of Executive Management Containing a Market Condition On March 7, 2019, Midstates issued 193,921 restricted stock units to certain members of Midstates executive management team that contained a market vesting condition. Midstates previously accounted for these restricted stock awards as equity awards. In connection with the Merger all 193,921 restricted stock units issued were cancelled and no shares were outstanding at December 31, 2019. Midstates Stock Options The Midstates stock options are accounted for as equity-classified awards. Stock Option awards outstanding under the Midstates 2016 LTIP would have vested ratably over a period of three years: one-sixth vest on the six-month anniversary of the grant date, an additional one-sixth vest on the twelve-month anniversary of the grant date, an additional one-third vest on the twenty-four month anniversary of the grant date and the final one-third vest on the thirty-six month anniversary of the grant date. Stock Option awards expire 10 years from the grant date. On August 5, 2019, Midstates had 54,365 stock options outstanding and in connection with the Merger all outstanding stock options vested. No stock options were outstanding at December 31, 2019. Midstates Non-Employee Director Restricted Stock Units Containing a Market Condition On November 23, 2016, Midstates issued restricted stock units to non-employee directors that contained a market vesting condition. Midstates previously recognized the non-employee director restricted stock units containing a market condition as liability awards. On August 5, 2019, Midstates had 50,864 market condition awards outstanding and in connection with the Merger all restricted stock units to non-employee directors that contained a market vesting condition vested. No shares were outstanding at December 31, 2019 related to non-employee director restricted stock units containing a market condition. Compensation Expense The following table summarizes the amount of recognized compensation expense associated with these awards that are reflected in the accompanying statements of operations for the periods presented (in thousands): For the Year Ended December 31, 2020 2019 Equity classified awards TSUs $ 267 $ 1,797 PSUs 98 981 Board RSUs 19 264 $ 384 $ 3,042

Leases

Leases	12 Months Ended
	Dec. 31, 2020
Leases [Abstract]
Leases	Note 13. Leases The Company adopted ASU 842, leases, on January 1, 2019 using the modified retrospective approach with a cumulative impact to retained earnings. The adoption of this standard has resulted in an increase in the assets and liabilities on the Company’s Condensed Consolidated Balance Sheet. The Company has completed the review and evaluation of current and potential leases which resulted primarily in our corporate office lease and some minor equipment and vehicle leases qualifying under the new guidance. Based upon this analysis, the impact of the new guidance established a liability and the corresponding asset of $5.4 million at January 1, 2019. For the year ended December 31, 2020, our leases qualify as operating leases and we did not have any existing or new leases qualifying as financing leases. We have leases for office space and equipment in our corporate office and operating regions as well as vehicles, compressors and surface rentals related to our business operations. In addition, we have offshore Southern California pipeline right-of-way use agreements. Most of our leases, other than our 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 our leases can be terminated with 30-day prior written notice. The majority of our month-to-month leases are not included as a lease liability in our balance sheet under ASC 842 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. Our corporate office lease does not provide an implicit rate. To determine the present value of the lease payments, we use our incremental borrowing rate based on the information available at the inception date. To determine the incremental borrowing rate, we apply a portfolio approach based on the applicable lease terms and the current economic environment. We use a reasonable market interest rate for our office equipment and vehicle leases. For the year ended December 31, 2020 and 2019, we recognized approximately $2.4 million and $2.1 million, respectively, of costs relating to the operating leases in the Statements of Consolidated Operations. The following table presents the Company’s right-of-use assets and lease liabilities for the period presented: December 31, December 31, 2020 2019 (In thousands) Right-of-use asset $ 2,500 $ 4,406 Lease liabilities: Current lease liability 2,258 1,712 Long-term lease liability 266 2,720 Total lease liability $ 2,524 $ 4,432 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 leases Leased vehicles and office equipment Total 2021 $ 1,631 $ 634 $ 2,265 2022 140 157 297 2023 — 35 35 2024 and thereafter — — — Total lease payments 1,771 826 2,597 Less: interest 51 22 73 Present value of lease liabilities $ 1,720 $ 804 $ 2,524 The weighted average remaining lease terms and discount rate for all of our operating leases for the period presented: December 31, 2020 2019 Weighted average remaining lease term (years): Office leases 0.74 1.50 Vehicles 0.34 0.44 Office equipment 0.04 0.08 Weighted average discount rate: Office leases 3.41 % 3.63 % Vehicles 0.96 % 0.84 % Office equipment 0.17 % 0.18 % During the year ended December 31, 2019, the Company recorded a $4.2 million loss on lease, which relates to the Midstates corporate office lease. The office was vacated in mid-November 2019. Due to excess sublease inventory in the local market, a liability has been accrued for rent and other operating expenses based upon the term and provisions of the lease.

Supplemental Disclosures to the

Supplemental Disclosures to the Consolidated Balance Sheet and Condensed Statement of Cash Flows	12 Months Ended
	Dec. 31, 2020
Supplemental Disclosures To Condensed Consolidated Statements Of Cash Flows [Abstract]
Supplemental Disclosures to the Consolidated Balance Sheet and Condensed Statement of Cash Flows	Note 14. Supplemental Disclosures to the Consolidated Balance Sheet and Condensed Statement of Cash Flows Accrued Liabilities Current accrued liabilities consisted of the following at the dates indicated (in thousands): December 31, December 31, 2020 2019 Accrued lease operating expense $ 8,978 $ 11,794 Accrued commitment fee and other expense 4,404 — Accrued general and administrative expense 3,349 3,126 Operating lease liability 2,258 1,712 Accrued production and ad valorem tax 2,601 520 Accrued capital expenditures 173 5,515 Asset retirement obligations 424 623 Accrued current income taxes 110 — Accrued interest payable 26 36 Other 354 32 Accrued liabilities $ 22,677 $ 23,358 Cash and Cash Equivalents Reconciliation The following table provides a reconciliation of cash and cash equivalents on the Consolidated Balance Sheet to cash, cash equivalents and restricted cash on the Statements of Consolidated Cash Flows (in thousands): December 31, December 31, 2020 2019 Cash and cash equivalents $ 10,364 $ — Restricted cash — 325 Total cash, cash equivalents and restricted cash $ 10,364 $ 325 Supplemental Cash Flows Supplemental cash flow for the periods presented (in thousands): For the Year Ended December 31, 2020 2019 Supplemental cash flows: Cash paid for interest, net of amounts capitalized $ 10,331 $ 15,937 Cash paid for reorganization items, net 566 1,057 Cash paid for taxes 85 — Noncash investing and financing activities: Change in capital expenditures in payables and accrued liabilities (5,343 ) 2,143 Assumption of asset retirement obligations related to Merger — 9,440 Assets acquired & liabilities assumed in the Merger: Accounts receivable — 14,633 Prepaids and other current assets — 3,229 Other non-current assets — 9,075 Oil and natural gas properties — 149,421 Other property and equipment — 1,694 Accounts payable and other current liabilities — (24,135 ) Other non-current liabilities — (5,067 ) Long-term debt — (76,559 ) Issuance of common stock in connection with the Merger — 91,541

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2020
Related Party Transactions [Abstract]
Related Party Transactions	Note 15. Related Party Transactions Related Party Agreements There have been no transactions between us and a related person in which the related person had a direct or indirect material interest for the year ended December 31, 2020 and 2019, respectively. Secondary Public Offering of Common Stock for Selling Stockholders On December 11, 2020, certain selling stockholders of the Company (the “Selling Stockholders”), Roth Capital Partners, LLC (the “Underwriter”) and the Company entered into an underwriting agreement, pursuant to which the Selling Stockholders agreed to sell to the Underwriter, and the Underwriter agreed to purchase from the Selling Stockholders, subject to and upon the terms and conditions set forth therein, an aggregate of 8,548,485 shares of Common Stock. The offering closed on December 15, 2020. The Company did not receive any proceeds from the sale of shares of Common Stock in the offering. The offering was made pursuant to effective shelf registration statements (File No. 333-233677, effective October 11, 2019, and 333-215602, effective May 1, 2018) and prospectuses filed by the Company with the SEC. The offering of these securities was made only by means of a prospectus and prospectus supplement.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2020
Commitments And Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 16. Commitments and Contingencies Litigation and Environmental As part of our normal business activities, we may be named as defendants in litigation and legal proceedings, including those arising from regulatory and environmental matters. We are not aware of any litigation, pending or threatened, that we believe will have a material adverse effect on our financial position, results of operations or cash flows; however, cash flow could be significantly impacted in the reporting periods in which such matters are resolved. Although we are insured against various risks to the extent we believe it is prudent, there is no assurance that the nature and amount of such insurance will be adequate, in every case, to indemnify us 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 December 31, 2020 and 2019, we had no environmental reserves recorded. Application for Final Decree On April 30, 2018, the Legacy Amplify debtors filed with the Bankruptcy Court a motion for a final decree and entry of an order closing the Chapter 11 cases with respect to each of the Legacy Amplify debtors other than (i) San Pedro Bay Pipeline Company, Ch. 11 Case No. 17-30249, (ii) Rise Energy Beta, LLC, Ch. 11 Case No. 17-30250, and (iii) Beta Operating Company, LLC, Ch. 11 Case No. 17-30253, (collectively, the “Closing Debtors”). On May 30, 2018, the Bankruptcy Court entered the final decree closing the Chapter 11 cases of the Closing Debtors. On August 24, 2020, the Legacy Amplify debtors filed with the Bankruptcy Court a motion for a final decree closing the remaining Chapter 11 cases with respect to (i) San Pedro Bay Pipeline Company, Ch. 11 Case No. 17-30249, (ii) Rise Energy Beta, LLC, Ch. 11 Case No. 17-30250, and (iii) Beta Operating Company, LLC, Ch. 11 Case No. 17-30253. On September 15, 2020, the Bankruptcy Court entered the final decree closing the remaining Chapter 11 cases. Accordingly, certain expenses, gains and losses that were realized or incurred in the bankruptcy proceedings are recorded in “reorganization items, net” on the Company’s Statement of Consolidated Operations. Sinking Fund Trust Agreement Beta Operating Company, LLC (“Beta”), a wholly owned subsidiary, assumed an obligation with a third party to make payments into a sinking fund in connection with its 2009 acquisition of our 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. Under the terms of the agreement, the operator of the properties is obligated to make monthly deposits into the sinking fund account in an amount equal to $0.25 per barrel of oil and other liquid hydrocarbon produced from the acquired working interest. 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 December 31, 2020, the account balance included in restricted investments was approximately $4.6 million. Supplemental Bond for Decommissioning Liabilities Trust Agreement Beta has an obligation with the BOEM in connection with the 2009 acquisition of the Beta Properties. The Company had previously supported this obligation with $71.3 million of A-rated surety bonds and $90.2 million in cash, but $90.0 million of cash was released to the Company on June 24, 2019. Following the release, Beta’s decommissioning obligations remain fully supported by $161.3 million in A-rated surety bonds and $0.3 million in cash at December 31, 2020. Pursuant to the terms of our existing bonding arrangements with various sureties in connection with the decommissioning obligations related to our Beta Properties, we may be required to post collateral at any time, on demand, at the sureties’ sole discretion, which may negatively impact our liquidity position. The expense related to the surety bonds are recorded in interest expense in our Statement of Consolidated Operations. Operating Leases We have leases for offshore Southern California pipeline right-of-way use as well as office space in our operating regions. We also lease equipment, compressors and incur surface rentals related to our business operations. For the years ended December 31, 2020 and 2019, we recognized $8.3 million and $7.5 million of rent expense, respectively. See Note 13 for the minimum lease payment obligations under non-cancelable operating leases with a remaining term in excess of one year. Purchase Commitments At December 31, 2020, we had a CO 2 2 2 Payment or Settlement Due by Period Purchase commitment Total 2021 2022 2023 2024 2025 Thereafter CO 2 $ 6,969 $ 3,729 $ 3,240 $ — $ — $ — $ — Minimum Volume Commitment At December 31, 2020, we had a long-term minimum volume commitments with third parties associated with a certain portion of our properties located in Oklahoma and East Texas. The table below outlines the future payment commitments associated with the minimum volume commitment plus any applicable fee for not meeting the minimum volume commitment (in thousands): Payment or Settlement Due by Period (1) Minimum volume commitment Total 2021 2022 2023 2024 2025 Thereafter Midstream services $ 28,193 $ 12,841 $ 12,394 $ 2,958 $ — $ — $ — (1) The amounts in the table do not reflect costs adjusted for inflation. The Company is party to a gas purchase, gathering and processing contract in Oklahoma, which includes certain minimum NGL commitments. To the extent the Company does not deliver natural gas volumes in sufficient quantities to generate, when processed, the minimum levels of recovered NGLS, it would be required to reimburse the counterparty an amount equal to sum of the monthly shortfall, if any, multiplied by a fee. Beginning in June 2019, the Company started not meeting the minimum volume required under these contractual provisions. The commitment fee expense for the year ended December 31, 2020, was approximately $2.1 million. The commitment fee/expense for the period from June through December 2019 was $0.7 million. The Company is party to a gas purchase, gathering and processing contract in East Texas, which includes certain minimum gas commitments. The Company notes that a shortfall had occurred for the year ended December 31, 2020 and has established an accrual for the commitment fee expense of $1.8 million.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2020
Income Tax Disclosure [Abstract]
Income Tax	Note 17. Income Tax Amplify Energy is a corporation and as a result, is subject to U.S. federal, state and local income taxes. In response to the COVID-19 pandemic, the President of the United States signed into law the CARES Act in March 2020. The CARES Act adjusted a number of provisions of the tax code, including interest deduction limitations, the treatment of net operating losses, and tax credits. The enactment of the CARES Act did not result in any material adjustments to the Company’s current year income tax provision. The components of income tax benefit (expense) are as follows: For the Year Ended December 31, 2020 2019 (In thousands) Current taxes: Federal $ (5 ) $ — State (110 ) 50 Total current income tax benefit (expense) (115 ) 50 Deferred taxes: Federal — — State — — Total deferred income tax benefit (expense) — — Total income tax benefit (expense) $ (115 ) $ 50 The actual income tax benefit (expense) differs from the expected amount computed by applying the federal statutory corporate tax rate of 21% in 2020 and in 2019 as follows: For the Year Ended December 31, 2020 2019 (In thousands) Expected tax benefit (expense) at federal statutory rate $ 97,423 $ 7,402 State income tax benefit (expense), net of federal benefit 6,189 946 Non-deductible expenses (45 ) (3,659 ) Changes in valuation allowances (110,445 ) (4,332 ) State rate change, net of federal benefit 6,100 — Non-cash compensation (137 ) (367 ) Other 800 60 Total income tax benefit (expense) $ (115 ) $ 50 The Company’s deferred tax position reflects the net tax effects of the temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax reporting. Significant components of the deferred tax assets and liabilities are as follows (in thousands): December 31, December 31, 2020 2019 Deferred income tax assets: Property, Plant & Equipment $ 115,695 $ 37,075 Net operating loss carryforward 174,479 141,534 Derivatives 2,448 — Disallowed interest expense 5,388 10,627 Accrued liabilities 1,226 1,431 Other 1,717 4,234 Total deferred income tax assets: 300,953 194,901 Valuation allowance (300,386 ) (189,941 ) Net deferred income tax assets 567 4,960 Deferred income tax liabilities: Derivatives $ — $ 2,767 Other 567 2,193 Total deferred income tax liabilities 567 4,960 Net deferred income tax liabilities $ — $ — As of December 31, 2020, the Company had approximately $732.1 million of federal net operating loss (“NOL”) carryovers of which $710.1 million have no expiration date and the remaining will expire in year 2037. In connection with the Merger with Midstates in 2019, the Company is subject to IRC §382 loss limitation on pre-merger NOL and tax attributes. The amount of 2020 federal NOL carryover generated post-merger, and not subject to §382 loss limitation, is $31.6 million. As of December 31, 2020, the Company had approximately $420.3 million of state net operating loss carryovers of which $367.3 million have no expiration period and the remaining will expire in varying amounts beginning in 2037. In assessing deferred tax assets, the Company considers whether a valuation allowance should be recorded for some or all of the deferred tax assets which may not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which the temporary differences become deductible. Among other items, the Company considers the scheduled reversal of deferred tax liabilities, projected future taxable income and available tax planning strategies. A valuation allowance is established against deferred tax assets for which management believes realization is considered to be more likely than not that all of the deferred tax assets will not be realized. As of December 31, 2020, a valuation allowance of $300.4 million had been recorded which is an increase to the valuation allowance of $110.5 million from the prior year. Uncertain Income Tax Position. We must recognize the tax effects of any uncertain tax positions we may adopt if the position taken by us is more likely than not sustainable based on its technical merits. For those benefits to be recognized, an income tax position must be more-likely-than-not to be sustained upon examination by taxing authorities. We had no unrecognized tax benefits as of December 31, 2020. Tax Audits and Settlements. Notification was received from the Internal Revenue Service (IRS) during the year that the examination of our 2017 federal income tax return was complete with no change to reported tax. Our income tax years 2018 through 20 20 remain open and subject to examination by the IRS . For state and local jurisdictions, our 2017 through 20 20 tax years remain open and subject to examination where we conduct operations . In certain jurisdictions we operate through more than one legal entity, each of which may have different open years subject to examination.

Supplemental Oil and Gas Inform

Supplemental Oil and Gas Information (Unaudited)	12 Months Ended
	Dec. 31, 2020
Extractive Industries [Abstract]
Supplemental Oil and Gas Information (Unaudited)	N ote 18. Supplemental Oil and Gas Information (Unaudited) Capitalized Costs Relating to Oil and Natural Gas Producing Activities The total amount of capitalized costs relating to oil and natural gas producing activities and the total amount of related accumulated depreciation, depletion and amortization is as follows at the dates indicated. December 31, December 31, 2020 2019 (In thousands) Evaluated oil and natural gas properties $ 775,167 $ 797,005 Support equipment and facilities 142,208 140,023 Accumulated depletion, depreciation, and amortization (602,861 ) (136,747 ) Total $ 314,514 $ 800,281 Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development Activities Costs incurred in property acquisition, exploration and development activities were as follows for the periods indicated: For the Year Ended December 31, 2020 2019 (In thousands) Property acquisition costs, proved $ 42 $ 150,871 Property acquisition costs, unproved (49,307 ) 7,674 Exploration — — Development 29,543 71,460 Total $ (19,722 ) $ 230,005 Standardized Measure of Discounted Future Net Cash Flows from Proved Reserves As required by the FASB and SEC, the standardized measure of discounted future net cash flows presented below is computed by applying first-day-of-the-month average prices, year-end costs and legislated tax rates and a discount factor of 10 percent to proved reserves. We do not believe the standardized measure provides a reliable estimate of the Company’s expected future cash flows to be obtained from the development and production of its oil and gas properties or of the value of its proved oil and gas reserves. The standardized measure is prepared on the basis of certain prescribed assumptions including first-day-of-the-month average prices, which represent discrete points in time and therefore may cause significant variability in cash flows from year to year as prices change. Oil and Natural Gas Reserves Users of this information should be aware that the process of estimating quantities of “proved” and “proved developed” oil and natural gas reserves is very complex, requiring significant subjective decisions in the evaluation of all available geological, engineering and economic data for each reservoir. The data for a given reservoir may also change substantially over time as a result of numerous factors including, but not limited to, additional development activity, evolving production history and continual reassessment of the viability of production under varying economic conditions. As a result, revisions to existing reserve estimates may occur from time to time. Although every reasonable effort is made to ensure reserve estimates reported represent the most accurate assessments possible, the subjective decisions and variances in available data for various reservoirs make these estimates generally less precise than other estimates included in the financial statement disclosures. Proved reserves are those quantities of oil and natural gas that 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. We engaged CG&A to prepare our reserves estimates for all of our estimated proved reserves at December 31, 2020 and 2019. All proved reserves are located in the United States and all prices are held constant in accordance with SEC rules. The weighted-average benchmark product prices used for valuing the reserves are based upon the average of the first-day-of-the-month price for each month within the period January through December of each year presented: 2020 2019 Oil ($/Bbl): WTI (1) $ 39.57 $ 55.69 NGL ($/Bbl): WTI (1) $ 39.57 $ 55.69 Natural Gas ($/MMbtu): Henry Hub (2) $ 1.99 $ 2.58 (1) The weighted average WTI price was adjusted by lease for quality, transportation fees, and a regional price differential. (2) The weighted average Henry Hub price was adjusted by lease for energy content, compression charges, transportation fees, and regional price differentials. The following tables set forth estimates of the net reserves for the periods indicated: For the Year Ended December 31, 2020 Oil Gas NGLs Total (MBbls) (MMcf) (MBbls) (MBoe) Proved developed and undeveloped reserves: Beginning of year 70,772 377,869 29,252 163,002 Extensions and discoveries 291 655 61 461 Production (3,887 ) (27,473 ) (1,725 ) (10,190 ) Revision of previous estimates (20,500 ) (76,912 ) (6,104 ) (39,424 ) End of year 46,676 274,139 21,484 113,849 Proved developed reserves: Beginning of year 53,476 320,731 23,646 130,577 End of year 35,613 252,218 19,009 96,658 Proved undeveloped reserves: Beginning of year 17,296 57,138 5,606 32,425 End of year 11,063 21,921 2,475 17,191 For the Year Ended December 31, 2019 Oil Gas NGLs Total (MBbls) (MMcf) (MBbls) (MBoe) Proved developed and undeveloped reserves: Beginning of period 69,624 293,959 21,572 140,189 Extensions and discoveries 301 576 44 441 Purchase of minerals in place 17,429 202,409 18,533 69,697 Production (3,498 ) (26,489 ) (1,343 ) (9,256 ) Revision of previous estimates (13,084 ) (92,586 ) (9,554 ) (38,069 ) End of period 70,772 377,869 29,252 163,002 Proved developed reserves: Beginning of period 54,147 232,110 17,324 110,156 End of period 53,476 320,731 23,646 130,577 Proved undeveloped reserves: Beginning of period 15,477 61,849 4,248 30,033 End of period 17,296 57,138 5,606 32,425 Noteworthy amounts included in the categories of proved reserve changes in the above tables include: • The 49.2 MMBoe reduction in reserves for the year ended December 31, 2020 is primarily due to a 50.1 MMBoe downward pricing revision offset by 10.7 MMBoe upward revision primarily due to lower maintenance costs and Special Royalty Relief on our offshore Southern California assets. We added 0.46 MMBoe during the year ended December 31, 2020 due to extensions and discoveries. • The 22.8 MMBoe increase in reserves for the year ended December 31, 2019 is primarily due to the Merger in which we acquired 69.7 MMBoe partially offset by downward pricing revision of a 25.9 MMBoe and a downward revision of 12.1 MMBoe due to updated well performance data and future anticipated maintenance cost increases. See Note 4 for additional information on acquisitions. A variety of methodologies are used to determine our proved reserve estimates. The principal methodologies employed are reservoir simulation, decline curve analysis, volumetric, material balance, advance production type curve matching, petro-physics/log analysis and analogy. Some combination of these methods is used to determine reserve estimates in substantially all of our fields. The standardized measure of discounted future net cash flows is as follows: For the Year Ended December 31, 2020 2019 (In thousands) Future cash inflows $ 2,410,260 $ 5,146,288 Future production costs (1) (1,589,945 ) (2,917,262 ) Future development costs (1) (375,146 ) (567,423 ) Future income tax expense — — Future net cash flows for estimated timing of cash flows 445,169 1,661,603 10% annual discount for estimated timing of cash flows (147,358 ) (745,042 ) Standardized measure of discounted future net cash flows $ 297,811 $ 916,561 (1) For the year ended December 31, 2020, onshore abandonment costs are included in future production cost and offshore abandonment costs are included in future development costs. Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves The following is a summary of the changes in the standardized measure of discounted future net cash flows for the proved oil and natural gas reserves during each of the years in the two year period presented: For the Year Ended December 31, 2020 2019 (In thousands) Beginning of year $ 916,561 $ 1,113,029 Sale of oil and natural gas produced, net of production costs (47,687 ) (113,545 ) Purchase of minerals in place — 408,370 Extensions and discoveries 3,687 5,334 Changes in prices and costs (548,429 ) (623,592 ) Previously estimated development costs incurred 49,144 84,341 Net changes in future development costs 89,997 110,892 Revisions of previous quantities (150,245 ) (183,300 ) Accretion of discount 91,657 92,998 Change in production rates and other (106,874 ) 22,034 End of year $ 297,811 $ 916,561

Organization and Basis of Pre_2

Organization and Basis of Presentation (Policies)	12 Months Ended
	Dec. 31, 2020
Accounting Policies [Abstract]
General	General On August 6, 2019, Midstates Petroleum Company, Inc., a Delaware corporation (“Midstates”), completed its business combination (the “Merger”) with Amplify Energy Corp. (“Legacy Amplify”), in accordance with the terms of that certain Agreement and Plan of Merger, dated May 5, 2019 (the “Merger Agreement”), by and among Midstates, Legacy Amplify and Midstates Holdings, Inc., a Delaware corporation and direct, wholly owned subsidiary of Midstates (“Merger Sub”). Pursuant to the terms of the Merger Agreement, Merger Sub merged with and into Legacy Amplify, with Legacy Amplify surviving the Merger as a wholly owned subsidiary of Midstates, and immediately following the Merger, Legacy Amplify merged with and into Alpha Mike Holdings LLC, a Delaware limited liability company and wholly owned subsidiary of Midstates (“LLC Sub”), with LLC Sub surviving as a wholly owned subsidiary of Midstates. On the effective date of the Merger, Midstates changed its name to “Amplify Energy Corp.” (the “Company”) and LLC Sub changed its name to “Amplify Energy Holdings LLC.” For financial reporting purposes, the Merger represented a “reverse merger” and Legacy Amplify was deemed to be the accounting acquirer in the transaction. Legacy Amplify’s historical results of operations replaced Midstates’ historical results of operations for all periods prior to the Merger and, for all periods following the Merger, the Company’s financial statements reflect the results of operations of the combined company. Accordingly, the financial statements for the Company included in this annual report for periods prior to the Merger are not the same as Midstates prior reported filings with the SEC, which were derived from the operations of Midstates. When referring to Legacy Amplify, the intent is to refer to Amplify Energy Corp. prior to the Merger, and its consolidated subsidiaries as a whole or on an individual basis, depending on the context in which the statements are made. 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 one reportable business segment as there are not different economic environments within the operation of our oil and natural gas properties. Our assets consist primarily of producing oil and natural gas properties located in Oklahoma, the Rockies, federal waters offshore Southern California, East Texas/North Louisiana and the Eagle Ford. Most of our 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	Basis of Presentation Material intercompany transactions and balances have been eliminated in preparation of our Consolidated Financial Statements. The accompanying Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). The Consolidated Financial Statements have been prepared as if the Company is a going concern and reflect the application of Accounting Standards Codification 852 “Reorganizations” (“ASC 852”).
Risk and Uncertainties	Risk and Uncertainties In March 2020, the World Health Organization declared a global pandemic related to the proliferation of COVID-19. The impact of COVID-19 and efforts to mitigate its spread have caused significant volatility in U.S. and international markets and a substantial reduction in global and domestic demand for oil and natural gas. Actions by governmental authorities to mitigate the spread of COVID-19, such as imposing mandatory closures of all non-essential business facilities, seeking voluntary closures of business facilities, and imposing restrictions on, or advisories with respect to, travel, business operations and public gatherings or interactions, have further exacerbated the economic impact of the pandemic. As a result of the pandemic, there has also been a sharp reduction in the demand for oil and natural gas and a precipitous decline in commodity prices, which were further impacted by disputes over production levels among oil-producing countries, the significant increase in production levels by such countries and limited storage capacity for natural gas, oil and refined products. The reductions in commodity prices have resulted in lower levels of cash flow from operating activities. In addition, the borrowing base under our Revolving Credit Facility (as defined below) is subject to redetermination on at least a semi-annual basis primarily based on an engineering report with respect to our estimated oil and natural gas reserves, which takes into account the prevailing oil and natural gas prices at such time, as adjusted for the impact of our commodity derivative contracts. Severely reduced commodity prices contributed to a reduction in our borrowing base during the Spring 2020 redetermination process, and continued low prices may adversely impact subsequent redeterminations. The reduction in commodity prices has directly led to an impairment of our oil and natural gas properties. There may be further impairments in future periods if commodity prices do not fully recover. Despite the gradual recover y in commodity prices in the second half of 2020, the expectation of a successful phased rollout of a vaccine in 2021, and the successful realization and execution of our liquidity enhancing initiatives and disciplined hedging program, there remains significant uncertainty around the breadth and duration of business disruptions related to COVID-19, as well as its impact on the U.S. and international economies and, as such, the Company is unable to determine the extent of the impact caused by the COVID-19 pandemic to the Company’s operations.
Use of Estimates	Use of Estimates The preparation of 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; depreciation, depletion and amortization of proved oil and natural gas properties; future cash flows from oil and natural gas properties; impairment of long-lived assets; fair value of derivatives; fair value of equity compensation; fair values of assets acquired and liabilities assumed in business combinations and asset retirement obligations.
Business Combinations	Business Combinations Accounting for the acquisition of a business requires the identifiable assets and liabilities acquired to be recorded at fair value. The most significant assumptions in a business combination include those used to estimate the fair value of the oil and gas properties acquired. The fair value of proved natural gas properties is determined using a risk-adjusted after-tax discounted cash flow analysis based upon significant assumptions including commodity prices; projections of estimated quantities of reserves; projections of future rates of production; timing and amount of future development and operating costs; projected reserve recovery factors; and a weighted average cost of capital. The Company utilizes a market approach to estimate the fair value of unproved properties acquired in a business combination which requires the Company to use judgment in considering the value per undeveloped acre in recent comparable transactions to estimate the value of unproved properties.
Cash and Cash Equivalents	Cash and Cash Equivalents Cash and cash equivalents represent unrestricted cash on hand and all highly liquid investments with original contractual maturities of three months or less.
Concentrations of Credit Risk	Concentrations of Credit Risk Cash balances, accounts receivable, restricted investments and derivative financial instruments are financial instruments potentially subject to credit risk. Cash and cash equivalents are maintained in bank deposit accounts which, at times, may exceed the federally insured limits. Management periodically reviews and assesses the financial condition of the banks to mitigate the risk of loss. Various restricted investment accounts fund certain long-term contractual and regulatory asset retirement obligations and collateralize certain regulatory bonds associated with the offshore Southern California oil and gas properties. These restricted investments consist of money market deposit accounts which are held with credit-worthy financial institutions. Derivative financial instruments are generally executed with major financial institutions that expose us to market and credit risks and which may, at times, be concentrated with certain counterparties. The credit worthiness of the counterparties is subject to continual review. We rely upon netting arrangements with counterparties to reduce credit exposure. Oil and natural gas are sold to a variety of purchasers, including intrastate and interstate pipelines or their marketing affiliates and independent marketing companies. Accounts receivable from joint operations are from a number of oil and natural gas companies, individuals and others who own interests in the properties operated by us. Generally, operators of crude oil and natural gas properties have the right to offset future revenues against unpaid charges related to operated wells, minimizing the credit risk associated with these receivables. An allowance for doubtful accounts is recorded after all reasonable efforts have been exhausted to collect or settle the amount owed. Any amounts outstanding longer than the contractual terms are considered past due. We recorded $1.5 million as an allowance for doubtful accounts at December 31, 2020 and 2019. If we were to lose any one of our customers, the loss could temporarily delay the production and the sale of oil and natural gas in the related producing region. If we were to lose any single customer, we believe that a substitute customer to purchase the impacted production volumes could be identified. The following individual customers each accounted for 10% or more of total reported revenues for the period indicated: For the Year Ended December 31, 2020 2019 Major customers: Phillips 66 23% 27% Sinclair Oil & Gas Company 21% 21% BP America Production Company 17% 13%
Oil and Natural Gas Properties	Oil and Natural Gas Properties Oil and natural gas exploration, development and production activities are accounted for in accordance with the successful efforts method of accounting. Under this method, costs of acquiring properties, costs of drilling successful exploration wells and development costs are capitalized. The costs of exploratory wells are initially capitalized pending a determination of whether proved reserves have been found. At the completion of drilling activities, the costs of exploratory wells remain capitalized if determination is made that proved reserves have been found. If no proved reserves have been found, the costs of each of the related exploratory wells are charged to expense. In some cases, a determination of proved reserves cannot be made at the completion of drilling, requiring additional testing and evaluation of the wells. The costs of such exploratory wells are expensed if a determination of proved reserves has not been made within a twelve-month period after drilling is complete. Exploration costs such as geological, geophysical, seismic costs and delay rental payments attributable to unproved locations are expensed as incurred. As exploration and development work progresses and the reserves on these properties are proven, capitalized costs attributed to the properties are subject to depreciation and depletion. Depletion of capitalized costs is provided using the units-of-production method based on proved oil and gas reserves related to the associated field. Capitalized drilling and development costs of producing oil and natural gas properties are depleted over proved developed reserves and leasehold costs are depleted over total proved reserves. Support equipment and facilities, which are primarily related to our Wyoming and California assets, are depreciated using the straight-line method generally based on estimated useful lives of twelve to twenty-four years. On the sale or retirement of a complete or partial unit of a proved property or pipeline and related facilities, the cost and related accumulated depreciation, depletion, and amortization are removed from the property accounts, and any gain or loss is recognized. There were no material capitalized exploratory drilling costs pending evaluation at December 31, 2020 and 2019.
Oil and Natural Gas Reserves	Oil and Natural Gas Reserves The estimates of proved oil and natural gas reserves utilized in the preparation of the Consolidated Financial Statements are estimated in accordance with the rules established by the SEC and the Financial Accounting Standards Board (“FASB”). These rules require that reserve estimates be prepared under existing economic and operating conditions using a trailing 12-month average price with no provision for price and cost escalations in future years except by contractual arrangements. The development of the Company’s oil and natural gas reserve quantities require management to make significant estimates and assumptions related to the intent and ability to complete undeveloped proved reserves within a five-year development period, as prescribed by SEC guidelines. Additionally, none of our PUDs are scheduled to be developed on a date more than five years from the date the reserves were initially booked as PUD as prescribed by the SEC guidelines. PUDs are converted from undeveloped to developed as applicable wells begin production. We engaged Cawley, Gillespie and Associates, Inc. (“CG&A”), our independent reserve engineers, to prepare our reserves estimates for all of our estimated proved reserves at December 31, 2020 and 2019. Reserve estimates are inherently imprecise. Accordingly, the estimates are expected to change as more current information becomes available. It is possible that, because of changes in market conditions or the inherent imprecision of reserve estimates, the estimates of future cash inflows, future gross revenues, the amount of oil and natural gas reserves, the remaining estimated lives of oil and natural gas properties, or any combination of the above may be increased or decreased. Increases in recoverable economic volumes generally reduce per unit depletion rates while decreases in recoverable economic volumes generally increase per unit depletion rates.
Other Property & Equipment	Other Property & Equipment Other property and equipment is stated at historical cost and is comprised primarily of vehicles, furniture, fixtures, office build-out cost and computer hardware and software. Depreciation of other property and equipment is calculated using the straight-line method generally based on estimated useful lives of three to seven years.
Restricted Investments	Restricted Investments Various restricted investment accounts fund certain long-term contractual and regulatory asset retirement obligations and collateralize certain regulatory bonds associated with the offshore Southern California oil and gas properties. These investments are classified as held-to-maturity and such investments are stated at amortized cost. Interest earned on these investments is included in interest expense, net in the statement of operations. These restricted investments may consist of money market deposit accounts and U.S. Government securities. See Note 8 and Note 16 for additional information.
Debt Issuance Costs	Debt Issuance Costs
Impairments	Impairments Proved oil and natural gas properties are reviewed for impairment when events and circumstances indicate the carrying value of such properties may not be recoverable. This may be due to a downward revision of the reserve estimates, less than expected production, drilling results, higher operating and development costs, or lower commodity prices. The estimated undiscounted future cash flows expected in connection with the property are compared to the carrying value of the property to determine if the carrying amount is recoverable. If the carrying value of the property exceeds its estimated undiscounted future cash flows, the carrying amount of the property is reduced to its estimated fair value using Level 3 inputs. The factors used to determine fair value include, but are not limited to, estimates of proved and 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 gas properties. We recorded $427.6 million of impairment expense related to our proved properties for the year ended December 31, 2020. No impairment expense related to our proved properties was recorded for the year ended December 31, 2019. Unproved oil and natural gas properties are reviewed for impairment based on time or geologic factors. Information such as drilling results, reservoir performance, seismic interpretation or future plans to develop acreage is also considered. When unproved property investments are deemed to be impaired, the expense is reported in impairment expense. We recognized $49.3 million and $2.2 million in impairment expense related to our unproved properties for the years ended December 31, 2020 and 2019, respectively. For the year ended December 31, 2020 the impairment was related to expiring leases and the evaluation of qualitative and quantitative factors related to the current decline in commodity prices. For the year ended December 31, 2019, the impairment was for certain unproved leasehold costs. Significant declines in commodity prices, further changes to the Company’s drilling or development plans, reduction of proved and probable reserve estimates, or increases in drilling or operating costs could result in other additional future impairments to proved and unproved oil and gas properties.
Asset Retirement Obligations	Asset Retirement Obligations An asset retirement obligation associated with retiring long-lived assets is recognized as a liability on a discounted basis in the period in which the legal obligation is incurred and becomes determinable, with an equal amount capitalized as an addition to oil and natural gas properties, which is allocated to expense over the useful life of the asset. Generally, oil and gas producing companies incur such a liability upon acquiring or drilling a well. Accretion expense is recognized over time as the discounted liabilities are accreted to their expected settlement value. Upon settlement of the liability, a gain or loss is recognized in net income (loss) to the extent the actual costs differ from the recorded liability. See Note 7 for further discussion of asset retirement obligations.
Book Overdrafts	Book Overdrafts Book overdrafts, representing outstanding checks in excess of funds on deposit, are classified as accounts payable and the change in the related balance is reflected in operating activities in the statement of cash flows.
Revenue Recognition	Revenue Recognition Revenue from the sale of oil and natural gas is recognized when title passes, net of royalties due to third parties. Oil and natural gas revenues are recorded using the sales method. Under this method, revenues are recognized based on actual volumes of oil and natural gas sold to purchasers, regardless of whether the sales are proportionate to our ownership in the property. An asset or a liability is recognized to the extent there is an imbalance in excess of the proportionate share of the remaining recoverable reserves on the underlying properties. No significant imbalances existed at December 31, 2020 and 2019.
Derivative Instruments	Derivative Instruments Commodity derivative financial instruments (e.g., swaps, collars and puts) are used to reduce the impact of natural gas and oil price fluctuations. Every derivative instrument is recorded on the balance sheet as either an asset or liability measured at its fair value. Changes in the derivative’s fair value are recognized in earnings as we have not elected hedge accounting for any of our derivative positions.
Capitalized Interest	Capitalized Interest We capitalize interest costs to oil and gas properties on expenditures made in connection with certain projects such as drilling and completion of new oil and natural gas wells and major facility installations. Interest is capitalized only for the period that such activities are in progress. Interest is capitalized using a weighted average interest rate based on our outstanding borrowings. These capitalized costs are included with intangible drilling costs and amortized using the units of production method. We had $0.2 million in capitalized interest for the years ended December 31, 2020 and 2019, respectively.
Income Tax	Income Tax We are a corporation subject to federal and certain state income taxes. We use the asset and liability method of accounting for income taxes, under which deferred tax assets and liabilities are recognized for the future tax consequences of (1) temporary differences between the tax basis of assets and liabilities and their reported amounts in the financial statements and (2) operating loss and tax credit carryforwards. Deferred income tax assets and liabilities are based on enacted tax rates applicable to the future period when those temporary differences are expected to be recovered or settled. Deferred tax assets are reduced by a valuation allowance if, based on the weight of available evidence, it is more likely than not that some portion or all of deferred tax assets will not be realized. We recognize a tax benefit from an uncertain tax position when it is more likely than not that the position will be sustained upon examination by taxing authorities, based on the technical merits of the position. The tax benefit recorded is equal to the largest amount that is greater than 50% likely to be realized through effective settlement with a taxing authority. We recognize interest and penalties accrued to unrecognized tax benefits in other income (expense) in our Statement of Consolidated Operations. Although we believe our assumptions, judgements and estimates are reasonable, changes in tax laws or our interpretation of tax laws and the resolution of any tax audits could significantly impact the amounts provided for income taxes in our consolidated financial statements.
Earnings Per Share	Earnings (loss) Per Share Basic and diluted earnings (loss) per share (“EPS”) is determined by dividing net income (loss) available to the common stockholders by the weighted average number of outstanding shares during the period. Diluted earnings (loss) per common share is calculated under the two-class method and the treasury stock method by dividing net income (loss) available to common stockholders by the weighted average number of diluted common shares outstanding, which includes the effect of potentially dilutive securities. When a loss from continuing operations exists, all potentially dilutive securities are anti-dilutive and are therefore excluded from the computation of diluted earnings per share. See Note 11 for additional information.
Equity Compensation	Equity Compensation The fair value of equity-classified awards (e.g., restricted common unit awards, restricted stock units or stock options) is amortized to earnings over the requisite service or vesting period. Compensation expense for liability-classified awards (e.g., phantom units awards) are recognized over the requisite service or vesting period of an award based on the fair value of the award re-measured at each reporting period. We currently have awards subject to performance criteria; such awards would vest when it is probable that the performance criteria will be met and the requisite service period has been met. Generally, no compensation expense is recognized for equity instruments that do not vest. See Note 12 for further information.
Lease Recognition	Lease Recognition In February 2016, the FASB issued guidance regarding the accounting for leases. The FASB retained a dual model, requiring leases to be classified as either direct financing or operating leases. The classification will be based on criteria that are similar to the current lease accounting treatment. The Company is the lessee under various agreements for office space, compressors, equipment, vehicles and surface rentals (right of use assets) that are currently accounted for as operating leases. The Company applied the revised lease rules for our interim and annual reporting periods starting January 1, 2019 using the modified retrospective approach with a cumulative impact to retained earnings in that period, and including several optional practical expedients relating to leases commenced before the effective date. The practical expedients the Company adopted are: (1) the original correct assessment of a contract containing a lease will be accepted without further review on all existing or expired contracts; (2) the original lease classification as an operating lease will convert as an operating lease under the new guidance; (3) initial direct costs for any existing leases will not be reassessed; (4) existing land easements or right of use agreements will continue under current accounting policy and only new agreements will be evaluated in the future; and (5) short-term leases for twelve months or less will not be evaluated under the guidance. See Note 13 for additional information regarding the adoption of the leases standard.
Recently Adopted Accounting Pronouncements	Recently Adopted Accounting Pronouncements Current Expected Credit Losses In May 2019, the FASB issued an accounting standard update to provide entities with an option to irrevocably elect the fair value option applied on an instrument-by-instrument basis for certain financial assets upon the adoption of the guidance. The fair value option election does not apply to held-to-maturity debt securities. The Company adopted the guidance as of January 1, 2020. The Company has evaluated the impact of this guidance and concluded that the current and historical evaluation of estimated credit losses falls within the acceptable guidance. The provisions of the standard were interpreted to relate only to the Company’s accounts receivable, net. Trade receivables relate to one common pool, revenue earned on the sale of oil, natural gas and natural gas liquids. The performance obligation is satisfied at a point in time and revenue is recognized and a trade receivable is recorded from the sale when production is delivered to, and title has transferred to, the purchaser. The majority of the Company’s purchasers have been large major companies in the industry with the wherewithal to pay. The Company, as operator on most of our wells, also records receivables on billings to our joint interest owners who participate in the operating costs of the wells they have an interest in. Historically, an allowance for doubtful accounts has been set up to recognize credit losses on joint interest billing (“JIB”) receivables based upon an aging analysis, which is an appropriate method to estimate credit losses under the guidance. The Company will continue to assess the expected credit loss in the future as economic conditions change. Considering the recent drop in commodity prices, we believe the majority of our revenue purchasers have the size and financial condition to currently meet their obligations. There could be added risk on the JIB accounts receivable as some wells could become uneconomic, with the revenue not enough to cover operating expenses billed, which could result in additional write-offs. The Company will continue to closely monitor trade receivables. Based upon the analysis performed there was no impact to beginning retained earnings upon the adoption of the guidance. The Company’s monitoring activities include timely account reconciliation and balances are written off when determined to be uncollectible. The Company considered the market conditions surrounding the COVID-19 pandemic and determined that the estimate of credit losses was not significantly impacted. Fair Value Measurement . In August 2018, the FASB issued an amendment to modify the disclosure requirements on fair value measurements in Topic 820, Fair Value Measurement. Certain disclosure requirements were removed, modified and added and primarily relate to Level 3 hierarchy measurements and changes to non-public entities disclosures. The guidance is effective for all entities for fiscal years and interim periods within those fiscal years, beginning after December 15, 2019. The adoption of this guidance had no material impact on our consolidated financial statements.
New Accounting Pronouncements	New Accounting Pronouncements Income Taxes – Simplifying the Accounting for Income Taxes . In December 2019, the FASB issued an accounting standards update which simplifies the accounting for income taxes by removing certain exceptions to the general principles in Topic 740. This accounting standards update removes the following exceptions: (i) exception to the incremental approach for intraperiod tax allocation when there is a loss continuing operations and income or a gain from other items; (ii) exception to the requirements to recognize a deferred tax liability for equity method investments when a foreign subsidiary becomes an equity method investment; (iii) exception to the ability not to recognize a deferred tax liability for a foreign subsidiary when a foreign equity method investment becomes a subsidiary; and (iv) exception to the general methodology for calculating income taxes in an interim period when a year-to-date loss exceeds the anticipated loss for the year. The amendments in the accounting standards update also improve consistency and simplify other areas of Topic 740 by clarifying and amending existing guidance. The new guidance is effective for fiscal years and interim periods within those fiscal years, beginning after December 15, 2020. The Company is expecting to adopt the guidance January 1, 2021, with all of the anticipated and applicable effects to be required on a prospective basis. The adoption of this guidance does not expect to have a material impact on our consolidated financial statements. Reference Rate Reform . In March 2020, the FASB issued an accounting standard update which provides optional expedients and expectations for applying GAAP to contracts, hedging relationships, and other transactions to ease financial reporting burdens to the expected market transition from the London Interbank Offered Rate (“LIBOR”) or another reference rate to alternative reference rates. The amendments in this accounting standards update are effective beginning March 12, 2020, and an entity may elect to apply the amendments prospectively through December 31, 2022. The Company is currently evaluating the impact this guidance may have on the Company’s consolidated financial statements. Other accounting standards that have been issued by the FASB or other standards-setting bodies are not expected to have a material impact on the Company’s financial position, results of operations and cash flows.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2020
Accounting Policies [Abstract]
Major Customers	The following individual customers each accounted for 10% or more of total reported revenues for the period indicated: For the Year Ended December 31, 2020 2019 Major customers: Phillips 66 23% 27% Sinclair Oil & Gas Company 21% 21% BP America Production Company 17% 13%

Revenue (Tables)

Revenue (Tables)	12 Months Ended
	Dec. 31, 2020
Revenue From Contract With Customer [Abstract]
Summary of Revenues Disaggregated	We have identified three material revenue streams in our business: oil, natural gas and NGLs. The following table present our revenues disaggregated by revenue stream. For the Year Ended December 31, 2020 2019 (in thousands) Revenues Oil $ 138,273 $ 192,944 NGLs $ 20,064 $ 22,347 Natural gas $ 42,551 $ 59,316 Oil and natural gas sales $ 200,888 $ 274,607

Acquisitions and Divestitures (

Acquisitions and Divestitures (Tables)	12 Months Ended
	Dec. 31, 2020
Business Combinations [Abstract]
Acquisition and Divestiture Related Expenses	Acquisition and divestiture related expenses for third party transactions are included in general and administrative expenses in the accompanying statements of operations for the periods indicated below (in thousands): For the Year Ended December 31, 2020 2019 $ 1,092 $ 17,305
Summary of Preliminary Purchase Price Allocation to Identifiable Assets Acquired and Liabilities Assumed	The following table represents the allocation of the total purchase price of Midstates to the identifiable assets acquired and the liabilities assumed based on the fair values as of the acquisition date. Purchase Price Allocation (In thousands) Consideration: Fair value of Midstates common stock issued in the Merger (a) $ 90,150 Fair value of Midstates warrants issued in the Merger 2 Value of shares to be issued 90,152 Fair value of Legacy Amplify restricted share consideration 832 Fair value of Legacy Amplify PSU consideration 557 Total consideration $ 91,541 Fair value of liabilities assumed: Current liabilities $ 24,135 Long-term debt 76,559 Long-term asset retirement obligation 9,440 Other long-term liabilities 5,067 Amounts attributable to liabilities assumed $ 115,201 Fair value of assets acquired: Cash and cash equivalents $ 19,250 Other current assets 17,862 Oil and natural gas properties 149,421 Other property and equipment 1,694 Long-term asset retirement cost 9,440 Other non-current assets 9,075 Amounts attributable to assets acquired $ 206,742 Total identifiable net assets $ 91,541 (a) Based on 20,415,005 Midstates common shares issued at closing at $4.12 per share (closing price as of August 6, 2019).
Summary of Unaudited Pro Forma Financial Information	The following unaudited pro forma financial information for the year ended December 31, 2019, is based on our historical consolidated financial statements adjusted to reflect as if the Merger had occurred on January 1, 2018. For the Year Ended December 31, 2019 (Unaudited) (In thousands, except per unit amounts) Revenues $ 336,326 Net income (loss) (22,926 ) Earnings per share: Basic $ (0.78 ) Diluted $ (0.78 )

Fair Value Measurements of Fi_2

Fair Value Measurements of Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2020
Fair Value Disclosures [Abstract]
Assets and Liabilities Measured at Fair Value on Recurring Basis	The following table presents the derivative assets and liabilities that are measured at fair value on a recurring basis at December 31, 2020 and December 31, 2019 for each of the fair value hierarchy levels: Fair Value Measurements at December 31, 2020 Using Quoted Prices in Significant Other Significant Active Market Observable Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Fair Value (In thousands) Assets: Commodity derivatives $ — $ 15,449 $ — $ 15,449 Interest rate derivatives — — — — Total assets $ — $ 15,449 $ — $ 15,449 Liabilities: Commodity derivatives $ — $ 23,495 $ — $ 23,495 Interest rate derivatives — 2,752 — 2,752 Total liabilities $ — $ 26,247 $ — $ 26,247 Fair Value Measurements at December 31, 2019 Using Quoted Prices in Significant Other Significant Active Market Observable Inputs Unobservable Inputs (Level 1) (Level 2) (Level 3) Fair Value (In thousands) Assets: Commodity derivatives $ — $ 18,509 $ — $ 18,509 Interest rate derivatives — 595 — 595 Total assets $ — $ 19,104 $ — $ 19,104 Liabilities: Commodity derivatives $ — $ 6,861 $ — $ 6,861 Interest rate derivatives — 558 — 558 Total liabilities $ — $ 7,419 $ — $ 7,419

Risk Management and Derivativ_2

Risk Management and Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2020
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Open Commodity Positions	At December 31, 20 20 , the Company had the following open commodity positions: 2021 2022 Natural Gas Derivative Contracts: Fixed price swap contracts: Average monthly volume (MMBtu) 925,000 590,000 Weighted-average fixed price $ 2.49 $ 2.48 Collar contracts: Two-way collars Average monthly volume (MMBtu) 925,000 595,000 Weighted-average floor price $ 2.10 $ 2.37 Weighted-average ceiling price $ 3.28 $ 3.09 Natural Gas Basis Swaps: PEPL basis swaps: Average monthly volume (MMBtu) 500,000 — Weighted-average spread $ (0.40 ) $ — Crude Oil Derivative Contracts: Fixed price swap contracts: Average monthly volume (Bbls) 181,250 40,000 Weighted-average fixed price $ 45.84 $ 52.39 Collar contracts: Three-way collars Average monthly volume (Bbls) 42,500 76,000 Weighted-average ceiling price $ 50.61 $ 53.18 Weighted-average floor price $ 40.00 $ 40.00 Weighted-average sub-floor price $ 30.00 $ 31.32 NGL Derivative Contracts: Fixed price swap contracts: Average monthly volume (Bbls) 22,800 — Weighted-average fixed price $ 24.25 $ —
Interest Rate Swap Open Positions	2021 2022 Average Monthly Notional (in thousands) $ 125,000 $ 75,000 Weighted-average fixed rate 1.612 % 1.281 % Floating rate 1 Month LIBOR 1 Month LIBOR
Gross Fair Value of Derivative Instruments by Appropriate Balance Sheet	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 December 31, 2020 and 2019. There was no cash collateral received or pledged associated with our derivative instruments since most of the counterparties, or certain of their affiliates, to our derivative contracts are lenders under our Credit Agreement (as defined below). Asset Derivatives Liability Derivatives Asset Derivatives Liability Derivatives December 31, December 31, December 31, December 31, Type Balance Sheet Location 2020 2020 2019 2019 (In thousands) Commodity contracts Short-term derivative instruments $ 6,088 $ 15,007 $ 11,518 $ 5,887 Interest rate swaps Short-term derivative instruments — 1,905 248 253 Gross fair value 6,088 16,912 11,766 6,140 Netting arrangements (6,088 ) (6,088 ) (5,887 ) (5,887 ) Net recorded fair value Short-term derivative instruments $ — $ 10,824 $ 5,879 $ 253 Commodity contracts Long-term derivative instruments $ 9,361 $ 8,488 $ 6,990 $ 973 Interest rate swaps Long-term derivative instruments — 847 347 305 Gross fair value 9,361 9,335 7,337 1,278 Netting arrangements (8,488 ) (8,488 ) (973 ) (973 ) Net recorded fair value Long-term derivative instruments $ 873 $ 847 $ 6,364 $ 305
Unrealized and Realized Gains and Losses Related to Derivative Instruments	The following table details the gains and losses related to derivative instruments for the periods indicated (in thousands): For the Year Ended Statements of December 31, Operations Location 2020 2019 Commodity derivative contracts (Gain) loss on commodity derivatives $ (60,671 ) $ 6,700 (Gain) loss on interest rate derivatives Interest expense, net 4,044 (224 )

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2020
Asset Retirement Obligation Disclosure [Abstract]
Summary of Changes in Asset Retirement Obligations	The Company’s asset retirement obligations primarily relate to the Company’s portion of future plugging and abandonment of wells and related facilities. The following table presents the changes in the asset retirement obligations for the years ended December 31, 2020 and 2019 (in thousands): For the Year Ended December 31, 2020 2019 Asset retirement obligations at beginning of period $ 91,089 $ 76,344 Liabilities added from acquisition or drilling (1) 79 9,497 Liabilities removed upon sale of wells — — Liabilities settled (327 ) (259 ) Accretion expense 6,206 5,559 Revision of estimates 102 (52 ) Asset retirement obligation at end of period 97,149 91,089 Less: Current Portion 424 623 Asset retirement obligations - long-term portion $ 96,725 $ 90,466 (1) The increase in liabilities added from acquisition or drilling for the year ended December 31, 2019, is primarily due to the Merger with Midstates.

Restricted Investments (Tables)

Restricted Investments (Tables)	12 Months Ended
	Dec. 31, 2020
Investments Debt And Equity Securities [Abstract]
Restricted Investment Balances	The components of the restricted investment balances are as follows December 31, 2020 2019 (In thousands) BOEM platform abandonment (See Note 16) $ 313 $ 313 SPBPC Collateral: Contractual pipeline and surface facilities abandonment 4,310 4,309 Restricted investments $ 4,623 $ 4,622

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2020
Debt Disclosure [Abstract]
Consolidated Debt Obligations	Our consolidated debt obligations consisted of the following at the dates indicated: December 31, December 31, 2020 2019 (In thousands) Revolving Credit Facility (1) $ 255,000 $ 285,000 Paycheck Protection Program loan 5,516 — Total long-term debt $ 260,516 $ 285,000 (1) The carrying amount of our Revolving Credit Facility approximates fair value because the interest rates are variable and reflective of market rates.
Summary of Weighted-Average Interest Rates Paid on Variable-Rate Debt Obligations	The following table presents the weighted-average interest rates paid on variable-rate debt obligations for the periods presented: For the Year Ended December 31, 2020 2019 Revolving Credit Facility 3.63% 4.76%

Equity (Deficit) (Tables)

Equity (Deficit) (Tables)	12 Months Ended
	Dec. 31, 2020
Equity And Distributions [Line Items]
Summary of Changes in Number of Outstanding Common Units and Shares of Common Stock	The following table summarizes the changes in the number of outstanding common units and shares of common stock: Common Shares Balance, December 31, 2018 22,181,881 Issuance of common stock — Restricted stock units vested 412,938 Repurchase of common shares (1) (120,163 ) Common stock repurchased and retired under share repurchase program (169,400 ) Balance, June 30, 2019 22,305,256 Restricted stock units vested 38,181 Repurchase of common shares (1) (9,427 ) Balance, August 5, 2019 22,334,010 Ratio to convert Amplify shares 0.933 Common stock issued to Legacy Amplify stockholders 20,837,633 Midstates stock outstanding and acquired with the Merger 20,415,005 Treasury shares acquired from the Merger 205,861 Restricted stock units vested 682,552 Repurchase of common shares (1) (31,697 ) Common stock repurchased and retired under share repurchase program (4,195,247 ) Cancelation and retirement of shares (347,567 ) Balance, December 31, 2019 37,566,540 Issuance of common stock — Restricted stock units vested 132,237 Repurchase of common shares (1) (35,268 ) Balance, December 31, 2020 37,663,509 (1) Represents the net settlement on vesting of restricted stock necessary to satisfy the minimum statutory tax withholding requirements.
Warrants [Member]
Equity And Distributions [Line Items]
Summary of Assumptions used to Estimate the Fair Value	The fair values for the warrants upon issuance on the Effective Date have been estimated using the Black-Scholes option pricing model using the following assumptions: Warrants Issued in Successor Period Risk-free interest rate 2.06 % Dividend yield — Expected life (in years) 5.0 Expected volatility 50.0 % Strike Price $ 42.60 Calculated fair value $ 2.20

Earnings per Share (Tables)

Earnings per Share (Tables)	12 Months Ended
	Dec. 31, 2020
Earnings Per Share [Abstract]
Calculation of 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 Year Ended December 31, 2020 2019 Net income (loss) $ (464,030 ) $ (35,197 ) Less: Net income (loss) allocated to participating restricted stockholders — — Basic and diluted earnings available to common stockholders $ (464,030 ) $ (35,197 ) Common shares: Common shares outstanding — basic 37,612 29,301 Dilutive effect of potential common shares — — Common shares outstanding — diluted 37,612 29,301 Net earnings (loss) per share: Basic $ (12.34 ) $ (1.20 ) Diluted $ (12.34 ) $ (1.20 ) Antidilutive warrants (1) 2,174 9,154 (1) Amount represents warrants to purchase common stock that are excluded from the diluted net earnings per share calculations because of their antidilutive effect.

Equity-based Awards (Tables)

Equity-based Awards (Tables)	12 Months Ended
	Dec. 31, 2020
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Summary of Amount of Compensation Expense Recognized	The following table summarizes the amount of recognized compensation expense associated with these awards that are reflected in the accompanying statements of operations for the periods presented (in thousands): For the Year Ended December 31, 2020 2019 Equity classified awards TSUs $ 267 $ 1,797 PSUs 98 981 Board RSUs 19 264 $ 384 $ 3,042
2017 Non-Employee Directors Compensation Plan [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Summary of Information Regarding Restricted Stock Unit Awards	The following table summarizes information regarding the Board RSUs granted under the Director Compensation Plan for the period presented: Weighted- Average Grant Number of Date Fair Value Units per Unit (1) Board RSUs outstanding at December 31, 2018 39,604 $ 11.36 Granted (2) 42,933 $ 6.95 Forfeited — $ — Vested (49,723 ) $ 9.54 Board RSUs outstanding at August 5, 2019 32,814 $ 8.35 Ratio to convert Board RSUs (3) 0.933 Converted Board RSUs 30,616 Board RSUs outstanding on August 6, 2019 (4) 30,616 $ 5.12 Granted — $ — Forfeited — $ — Vested (14,459 ) $ 5.12 Board RSUs outstanding at December 31, 2019 16,157 $ 5.12 Granted — $ — Forfeited — $ — Vested (7,259 ) $ 5.12 Board RSUs outstanding at December 31, 2020 8,898 $ 5.12 (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 Board RSUs issued for the period from January 1, 2019 through August 5, 2019 was $0.3 million based on a grant date market price of $6.95 per share. (3) The merger ratio used to convert Legacy Amplify Board RSUs into newly issued Company Board RSUs. (4) This reflects the unvested Board RSU awards converted into newly issued Board RSUs at August 6, 2019 in which the stock price was at $5.12 per share.
TSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Summary of Information Regarding Restricted Stock Unit Awards	The following table summarizes information regarding the TSUs granted under the Legacy Amplify MIP for the period presented: Weighted- Average Grant Number of Date Fair Value Units per Unit (1) TSUs outstanding at December 31, 2018 598,024 $ 11.35 Granted (2) 300,517 $ 6.80 Forfeited (38,151 ) $ 11.13 Vested (437,834 ) $ 8.71 TSUs outstanding at August 5, 2019 422,556 $ 10.87 Ratio to convert TSUs (3) 0.933 Converted TSUs 394,245 TSUs outstanding at August 6, 2019 (4) 394,245 $ 5.12 Granted (5) 17,500 $ 6.14 Forfeited (38,652 ) $ 5.12 Vested (81,723 ) $ 5.12 TSUs outstanding at December 31, 2019 291,370 $ 5.18 Granted (6) 43,250 $ 3.10 Forfeited (93,845 ) $ 5.12 Vested (124,978 ) $ 5.17 TSUs outstanding at December 31, 2020 115,797 $ 4.47 (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 period from January 1, 2019 through August 5, 2019 was $2.0 million based on a grant date market price ranging from $4.48 to $8.70 per share. ( 3 ) The merger ratio used to convert Legacy Amplify TSUs into newly issued TSUs. ( 4 ) This reflects the unvested TSUs converted into newly issued Company’s TSUs at August 6, 2019 at a stock price of $5.12 per share. ( 5 ) The aggregate grant date fair value of TSUs issued for the period August 6, 2019 through December 31, 2019 was $0.1 million based on a grant date market price of $6.14 per share. ( 6 ) The aggregate grant date fair value of TSUs issued for the year ended December 31, 2020 was $0.1 million based on a grant date market price ranging from $0.54 to $6.61 per share.
PSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Summary of Information Regarding Restricted Stock Unit Awards	The following table summarizes information regarding the PSUs granted under the Legacy Amplify MIP for the period presented: Weighted- Average Grant Number of Date Fair Value Units per Unit (1) PSUs outstanding at December 31, 2018 393,500 $ 8.14 Granted (2) 17,750 $ 4.06 Forfeited (22,750 ) $ 7.59 Vested — $ — PSUs outstanding at August 5, 2019 388,500 $ 7.98 Ratio to convert PSUs (3) 0.933 Converted PSUs 362,471 PSUs outstanding on August 6, 2019 (4) 362,471 $ 2.11 Granted (5) 17,500 $ 2.87 Forfeited (74,078 ) $ 2.11 Vested — $ — PSUs outstanding at December 31, 2019 305,893 $ 2.15 Granted (6) 43,250 $ 3.03 Forfeited (134,589 ) $ 2.11 Vested — $ — PSUs outstanding at December 31, 2020 214,554 $ 2.36 (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 period January 1, 2019 through August 5, 2019 was less than $0.1 million based on a calculated fair value price ranging from $1.64 to $6.76 per share. ( 3 ) The merger ratio used to convert Legacy Amplify PSUs into newly issued Company PSUs. ( 4 ) This reflects the unvested PSU awards converted into newly issued PSUs at August 6, 2019 based on a calculated fair value price ranging from $1.64 to $2.63 per share. ( 5 ) The aggregate grant date fair value of PSUs issued for the period August 6, 2019 through December 31, 2019 was less than $0.1 million based on a calculated fair value price ranging from $2.38 to $3.40 per share. ( 6 ) The aggregate grant date fair value of PSUs issued for the year ended December 31, 2020 was $0.1 million based on a calculated fair value price ranging from $2.46 to $3.66 per share.
Schedule of Fair Value Assumptions for PSUs	A Monte Carlo simulation was used to determine the fair value of these awards at the grant date. The assumptions used to estimate the fair value of the PSUs are as follows: Share price targets $ 12.50 $ 15.00 $ 17.50 Risk-free interest rate: Awards Issued on January 1, 2020 and April 1, 2020 1.61 % 1.61 % 1.61 % Dividend yield Awards Issued on January 1, 2020 and April 1, 2020 12.1 % 12.1 % 12.1 % Expected volatility: Awards Issued on January 1, 2020 and April 1, 2020 60.0 % 60.0 % 60.0 % Calculated fair value per PSU: Awards Issued on January 1, 2020 and April 1, 2020 $ 3.66 $ 2.98 $ 2.46 Share price targets $ 12.50 $ 15.00 $ 17.50 Risk-free interest rate: Awards Issued on January 1, 2019 2.44 % 2.44 % 2.44 % Awards Issued on April 1, 2019 2.28 % 2.28 % 2.28 % Awards Issued on July 1, 2019 1.73 % 1.73 % 1.73 % Awards Issued on October 1, 2019 1.50 % 1.50 % 1.50 % Dividend yield — — — Expected volatility: Awards Issued on January 1, 2019 54.0 % 54.0 % 54.0 % Awards Issued on April 1, 2019 50.0 % 50.0 % 50.0 % Awards Issued on July 1, 2019 57.0 % 57.0 % 57.0 % Awards Issued on October 1, 2019 65.0 % 65.0 % 65.0 % Calculated fair value per PSU: Awards Issued on January 1, 2019 $ 6.76 $ 5.86 $ 5.11 Awards Issued on April 1, 2019 $ 4.22 $ 3.43 $ 2.80 Awards Issued on July 1, 2019 $ 2.63 $ 2.05 $ 1.64 Awards Issued on October 1, 2019 $ 3.40 $ 2.83 $ 2.38

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2020
Leases [Abstract]
Schedule of Right-of-Use Assets and Lease Liabilities	The following table presents the Company’s right-of-use assets and lease liabilities for the period presented: December 31, December 31, 2020 2019 (In thousands) Right-of-use asset $ 2,500 $ 4,406 Lease liabilities: Current lease liability 2,258 1,712 Long-term lease liability 266 2,720 Total lease liability $ 2,524 $ 4,432
Schedule of Maturity Analysis of Minimum Lease Payment Obligation Under Non-cancellable Operating Leases	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 leases Leased vehicles and office equipment Total 2021 $ 1,631 $ 634 $ 2,265 2022 140 157 297 2023 — 35 35 2024 and thereafter — — — Total lease payments 1,771 826 2,597 Less: interest 51 22 73 Present value of lease liabilities $ 1,720 $ 804 $ 2,524
Schedule of Weighted Average Remaining Lease Terms and Discount Rate of Operating Leases	The weighted average remaining lease terms and discount rate for all of our operating leases for the period presented: December 31, 2020 2019 Weighted average remaining lease term (years): Office leases 0.74 1.50 Vehicles 0.34 0.44 Office equipment 0.04 0.08 Weighted average discount rate: Office leases 3.41 % 3.63 % Vehicles 0.96 % 0.84 % Office equipment 0.17 % 0.18 %

Supplemental Disclosures to t_2

Supplemental Disclosures to the Consolidated Balance Sheet and Condensed Statement of Cash Flows (Tables)	12 Months Ended
	Dec. 31, 2020
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Summary of Current Accrued Liabilities	Current accrued liabilities consisted of the following at the dates indicated (in thousands): December 31, December 31, 2020 2019 Accrued lease operating expense $ 8,978 $ 11,794 Accrued commitment fee and other expense 4,404 — Accrued general and administrative expense 3,349 3,126 Operating lease liability 2,258 1,712 Accrued production and ad valorem tax 2,601 520 Accrued capital expenditures 173 5,515 Asset retirement obligations 424 623 Accrued current income taxes 110 — Accrued interest payable 26 36 Other 354 32 Accrued liabilities $ 22,677 $ 23,358
Summary of Cash and Cash Equivalents Reconciliation	The following table provides a reconciliation of cash and cash equivalents on the Consolidated Balance Sheet to cash, cash equivalents and restricted cash on the Statements of Consolidated Cash Flows (in thousands): December 31, December 31, 2020 2019 Cash and cash equivalents $ 10,364 $ — Restricted cash — 325 Total cash, cash equivalents and restricted cash $ 10,364 $ 325
Summary of Supplemental Cash Flows	Supplemental cash flow for the periods presented (in thousands): For the Year Ended December 31, 2020 2019 Supplemental cash flows: Cash paid for interest, net of amounts capitalized $ 10,331 $ 15,937 Cash paid for reorganization items, net 566 1,057 Cash paid for taxes 85 — Noncash investing and financing activities: Change in capital expenditures in payables and accrued liabilities (5,343 ) 2,143 Assumption of asset retirement obligations related to Merger — 9,440 Assets acquired & liabilities assumed in the Merger: Accounts receivable — 14,633 Prepaids and other current assets — 3,229 Other non-current assets — 9,075 Oil and natural gas properties — 149,421 Other property and equipment — 1,694 Accounts payable and other current liabilities — (24,135 ) Other non-current liabilities — (5,067 ) Long-term debt — (76,559 ) Issuance of common stock in connection with the Merger — 91,541

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2020
Commitments And Contingencies Disclosure [Abstract]
Purchase Commitments Under the Contracts	At December 31, 2020, we had a CO 2 2 2 Payment or Settlement Due by Period Purchase commitment Total 2021 2022 2023 2024 2025 Thereafter CO 2 $ 6,969 $ 3,729 $ 3,240 $ — $ — $ — $ — At December 31, 2020, we had a long-term minimum volume commitments with third parties associated with a certain portion of our properties located in Oklahoma and East Texas. The table below outlines the future payment commitments associated with the minimum volume commitment plus any applicable fee for not meeting the minimum volume commitment (in thousands): Payment or Settlement Due by Period (1) Minimum volume commitment Total 2021 2022 2023 2024 2025 Thereafter Midstream services $ 28,193 $ 12,841 $ 12,394 $ 2,958 $ — $ — $ —

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2020
Income Tax Disclosure [Abstract]
Components of Income Tax Expense (Benefit)	The components of income tax benefit (expense) are as follows: For the Year Ended December 31, 2020 2019 (In thousands) Current taxes: Federal $ (5 ) $ — State (110 ) 50 Total current income tax benefit (expense) (115 ) 50 Deferred taxes: Federal — — State — — Total deferred income tax benefit (expense) — — Total income tax benefit (expense) $ (115 ) $ 50
Reconciliation of Income Tax Benefit (Provision)	The actual income tax benefit (expense) differs from the expected amount computed by applying the federal statutory corporate tax rate of 21% in 2020 and in 2019 as follows: For the Year Ended December 31, 2020 2019 (In thousands) Expected tax benefit (expense) at federal statutory rate $ 97,423 $ 7,402 State income tax benefit (expense), net of federal benefit 6,189 946 Non-deductible expenses (45 ) (3,659 ) Changes in valuation allowances (110,445 ) (4,332 ) State rate change, net of federal benefit 6,100 — Non-cash compensation (137 ) (367 ) Other 800 60 Total income tax benefit (expense) $ (115 ) $ 50
Components of Net Deferred Income Tax Liabilities	The Company’s deferred tax position reflects the net tax effects of the temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax reporting. Significant components of the deferred tax assets and liabilities are as follows (in thousands): December 31, December 31, 2020 2019 Deferred income tax assets: Property, Plant & Equipment $ 115,695 $ 37,075 Net operating loss carryforward 174,479 141,534 Derivatives 2,448 — Disallowed interest expense 5,388 10,627 Accrued liabilities 1,226 1,431 Other 1,717 4,234 Total deferred income tax assets: 300,953 194,901 Valuation allowance (300,386 ) (189,941 ) Net deferred income tax assets 567 4,960 Deferred income tax liabilities: Derivatives $ — $ 2,767 Other 567 2,193 Total deferred income tax liabilities 567 4,960 Net deferred income tax liabilities $ — $ —

Supplemental Oil and Gas Info_2

Supplemental Oil and Gas Information (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2020
Extractive Industries [Abstract]
Schedule of Capitalized Costs Relating to Oil and Natural Gas Producing Activities	The total amount of capitalized costs relating to oil and natural gas producing activities and the total amount of related accumulated depreciation, depletion and amortization is as follows at the dates indicated. December 31, December 31, 2020 2019 (In thousands) Evaluated oil and natural gas properties $ 775,167 $ 797,005 Support equipment and facilities 142,208 140,023 Accumulated depletion, depreciation, and amortization (602,861 ) (136,747 ) Total $ 314,514 $ 800,281
Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development Activities	Costs incurred in property acquisition, exploration and development activities were as follows for the periods indicated: For the Year Ended December 31, 2020 2019 (In thousands) Property acquisition costs, proved $ 42 $ 150,871 Property acquisition costs, unproved (49,307 ) 7,674 Exploration — — Development 29,543 71,460 Total $ (19,722 ) $ 230,005
Schedule of Product Prices Used for Valuing the Reserves	The weighted-average benchmark product prices used for valuing the reserves are based upon the average of the first-day-of-the-month price for each month within the period January through December of each year presented: 2020 2019 Oil ($/Bbl): WTI (1) $ 39.57 $ 55.69 NGL ($/Bbl): WTI (1) $ 39.57 $ 55.69 Natural Gas ($/MMbtu): Henry Hub (2) $ 1.99 $ 2.58 (1) The weighted average WTI price was adjusted by lease for quality, transportation fees, and a regional price differential. (2) The weighted average Henry Hub price was adjusted by lease for energy content, compression charges, transportation fees, and regional price differentials.
Schedule of Net Reserves	The following tables set forth estimates of the net reserves for the periods indicated: For the Year Ended December 31, 2020 Oil Gas NGLs Total (MBbls) (MMcf) (MBbls) (MBoe) Proved developed and undeveloped reserves: Beginning of year 70,772 377,869 29,252 163,002 Extensions and discoveries 291 655 61 461 Production (3,887 ) (27,473 ) (1,725 ) (10,190 ) Revision of previous estimates (20,500 ) (76,912 ) (6,104 ) (39,424 ) End of year 46,676 274,139 21,484 113,849 Proved developed reserves: Beginning of year 53,476 320,731 23,646 130,577 End of year 35,613 252,218 19,009 96,658 Proved undeveloped reserves: Beginning of year 17,296 57,138 5,606 32,425 End of year 11,063 21,921 2,475 17,191 For the Year Ended December 31, 2019 Oil Gas NGLs Total (MBbls) (MMcf) (MBbls) (MBoe) Proved developed and undeveloped reserves: Beginning of period 69,624 293,959 21,572 140,189 Extensions and discoveries 301 576 44 441 Purchase of minerals in place 17,429 202,409 18,533 69,697 Production (3,498 ) (26,489 ) (1,343 ) (9,256 ) Revision of previous estimates (13,084 ) (92,586 ) (9,554 ) (38,069 ) End of period 70,772 377,869 29,252 163,002 Proved developed reserves: Beginning of period 54,147 232,110 17,324 110,156 End of period 53,476 320,731 23,646 130,577 Proved undeveloped reserves: Beginning of period 15,477 61,849 4,248 30,033 End of period 17,296 57,138 5,606 32,425
Standardized Measure of Discounted Future Net Cash Flows	The standardized measure of discounted future net cash flows is as follows: For the Year Ended December 31, 2020 2019 (In thousands) Future cash inflows $ 2,410,260 $ 5,146,288 Future production costs (1) (1,589,945 ) (2,917,262 ) Future development costs (1) (375,146 ) (567,423 ) Future income tax expense — — Future net cash flows for estimated timing of cash flows 445,169 1,661,603 10% annual discount for estimated timing of cash flows (147,358 ) (745,042 ) Standardized measure of discounted future net cash flows $ 297,811 $ 916,561 (1) For the year ended December 31, 2020, onshore abandonment costs are included in future production cost and offshore abandonment costs are included in future development costs.
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves	The following is a summary of the changes in the standardized measure of discounted future net cash flows for the proved oil and natural gas reserves during each of the years in the two year period presented: For the Year Ended December 31, 2020 2019 (In thousands) Beginning of year $ 916,561 $ 1,113,029 Sale of oil and natural gas produced, net of production costs (47,687 ) (113,545 ) Purchase of minerals in place — 408,370 Extensions and discoveries 3,687 5,334 Changes in prices and costs (548,429 ) (623,592 ) Previously estimated development costs incurred 49,144 84,341 Net changes in future development costs 89,997 110,892 Revisions of previous quantities (150,245 ) (183,300 ) Accretion of discount 91,657 92,998 Change in production rates and other (106,874 ) 22,034 End of year $ 297,811 $ 916,561

Organization and Basis of Pre_3

Organization and Basis of Presentation - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2020Segment
Accounting Policies [Abstract]
Number of reportable business segments	1

Summary of Significant Accoun_3

Summary of Significant Accounting Policies - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Summary Of Significant Accounting Policies [Line Items]
Allowance for doubtful accounts	$ 1,500,000	$ 1,500,000
Capitalized exploratory drilling costs pending evaluation	0	0
Amortization expense including write-off of debt issuance costs	3,300,000	1,200,000
Impairment expense for proved/unproved properties	476,936,000	2,246,000
Capitalized interest	$ 200,000	200,000
Chance of tax benefit likely to be realized	greater than 50%
Proved Developed and Producing Oil and Gas Properties [Member]
Summary Of Significant Accounting Policies [Line Items]
Impairment expense for proved/unproved properties	$ 427,600,000	0
Unproved Oil and Natural Gas Properties [Member]
Summary Of Significant Accounting Policies [Line Items]
Impairment expense for unproved leasehold costs	$ 49,300,000	$ 2,200,000
Minimum [Member] | Other Property & Equipment [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives	3 years
Minimum [Member] | Support Equipment and Facilities [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives	12 years
Maximum [Member] | Other Property & Equipment [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives	7 years
Maximum [Member] | Support Equipment and Facilities [Member]
Summary Of Significant Accounting Policies [Line Items]
Estimated useful lives	24 years
Customer Concentration Risk [Member] | Revenues [Member]
Summary Of Significant Accounting Policies [Line Items]
Percentage of total revenue	10.00%

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Major Customers (Detail) - Customer Concentration Risk [Member] - Revenues [Member]	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Significant Accounting Policies [Line Items]
Total Reported Revenues	10.00%
Phillips 66 [Member]
Significant Accounting Policies [Line Items]
Total Reported Revenues	23.00%	27.00%
Sinclair Oil & Gas Company [Member]
Significant Accounting Policies [Line Items]
Total Reported Revenues	21.00%	21.00%
BP America Production Company [Member]
Significant Accounting Policies [Line Items]
Total Reported Revenues	17.00%	13.00%

Revenue - Summary of Revenues D

Revenue - Summary of Revenues Disaggregated (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Revenues:
Total revenues	$ 202,144	$ 275,575
Oil and Natural Gas Sales [Member]
Revenues:
Total revenues	200,888	274,607
Oil [Member]
Revenues:
Total revenues	138,273	192,944
NGLs [Member]
Revenues:
Total revenues	20,064	22,347
Natural Gas [Member]
Revenues:
Total revenues	$ 42,551	$ 59,316

Revenue - Additional Informatio

Revenue - Additional Information (Detail) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Revenue From Contract With Customer [Abstract]
Accounts receivable attributable to revenue contracts with customers	$ 25.6	$ 31.9

Acquisitions and Divestitures -

Acquisitions and Divestitures - Summary of Purchase Price Allocation (Parenthetical) (Detail) - Legacy Amplify, Midstates and Midstates Holdings, Inc. [Member]	Aug. 06, 2019$ / sharesshares
Business Acquisition [Line Items]
Business acquisition, common shares issued | shares	20,415,005
Business acquisition, share price | $ / shares	$ 4.12

Acquisitions and Divestitures_2

Acquisitions and Divestitures - Acquisition and Divestiture Related Expenses (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
General and Administrative Expense [Member]
Business Acquisition [Line Items]
Business Acquisition and Divestiture, Related Expenses	$ 1,092	$ 17,305

Acquisitions and Divestitures_3

Acquisitions and Divestitures - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Thousands	May 05, 2019	Dec. 31, 2019	Dec. 31, 2020	Sep. 30, 2019	Jan. 01, 2019	Dec. 31, 2018
Business Acquisition And Divestiture [Line Items]
Common stock, par value		$ 0.01	$ 0.01
Measurement period adjustment amount of increase asset retirement obligations liability		$ 91,089	$ 97,149			$ 76,344
Operating lease - long term right-of-use asset		4,406	2,500
Operating Liabilities		4,432	$ 2,524
ASU 2016-02 [Member]
Business Acquisition And Divestiture [Line Items]
Operating lease - long term right-of-use asset					$ 5,400
Operating Liabilities					$ 5,400
Legacy Amplify, Midstates and Midstates Holdings, Inc. [Member]
Business Acquisition And Divestiture [Line Items]
Merger conversion ratio	0.933
Common stock, par value	$ 0.01
Measurement period adjustment amount of increase asset retirement obligations liability				$ 900
Legacy Amplify, Midstates and Midstates Holdings, Inc. [Member] | ASU 2016-02 [Member]
Business Acquisition And Divestiture [Line Items]
Operating lease - long term right-of-use asset				300
Operating Liabilities				$ 300
Legacy Amplify, Midstates and Midstates Holdings, Inc. [Member] | Oklahoma Properties [Member]
Business Acquisition And Divestiture [Line Items]
Business acquisition, revenues		31,800
Legacy Amplify, Midstates and Midstates Holdings, Inc. [Member] | Direct Operating Expense [Member] | Oklahoma Properties [Member]
Business Acquisition And Divestiture [Line Items]
Business acquisition, expenses		34,000
Legacy Amplify, Midstates and Midstates Holdings, Inc. [Member] | Other Expenses [Member | Oklahoma Properties [Member]
Business Acquisition And Divestiture [Line Items]
Business acquisition, expenses		$ 400

Acquisitions and Divestitures_4

Acquisitions and Divestitures - Summary of Purchase Price Allocation (Detail) - Legacy Amplify, Midstates and Midstates Holdings, Inc. [Member] $ in Thousands	Aug. 06, 2019USD ($)
Consideration:
Fair value of Midstates common stock issued in the Merger (a)	$ 90,150
Fair value of Midstates warrants issued in the Merger	2
Value of shares to be issued	90,152
Fair value of Legacy Amplify restricted share consideration	832
Fair value of Legacy Amplify PSU consideration	557
Total consideration	91,541
Fair value of liabilities assumed:
Current liabilities	24,135
Long-term debt	76,559
Long-term asset retirement obligation	9,440
Other long-term liabilities	5,067
Amounts attributable to liabilities assumed	115,201
Fair value of assets acquired:
Cash and cash equivalents	19,250
Other current assets	17,862
Oil and natural gas properties	149,421
Other property and equipment	1,694
Long-term asset retirement cost	9,440
Other non-current assets	9,075
Amounts attributable to assets acquired	206,742
Total identifiable net assets	$ 91,541

Acquisitions and Divestitures_5

Acquisitions and Divestitures - Summary of Unaudited Pro Forma Financial Information (Detail) - Legacy Amplify, Midstates and Midstates Holdings, Inc. [Member] $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)$ / shares
Business Acquisition [Line Items]
Revenues | $	$ 336,326
Net income (loss) | $	$ (22,926)
Earnings per share:
Basic | $ / shares	$ (0.78)
Diluted | $ / shares	$ (0.78)

Fair Value Measurements of Fi_3

Fair Value Measurements of Financial Instruments - Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) - Fair Value [Member] - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	$ 15,449	$ 19,104
Total liabilities	26,247	7,419
Quoted Prices in Active Market (Level 1) [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	0	0
Total liabilities	0	0
Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	15,449	19,104
Total liabilities	26,247	7,419
Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	0	0
Total liabilities	0	0
Commodity derivatives [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	15,449	18,509
Total liabilities	23,495	6,861
Commodity derivatives [Member] | Quoted Prices in Active Market (Level 1) [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	0	0
Total liabilities	0	0
Commodity derivatives [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	15,449	18,509
Total liabilities	23,495	6,861
Commodity derivatives [Member] | Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	0	0
Total liabilities	0	0
Interest rate derivatives [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	0	595
Total liabilities	2,752	558
Interest rate derivatives [Member] | Quoted Prices in Active Market (Level 1) [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	0	0
Total liabilities	0	0
Interest rate derivatives [Member] | Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	0	595
Total liabilities	2,752	558
Interest rate derivatives [Member] | Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	0	0
Total liabilities	$ 0	$ 0

Fair Value Measurements of Fi_4

Fair Value Measurements of Financial Instruments - Additional Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Assets And Liabilities Carrying Value And Fair Value [Line Items]
Impairment expense	$ 476,936	$ 2,246
Proved Developed and Producing Oil and Gas Properties [Member]
Assets And Liabilities Carrying Value And Fair Value [Line Items]
Impairment expense	427,600	0
Unproved Properties [Member]
Assets And Liabilities Carrying Value And Fair Value [Line Items]
Impairment expense	$ 49,300	$ 2,200

Risk Management and Derivativ_3

Risk Management and Derivative Instruments - Additional Information (Detail) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Apr. 30, 2020	Dec. 31, 2020
Fair Value Disclosures [Abstract]
Conditional rights of set-off under ISDA Master Agreement reduce the maximum amount of loss due to credit risk		$ 2.1
Derivative Cash Received On Hedge	$ 18

Risk Management and Derivativ_4

Risk Management and Derivative Instruments - Open Commodity Positions (Detail)	12 Months Ended
	Dec. 31, 2020MMBTU$ / MMBTU$ / bblbbl
Natural Gas Derivative Contracts Fixed Price Swap 2022 [Member]
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	590,000
Weighted-average fixed price | $ / MMBTU	2.48
Natural Gas Derivative Two Way Collars Contracts 2022 [Member]
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	595,000
Weighted-average floor price	2.37
Weighted-average ceiling price	3.09
Crude Oil Derivative Contracts Fixed Price Swap 2022 [Member]
Derivative [Line Items]
Average monthly volume (Bbls) | bbl	40,000
Weighted-average fixed price	52.39
Natural Gas P E P L Basis Swaps Two Thousand Twenty Two
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	0
Weighted-average spread | $ / MMBTU	0
Crude Oil Derivative Three Way Collars Contracts 2022 [Member]
Derivative [Line Items]
Average monthly volume (Bbls) | bbl	76,000
Weighted-average floor price	40
Weighted-average ceiling price	53.18
Weighted-average sub-floor price	31.32
NGL Derivative Contracts Fixed Price Swap 2022 [Member]
Derivative [Line Items]
Average monthly volume (Bbls) | bbl	0
Weighted-average fixed price	0
Natural Gas Derivative Contracts Fixed Price Swap 2021 [Member]
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	925,000
Weighted-average fixed price | $ / MMBTU	2.49
Natural Gas Derivative Two Way Collars Contracts 2021 [Member]
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	925,000
Weighted-average floor price	2.10
Weighted-average ceiling price	3.28
Crude Oil Derivative Three Way Collars Contracts 2021 [Member]
Derivative [Line Items]
Average monthly volume (Bbls) | bbl	42,500
Weighted-average floor price	40
Weighted-average ceiling price	50.61
Weighted-average sub-floor price	30
Natural Gas P E P L Basis Swaps Two Thousand Twenty One
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	500,000
Weighted-average spread | $ / MMBTU	(0.40)
Crude Oil Derivative Contracts Fixed Price Swap 2021 [Member]
Derivative [Line Items]
Average monthly volume (Bbls) | bbl	181,250
Weighted-average fixed price	45.84
NGL Derivative Contracts Fixed Price Swap 2021 [Member]
Derivative [Line Items]
Average monthly volume (Bbls) | bbl	22,800
Weighted-average fixed price	24.25

Risk Management and Derivativ_5

Risk Management and Derivative Instruments - Interest Rate Swap Open Positions (Detail)	12 Months Ended
	Dec. 31, 2020USD ($)
Interest Rate Swap Open Position 2021 [Member]
Derivative [Line Items]
Average Monthly Notional (in thousands)	$ 125,000,000
Weighted-average fixed rate	1.612%
Floating rate	1 Month LIBOR
Interest Rate Swap Open Position 2022 [Member]
Derivative [Line Items]
Average Monthly Notional (in thousands)	$ 75,000,000
Weighted-average fixed rate	1.281%
Floating rate	1 Month LIBOR

Risk Management and Derivativ_6

Risk Management and Derivative Instruments - Gross Fair Value of Derivative Instruments by Appropriate Balance Sheet (Detail) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Derivative Instruments and Hedges, Assets [Abstract]
Asset Derivatives, Net recorded fair value	$ 0	$ 5,879
Asset Derivatives, Net recorded fair value	873	6,364
Liability Derivatives, Net recorded fair value	10,824	253
Liability Derivatives, Net recorded fair value	847	305
Short-Term Derivative Instruments [Member]
Derivative Instruments and Hedges, Assets [Abstract]
Total assets	6,088	11,766
Asset Derivatives, Netting arrangements	(6,088)	(5,887)
Asset Derivatives, Net recorded fair value	0	5,879
Liability Derivatives, Gross fair value	16,912	6,140
Liability Derivatives, Netting arrangements	(6,088)	(5,887)
Liability Derivatives, Net recorded fair value	10,824	253
Short-Term Derivative Instruments [Member] | Commodity derivatives [Member]
Derivative Instruments and Hedges, Assets [Abstract]
Total assets	6,088	11,518
Liability Derivatives, Gross fair value	15,007	5,887
Short-Term Derivative Instruments [Member] | Interest Rate Swaps [Member]
Derivative Instruments and Hedges, Assets [Abstract]
Total assets	0	248
Liability Derivatives, Gross fair value	1,905	253
Long-Term Derivative Instruments [Member]
Derivative Instruments and Hedges, Assets [Abstract]
Total assets	9,361	7,337
Asset Derivatives, Netting arrangements	(8,488)	(973)
Asset Derivatives, Net recorded fair value	873	6,364
Liability Derivatives, Gross fair value	9,335	1,278
Liability Derivatives, Netting arrangements	(8,488)	(973)
Liability Derivatives, Net recorded fair value	847	305
Long-Term Derivative Instruments [Member] | Commodity derivatives [Member]
Derivative Instruments and Hedges, Assets [Abstract]
Total assets	9,361	6,990
Liability Derivatives, Gross fair value	8,488	973
Long-Term Derivative Instruments [Member] | Interest Rate Swaps [Member]
Derivative Instruments and Hedges, Assets [Abstract]
Total assets	0	347
Liability Derivatives, Gross fair value	$ 847	$ 305

Risk Management and Derivativ_7

Risk Management and Derivative Instruments - Unrealized and Realized Gains and Losses Related to Derivative Instruments (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Derivative Instruments Gain Loss [Line Items]
(Gain) loss on commodity derivative instruments	$ (60,671)	$ 6,700
Interest expense, net	(20,522)	(16,855)
Commodity derivatives [Member]
Derivative Instruments Gain Loss [Line Items]
(Gain) loss on commodity derivative instruments	(60,671)	6,700
Interest Rate Swaps [Member]
Derivative Instruments Gain Loss [Line Items]
Interest expense, net	$ 4,044	$ (224)

Asset Retirement Obligations -

Asset Retirement Obligations - Summary of Changes in Asset Retirement Obligations (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations at beginning of period		$ 91,089	$ 76,344
Liabilities added from acquisition or drilling	[1]	79	9,497
Liabilities removed upon sale of wells		0	0
Liabilities settled		(327)	(259)
Accretion expense		6,206	5,559
Revision of estimates		102	(52)
Asset retirement obligation at end of period		97,149	91,089
Less: Current Portion		424	623
Asset retirement obligations - long-term portion		$ 96,725	$ 90,466
[1]	The increase in liabilities added from acquisition or drilling for the year ended December 31, 2019, is primarily due to the Merger with Midstates.

Restricted Investments - Restri

Restricted Investments - Restricted Investment Balances (Detail) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Schedule Of Investments [Line Items]
Restricted investments	$ 4,623	$ 4,622
BOEM platform abandonment [Member]
Schedule Of Investments [Line Items]
Restricted investments	313	313
SPBPC Collateral Contractual pipeline and surface facilities abandonment [Member]
Schedule Of Investments [Line Items]
Restricted investments	$ 4,310	$ 4,309

Restricted Investments - Additi

Restricted Investments - Additional Information (Detail) $ in Millions	Jun. 24, 2019USD ($)
Investments Debt And Equity Securities [Abstract]
Proceeds from Beta Decommissioning Trust account	$ 90

Debt - Consolidated Debt Obliga

Debt - Consolidated Debt Obligations (Detail) - USD ($) $ in Thousands		Apr. 24, 2020	Dec. 31, 2020	Dec. 31, 2019
Line Of Credit Facility [Line Items]
Paycheck Protection Program loan		$ 5,500	$ 5,516	$ 0
Total long-term debt			260,516	285,000
Revolving Credit Facility [Member]
Line Of Credit Facility [Line Items]
Aggregate principal outstanding	[1]		$ 255,000	$ 285,000
[1]	The carrying amount of our Revolving Credit Facility approximates fair value because the interest rates are variable and reflective of market rates.

Debt - Credit Facility - Additi

Debt - Credit Facility - Additional Information (Detail) - USD ($) $ in Millions	Nov. 02, 2018	Nov. 17, 2020	Dec. 31, 2020	Dec. 31, 2022	Dec. 31, 2021	Nov. 11, 2020	Nov. 08, 2019	Nov. 07, 2019	Aug. 06, 2019	Aug. 05, 2019
Line Of Credit Facility [Line Items]
Debt instrument interest rate description			the applicable margin for LIBOR loans and LIBOR Market loans increased from 200 to 300 basis points to 250 to 350 basis points.
Letters of credit outstanding			$ 0
Revolving Credit Facility [Member]
Line Of Credit Facility [Line Items]
Borrowing base		$ 260	$ 260			$ 260	$ 450	$ 530	$ 530	$ 425
Maturity date			Nov. 2, 2023
LIBOR rate interest period	1 month
Unsused line of credit, commitment fee percentage	0.50%
Debt Instrument, Covenant Description		modify the affirmative hedging covenant to include at least 65% and 45% hedge for calendar years 2021 and 2022 on a total proved developed producing reserves, respectively
Monthly reduction of line of credit facility current borrowing capacity			$ 5
Line of credit facility, covenant terms			suspend certain financial covenants for the quarter ended June 30, 2020
Revolving Credit Facility [Member] | Amplify Acquisitionco Inc
Line Of Credit Facility [Line Items]
Pledge and security interest	100.00%
Revolving Credit Facility [Member] | Minimum [Member]
Line Of Credit Facility [Line Items]
Borrowing base			$ 285
Current ratio	1.00%
Hedging Liabilities Noncurrent			30.00%
Increase in percentage of priority lien assets			85.00%
Line of credit facility decrease limit of cash and cash equivalents			$ 30
Line of credit facility increase limit of transaction-related expense add-backs			5
Revolving Credit Facility [Member] | Minimum [Member] | Scenario Forecast [Member]
Line Of Credit Facility [Line Items]
Hedging Liabilities Noncurrent				45.00%	65.00%
Revolving Credit Facility [Member] | Minimum [Member] | Oil and Gas Properties [Member]
Line Of Credit Facility [Line Items]
Secured by percentage of mortgages	85.00%
Revolving Credit Facility [Member] | Minimum [Member] | Proved Developed and Producing Oil and Gas Properties [Member]
Line Of Credit Facility [Line Items]
Secured by percentage of mortgages	85.00%
Revolving Credit Facility [Member] | Maximum [Member]
Line Of Credit Facility [Line Items]
Borrowing base			$ 450
Total debt to EBITDAX	4.00%
Hedging Liabilities Noncurrent			60.00%
Increase in percentage of priority lien assets			90.00%
Line of credit facility decrease limit of cash and cash equivalents			$ 25
Line of credit facility increase limit of transaction-related expense add-backs			$ 20
Revolving Credit Facility [Member] | Federal Funds Effective Rate [Member]
Line Of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate	0.50%
Revolving Credit Facility [Member] | LIBOR [Member]
Line Of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate	1.00%
Revolving Credit Facility [Member] | LIBOR [Member] | Minimum [Member]
Line Of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate	2.00%
Revolving Credit Facility [Member] | LIBOR [Member] | Maximum [Member]
Line Of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate	3.00%
Revolving Credit Facility [Member] | Base Rate [Member] | Minimum [Member]
Line Of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate	1.00%
Revolving Credit Facility [Member] | Base Rate [Member] | Maximum [Member]
Line Of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate	2.00%

Debt - Paycheck Protection Prog

Debt - Paycheck Protection Program - Additional Information (Detail) - USD ($)	Apr. 24, 2020	Dec. 31, 2020	Dec. 31, 2019
Debt Disclosure [Abstract]
Loan amount received under paycheck protection plan	$ 5,500,000	$ 5,516,000	$ 0
Paycheck protection program loan of 2020, term	2 years
Paycheck protection program Loan of 2020, interest rate	1.00%
Paycheck protection program loan, principal or interest due next six months	$ 0

Debt - Summary of Weighted-Aver

Debt - Summary of Weighted-Average Interest Rates Paid on Variable-Rate Debt Obligations (Detail)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Revolving Credit Facility [Member]
Line Of Credit Facility [Line Items]
Revolving credit facility, weighted-average interest rates	3.63%	4.76%

Debt - Unamortized Deferred Fin

Debt - Unamortized Deferred Financing Costs - Additional Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Line Of Credit Facility [Line Items]
Amortization and write-off of deferred financing costs	$ 3,272	$ 1,174
Successor Credit Facility [Member]
Line Of Credit Facility [Line Items]
Unamortized deferred financing costs	1,600
Revolving Credit Facility [Member]
Line Of Credit Facility [Line Items]
Amortization and write-off of deferred financing costs	$ 2,400

Equity (Deficit)- Additional In

Equity (Deficit)- Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions

Mar. 30, 2020

Mar. 03, 2020

Dec. 18, 2019

Nov. 05, 2019

Sep. 18, 2019

Aug. 06, 2019

May 04, 2017

Dec. 31, 2019

Jun. 30, 2019

Dec. 31, 2020

Aug. 05, 2019

Dec. 21, 2018

Equity And Distributions [Line Items]

Common stock, shares authorized

250,000,000

250,000,000

Common stock, par value

$ 0.01

$ 0.01

Warrants outstanding

9,153,522

2,173,913

Warrant expiry date

Apr. 21, 2020

Treasury shares outstanding

0

0

Stock repurchase authorized amount

$ 25

Shares repurchased during period

4,195,247

Average common stock price

$ 6.28

Total cost of share repurchase

$ 24.9

Dividend declared date

Mar. 3, 2020

Nov. 5, 2019

Aug. 6, 2019

Dividends declared per share

$ 0.10

$ 0.20

$ 0.20

Dividends paid

$ 3.8

$ 7.7

$ 8.2

Dividend payable record date

Mar. 16, 2020

Dec. 4, 2019

Sep. 4, 2019

Warrants [Member]

Equity And Distributions [Line Items]

Warrant life period

5 years

Percentage of common shares to be issued upon exercise of warrants

8.00%

Warrant issued during period

2,173,913

Warrant exercise price

$ 42.60

Third Lien Notes Warrants [Member]

Equity And Distributions [Line Items]

Warrant exercise price

$ 22.78

Warrants outstanding

4,647,520

Unsecured Creditor Warrants [Member]

Equity And Distributions [Line Items]

Warrant exercise price

$ 43.67

Warrants outstanding

2,332,089

Midstates [Member]

Equity And Distributions [Line Items]

Treasury shares outstanding

205,861

Common Stock [Member]

Equity And Distributions [Line Items]

Stock repurchase authorized amount

$ 25

Shares repurchased during period

169,400

Average common stock price

$ 7.35

Total cost of share repurchase

$ 1.3

Equity (Deficit) - Summary of C

Equity (Deficit) - Summary of Changes in Number of Outstanding Common Units and Shares of Common Stock (Detail) - shares		1 Months Ended	5 Months Ended	6 Months Ended	7 Months Ended	12 Months Ended
		Aug. 05, 2019	Dec. 31, 2019	Jun. 30, 2019	Aug. 05, 2019	Dec. 31, 2020	Dec. 31, 2019
Summary Of Changes In Number Of Outstanding Units Or Shares [Line Items]
Beginning balance						37,566,540
Ending balance			37,566,540			37,663,509	37,566,540
Common Stock [Member]
Summary Of Changes In Number Of Outstanding Units Or Shares [Line Items]
Beginning balance		22,305,256	22,334,010	22,181,881	22,181,881	37,566,540	22,181,881
Issuance of common stock				0		0
Restricted stock units vested		38,181	682,552	412,938		132,237
Repurchase of common shares	[1]	(9,427)	(31,697)	(120,163)		(35,268)
Common stock repurchased and retired under share repurchase program			(4,195,247)	(169,400)
Ending balance		22,334,010	37,566,540	22,305,256	22,334,010	37,663,509	37,566,540
Merger conversion ratio			0.933
Common stock issued to Legacy Amplify stockholders			20,837,633				20,837,633
Midstates stock outstanding and acquired with the Merger			20,415,005
Treasury shares acquired from the Merger			205,861
Cancelation and retirement of shares			(347,567)
[1]	Represents the net settlement on vesting of restricted stock necessary to satisfy the minimum statutory tax withholding requirements.

Equity (Deficit) - Summary of A

Equity (Deficit) - Summary of Assumptions used to Estimate the Fair Value (Detail) - Warrants [Member]	May 04, 2017$ / shares
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis Valuation Techniques [Line Items]
Calculated fair value	$ 2.20
Risk-free Interest Rate [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis Valuation Techniques [Line Items]
Fair values of warrants, measurement input	0.0206
Dividend Yield [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis Valuation Techniques [Line Items]
Fair values of warrants, measurement input	0
Expected Life [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis Valuation Techniques [Line Items]
Fair values of warrants, measurement input	5 years
Expected Volatility [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis Valuation Techniques [Line Items]
Fair values of warrants, measurement input	0.500
Strike Price [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis Valuation Techniques [Line Items]
Fair values of warrants, measurement input	42.60

Earnings per Share - Calculatio

Earnings per Share - Calculation of Earnings (Loss) per Share (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019
Earnings Per Share [Line Items]
Net income (loss)		$ (464,030)	$ (35,197)
Less: Net income (loss) allocated to participating restricted stockholders		0	0
Basic and diluted earnings available to common stockholders		$ (464,030)	$ (35,197)
Weighted average common shares outstanding:
Common shares outstanding — basic		37,612	29,301
Common shares outstanding — diluted		37,612	29,301
Earnings (loss) per share: (See Note 11)
Basic		$ (12.34)	$ (1.20)
Diluted		$ (12.34)	$ (1.20)
Warrants [Member]
Earnings (loss) per share: (See Note 11)
Antidilutive stock options or warrants	[1]	2,174	9,154
[1]	Amount represents warrants to purchase common stock that are excluded from the diluted net earnings per share calculations because of their antidilutive effect.

Equity-based Awards - Additiona

Equity-based Awards - Additional Information (Detail) $ / shares in Units, $ in Millions		Aug. 06, 2019$ / sharesshares		Aug. 05, 2019shares	Mar. 07, 2019shares	Dec. 31, 2019$ / sharesshares	Aug. 05, 2019shares		Dec. 31, 2020USD ($)Installment$ / sharesshares	Dec. 31, 2019$ / sharesshares	Dec. 31, 2018shares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Common stock, par value | $ / shares						$ 0.01			$ 0.01	$ 0.01
TSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Unrecognized compensation cost | $									$ 0.3
Weighted-average period of unrecognized compensation cost									1 year 3 months 18 days
PSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Unrecognized compensation cost | $									$ 0.1
Weighted-average period of unrecognized compensation cost									1 year 4 months 24 days
Decrease in share targets | $ / shares									$ 0.25
PSUs [Member] | Market Vesting Date [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock units vesting percentage									50.00%
PSUs [Member] | First Anniversary Market-Vesting Date [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock units vesting percentage									25.00%
PSUs [Member] | Second Anniversary Market-Vesting Date [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock units vesting percentage									25.00%
Midstates Restricted Stock Units [Member] | Market Condition Awards [Member] | Non-Employee Director [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares outstanding				585,547		0	585,547			0
Shares vested				585,547
Midstates 2019 Performance Stock Units
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares outstanding						0				0
Shares granted					193,921
Shares cancelled										193,921
Midstates Non-Employee Director Restricted Stock Units | Market Condition Awards [Member] | Non-Employee Director [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares outstanding				50,864		0	50,864			0
Shares vested				50,864
Midstates 2016 Long Term Incentive Plan [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares available for future distribution (in shares)									2,167,996
Shares outstanding				54,365		0	54,365			0
Shares vested										54,365
Vesting period										3 years
Expiration period										10 years
2017 Non-Employee Directors Compensation Plan [Member] | Restricted Stock Units (RSUs)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Merger conversion ratio	[1]	0.933
Shares available for future distribution (in shares)									104,503
Weighted-average period of unrecognized compensation cost									1 year 3 months 18 days
Number of vesting annually equal installments | Installment									3
Vesting date description									Awards granted generally vest annually in three equal installments on each of the first three anniversaries of the grant date, subject to the grantee’s continued employment through each such vesting date.
Shares outstanding		30,616	[2]	32,814		16,157	32,814		8,898	16,157	39,604
Shares vested						14,459	49,723		7,259
Shares granted						0	42,933	[3]	0
Shares cancelled						0	0		0
2017 Non-Employee Directors Compensation Plan [Member] | Restricted Stock Units (RSUs) | Maximum [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Unrecognized compensation cost | $									$ 0.1
Legacy Amplify [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Common stock, par value | $ / shares		$ 0.0001
Merger conversion ratio		0.933
Shares available for future distribution (in shares)									1,046,698
[1]	The merger ratio used to convert Legacy Amplify Board RSUs into newly issued Company Board RSUs.
[2]	This reflects the unvested Board RSU awards converted into newly issued Board RSUs at August 6, 2019 in which the stock price was at $5.12 per share.
[3]	The aggregate grant date fair value of Board RSUs issued for the period from January 1, 2019 through August 5, 2019 was $0.3 million based on a grant date market price of $6.95 per share.

Equity-based Awards - Summary o

Equity-based Awards - Summary of Information Regarding Restricted Stock Unit Awards (Detail) - $ / shares		Aug. 06, 2019		Dec. 31, 2019		Dec. 31, 2019	Aug. 05, 2019		Dec. 31, 2020		Dec. 31, 2019
TSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Weighted-Average Grant Date Fair Value per unit, Beginning balance				$ 5.12
Outstanding, Weighted-Average Grant Date Fair Value per unit, Ending balance		$ 5.12
Management Incentive Plan [Member] | TSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Number of Units, Beginning Balance		422,556		394,245	[1]	422,556	598,024		291,370		598,024
Granted, Number of Units				17,500	[2]		300,517	[3]	43,250	[4]
Forfeited, Number of Units				(38,652)			(38,151)		(93,845)
Vested, Number of Units				(81,723)			(437,834)		(124,978)
Outstanding, Number of Units, Ending Balance		394,245	[1]	291,370		291,370	422,556		115,797		291,370
Merger conversion ratio	[5]	0.933
Converted TSUs		394,245
Outstanding, Weighted-Average Grant Date Fair Value per unit, Beginning balance	[6]	$ 10.87		$ 5.12	[1]	$ 10.87	$ 11.35		$ 5.18		$ 11.35
Granted, Weighted-Average Grant Date Fair Value per Unit	[6]			6.14	[2]		6.80	[3]	3.10	[4]
Forfeited, Weighted-Average Grant Date Fair Value per Unit	[6]			5.12			11.13		5.12
Vested, Weighted-Average Grant Date Fair Value per Unit	[6]			5.12			8.71		5.17
Outstanding, Weighted-Average Grant Date Fair Value per unit, Ending balance	[6]	$ 5.12	[1]	$ 5.18		$ 5.18	$ 10.87		$ 4.47		$ 5.18
Merger conversion ratio	[5]	0.933
Management Incentive Plan [Member] | PSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Number of Units, Beginning Balance		388,500		362,471	[7]	388,500	393,500		305,893		393,500
Granted, Number of Units				17,500	[8]		17,750	[9]	43,250	[10]
Forfeited, Number of Units				(74,078)			(22,750)		(134,589)
Vested, Number of Units				0			0		0
Outstanding, Number of Units, Ending Balance		362,471	[7]	305,893		305,893	388,500		214,554		305,893
Merger conversion ratio	[11]	0.933
Converted TSUs		362,471
Outstanding, Weighted-Average Grant Date Fair Value per unit, Beginning balance	[6]	$ 7.98		$ 2.11	[7]	$ 7.98	$ 8.14		$ 2.15		$ 8.14
Granted, Weighted-Average Grant Date Fair Value per Unit	[6]			2.87	[8]		4.06	[9]	3.03	[10]
Forfeited, Weighted-Average Grant Date Fair Value per Unit	[6]			2.11			7.59		2.11
Vested, Weighted-Average Grant Date Fair Value per Unit	[6]			0			0		0
Outstanding, Weighted-Average Grant Date Fair Value per unit, Ending balance	[6]	$ 2.11	[7]	$ 2.15		$ 2.15	$ 7.98		$ 2.36		$ 2.15
Merger conversion ratio	[11]	0.933
[1]	This reflects the unvested TSUs converted into newly issued Company’s TSUs at August 6, 2019 at a stock price of $5.12 per share.
[2]	The aggregate grant date fair value of TSUs issued for the period August 6, 2019 through December 31, 2019 was $0.1 million based on a grant date market price of $6.14 per share.
[3]	The aggregate grant date fair value of TSUs issued for the period from January 1, 2019 through August 5, 2019 was $2.0 million based on a grant date market price ranging from $4.48 to $8.70 per share.
[4]	The aggregate grant date fair value of TSUs issued for the year ended December 31, 2020 was $0.1 million based on a grant date market price ranging from $0.54 to $6.61 per share.
[5]	The merger ratio used to convert Legacy Amplify TSUs into newly issued TSUs.
[6]	Determined by dividing the aggregate grant date fair value of awards by the number of awards issued.
[7]	This reflects the unvested PSU awards converted into newly issued PSUs at August 6, 2019 based on a calculated fair value price ranging from $1.64 to $2.63 per share.
[8]	The aggregate grant date fair value of PSUs issued for the period August 6, 2019 through December 31, 2019 was less than $0.1 million based on a calculated fair value price ranging from $2.38 to $3.40 per share.
[9]	The aggregate grant date fair value of PSUs issued for the period January 1, 2019 through August 5, 2019 was less than $0.1 million based on a calculated fair value price ranging from $1.64 to $6.76 per share.
[10]	The aggregate grant date fair value of PSUs issued for the year ended December 31, 2020 was $0.1 million based on a calculated fair value price ranging from $2.46 to $3.66 per share.
[11]	The merger ratio used to convert Legacy Amplify PSUs into newly issued Company PSUs.

Equity-based Awards - Summary_2

Equity-based Awards - Summary of Information Regarding Restricted Stock Unit Awards (Parenthetical) (Detail) - USD ($) $ / shares in Units, $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Aug. 06, 2019	Aug. 05, 2019
TSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate grant date fair value of restricted stock units issued	$ 0.1	$ 0.1		$ 2
Grant Date Market Price		$ 6.14
Unvested awards converted into newly issued TSUs			$ 5.12
TSUs [Member] | Minimum [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Grant Date Market Price	$ 0.54			$ 4.48
TSUs [Member] | Maximum [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Grant Date Market Price	$ 6.61			8.70
PSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate grant date fair value of restricted stock units issued	$ 0.1
PSUs [Member] | Minimum [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Calculated fair value price	$ 2.46	$ 2.38	1.64	$ 1.64
PSUs [Member] | Maximum [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate grant date fair value of restricted stock units issued		$ 0.1		$ 0.1
Calculated fair value price	$ 3.66	$ 3.40	$ 2.63	$ 6.76

Equity-based Awards - Summary_3

Equity-based Awards - Summary of Fair Value Assumptions (Detail) - PSUs [Member] - $ / shares	Apr. 01, 2020	Jan. 01, 2020	Oct. 01, 2019	Jul. 01, 2019	Apr. 01, 2019	Jan. 01, 2019	Dec. 31, 2020	Dec. 31, 2019
Share Price Target 12.50 [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Share price targets							$ 12.50	$ 12.50
Risk-free interest rate	1.61%	1.61%	1.50%	1.73%	2.28%	2.44%
Dividend yield	12.10%	12.10%						0.00%
Expected volatility	60.00%	60.00%	65.00%	57.00%	50.00%	54.00%
Calculated fair value per PSU	$ 3.66	$ 3.66	$ 3.40	$ 2.63	$ 4.22	$ 6.76
Share Price Target 15.00 [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Share price targets							15	$ 15
Risk-free interest rate	1.61%	1.61%	1.50%	1.73%	2.28%	2.44%
Dividend yield	12.10%	12.10%						0.00%
Expected volatility	60.00%	60.00%	65.00%	57.00%	50.00%	54.00%
Calculated fair value per PSU	$ 2.98	$ 2.98	$ 2.83	$ 2.05	$ 3.43	$ 5.86
Share Price Target 17.50 [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Share price targets							$ 17.50	$ 17.50
Risk-free interest rate	1.61%	1.61%	1.50%	1.73%	2.28%	2.44%
Dividend yield	12.10%	12.10%						0.00%
Expected volatility	60.00%	60.00%	65.00%	57.00%	50.00%	54.00%
Calculated fair value per PSU	$ 2.46	$ 2.46	$ 2.38	$ 1.64	$ 2.80	$ 5.11

Equity-based Awards - Summary_4

Equity-based Awards - Summary of Information Regarding Restricted Stock Awards (Detail) - Restricted Stock Units (RSUs) - 2017 Non-Employee Directors Compensation Plan [Member] - $ / shares		Aug. 06, 2019		Dec. 31, 2019		Dec. 31, 2019	Aug. 05, 2019		Dec. 31, 2020	Dec. 31, 2019
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Number of Units, Beginning Balance		32,814		30,616	[1]	32,814	39,604		16,157	39,604
Granted, Number of Units				0			42,933	[2]	0
Forfeited, Number of Units				0			0		0
Vested, Number of Units				(14,459)			(49,723)		(7,259)
Outstanding, Number of Units, Ending Balance		30,616	[1]	16,157		16,157	32,814		8,898	16,157
Merger conversion ratio	[3]	0.933
Converted Board RSUs		30,616
Outstanding, Weighted-Average Grant Date Fair Value per unit, Beginning balance	[4]	$ 8.35		$ 5.12	[1]	$ 8.35	$ 11.36		$ 5.12	$ 11.36
Granted, Weighted-Average Grant Date Fair Value per Unit	[4]			0			6.95	[2]	0
Forfeited, Weighted-Average Grant Date Fair Value per Unit	[4]			0			0		0
Vested, Weighted-Average Grant Date Fair Value per Unit	[4]			5.12			9.54		5.12
Outstanding, Weighted-Average Grant Date Fair Value per unit, Ending balance	[4]	$ 5.12	[1]	$ 5.12		$ 5.12	$ 8.35		$ 5.12	$ 5.12
[1]	This reflects the unvested Board RSU awards converted into newly issued Board RSUs at August 6, 2019 in which the stock price was at $5.12 per share.
[2]	The aggregate grant date fair value of Board RSUs issued for the period from January 1, 2019 through August 5, 2019 was $0.3 million based on a grant date market price of $6.95 per share.
[3]	The merger ratio used to convert Legacy Amplify Board RSUs into newly issued Company Board RSUs.
[4]	Determined by dividing the aggregate grant date fair value of awards by the number of awards issued.

Equity-based Awards - Summary_5

Equity-based Awards - Summary of Information Regarding Restricted Stock Awards (Parenthetical) (Detail) - Restricted Stock Units (RSUs) - 2017 Non-Employee Directors Compensation Plan [Member] - USD ($) $ / shares in Units, $ in Millions		Dec. 31, 2020	Dec. 31, 2019	Aug. 06, 2019	[2]	Aug. 05, 2019	Dec. 31, 2018
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate grant date fair value of restricted stock units issued						$ 0.3
Grant Date Market Price						$ 6.95
Unvested awards converted into newly issued TSUs	[1]	$ 5.12	$ 5.12	$ 5.12		$ 8.35	$ 11.36
[1]	Determined by dividing the aggregate grant date fair value of awards by the number of awards issued.
[2]	This reflects the unvested Board RSU awards converted into newly issued Board RSUs at August 6, 2019 in which the stock price was at $5.12 per share.

Equity-based Awards - Summary_6

Equity-based Awards - Summary of Amount of Compensation Expense Recognized (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)	$ 384	$ 3,042
TSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)	267	1,797
PSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)	98	981
Board RSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)	$ 19	$ 264

Leases - Additional Information

Leases - Additional Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Jan. 01, 2019
Lessee Lease Description [Line Items]
Operating lease - long term right-of-use asset	$ 2,500	$ 4,406
Operating Liabilities	$ 2,524	4,432
Lease, option to terminate	leases can be terminated with 30-day prior written notice
Lease termination period with prior written notice	30 days
Operating lease costs	$ 2,400	2,100
Loss on lease	$ 0	$ 4,247
ASU 2016-02 [Member]
Lessee Lease Description [Line Items]
Operating lease - long term right-of-use asset			$ 5,400
Operating Liabilities			$ 5,400

Leases - Schedule of Right-of-U

Leases - Schedule of Right-of-Use Assets and Lease Liabilities (Detail) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Lessee Lease Description [Line Items]
Right-of-use asset	$ 2,500	$ 4,406
Current lease liability	2,258	1,712
Long-term lease liability	266	2,720
Total lease liability	2,524	4,432
Accrued Liabilites [Member]
Lessee Lease Description [Line Items]
Current lease liability	$ 2,258	$ 1,712

Leases - Schedule of Maturity A

Leases - Schedule of Maturity Analysis of Minimum Lease Payment Obligation Under Non-cancellable Operating Leases (Detail) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Lessee Lease Description [Line Items]
2021	$ 2,265
2022	297
2023	35
2024 and thereafter	0
Total lease payments	2,597
Less: interest	73
Present value of lease liabilities	2,524	$ 4,432
Office Leases [Member]
Lessee Lease Description [Line Items]
2021	1,631
2022	140
2023	0
2024 and thereafter	0
Total lease payments	1,771
Less: interest	51
Present value of lease liabilities	1,720
Leased Vehicles and Office Equipment [Member]
Lessee Lease Description [Line Items]
2021	634
2022	157
2023	35
2024 and thereafter	0
Total lease payments	826
Less: interest	22
Present value of lease liabilities	$ 804

Leases - Schedule of Weighted A

Leases - Schedule of Weighted Average Remaining Lease Terms and Discount Rate of Operating Leases (Detail)	Dec. 31, 2020	Dec. 31, 2019
Office Leases [Member]
Lessee Lease Description [Line Items]
Weighted average remaining lease term	8 months 26 days	1 year 6 months
Weighted average discount rate	3.41%	3.63%
Vehicles [Member]
Lessee Lease Description [Line Items]
Weighted average remaining lease term	4 months 2 days	5 months 8 days
Weighted average discount rate	0.96%	0.84%
Office Equipment [Member]
Lessee Lease Description [Line Items]
Weighted average remaining lease term	14 days	29 days
Weighted average discount rate	0.17%	0.18%

Supplemental Disclosures to t_3

Supplemental Disclosures to the Consolidated Balance Sheet and Condensed Statement of Cash Flows - Summary of Current Accrued Liabilities (Detail) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Accrued Liabilities Current [Abstract]
Accrued lease operating expense	$ 8,978	$ 11,794
Accrued commitment fee and other expense	4,404	0
Accrued general and administrative expense	3,349	3,126
Operating lease liability	2,258	1,712
Accrued production and ad valorem tax	2,601	520
Accrued capital expenditures	173	5,515
Asset retirement obligations	424	623
Accrued current income taxes	110	0
Accrued interest payable	26	36
Other	354	32
Accrued liabilities	$ 22,677	$ 23,358

Supplemental Disclosures to t_4

Supplemental Disclosures to the Consolidated Balance Sheet and Condensed Statement of Cash Flows - Summary of Cash and Cash Equivalents Reconciliation (Detail) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Cash And Cash Equivalents [Abstract]
Cash and cash equivalents	$ 10,364	$ 0
Restricted cash	0	325
Total cash, cash equivalents and restricted cash	$ 10,364	$ 325	$ 50,029

Supplemental Disclosures to t_5

Supplemental Disclosures to the Consolidated Balance Sheet and Condensed Statement of Cash Flows - Summary of Supplemental Cash Flows (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Supplemental cash flows:
Cash paid for interest, net of amounts capitalized	$ 10,331	$ 15,937
Cash paid for reorganization items, net	566	1,057
Cash paid for taxes	85	0
Noncash investing and financing activities:
Change in capital expenditures in payables and accrued liabilities	(5,343)	2,143
Assumption of asset retirement obligations related to Merger	0	9,440
Assets acquired & liabilities assumed in the Merger:
Accounts receivable	0	14,633
Prepaids and other current assets	0	3,229
Other non-current assets	0	9,075
Oil and natural gas properties	0	149,421
Other property and equipment	0	1,694
Accounts payable and other current liabilities	0	(24,135)
Other non-current liabilities	0	(5,067)
Long-term debt	0	(76,559)
Issuance of common stock in connection with the Merger	$ 0	$ 91,541

Related Party Transactions - Ad

Related Party Transactions - Additional Information (Detail) - USD ($) $ in Thousands	Dec. 11, 2020	Dec. 31, 2020	Dec. 31, 2019
Related Party Transactions [Abstract]
Significant transaction with related party		$ 0	$ 0
Underwriters option to purchase additional shares from selling stockholders	8,548,485
Proceeds from issuance of common stock	$ 0

Commitments and Contingencies -

Commitments and Contingencies - Additional Information (Detail)	Jun. 24, 2019USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2020USD ($)$ / bbl	Dec. 31, 2019USD ($)
Commitments and Contingencies Additional Textual [Abstract]
Remaining environmental accrued liability recorded		$ 0	$ 0	$ 0
Obligatory monthly deposit into sinking fund account per barrel of oil | $ / bbl			0.25
Sinking fund account maximum value upon which obligation ceases			$ 4,300,000
Beta's decommissioning obligations, previously supported by surety bonds			71,300,000
Beta's decommissioning obligations, cash			90,200,000
Proceeds from Beta Decommissioning Trust account	$ 90,000,000
Beta's decommissioning obligations, full supported by surety bonds			161,300,000
Beta's decommissioning remaining obligations, cash			300,000
Rent expense			8,300,000	$ 7,500,000
Commitment fee/expense		$ 700,000	2,100,000
Commitment fee/expense			1,800,000
SPBPC Collateral Contractual pipeline and surface facilities abandonment [Member]
Commitments and Contingencies Additional Textual [Abstract]
Restricted Investment - decommissioning of offshore production facilities			$ 4,600,000

Commitments and Contingencies_2

Commitments and Contingencies - Purchase Commitments Under the Contracts (Detail) $ in Thousands	Dec. 31, 2020USD ($)
CO2 Minimum Purchase Commitment [Member]
Recorded Unconditional Purchase Obligation [Line Items]
Total	$ 6,969
2021	3,729
2022	3,240
2023	0
2024	0
2025	0
Thereafter	0
Midstream services [Member]
Recorded Unconditional Purchase Obligation [Line Items]
Total	28,193
2021	12,841
2022	12,394
2023	2,958
2024	0
2025	0
Thereafter	$ 0

Income Taxes - Components of In

Income Taxes - Components of Income Tax Expense (Benefit) (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Current taxes:
Federal	$ (5)	$ 0
State	(110)	50
Total current income tax benefit (expense)	(115)	50
Deferred taxes:
Federal	0	0
State	0	0
Total deferred income tax benefit (expense)	0	0
Total income tax benefit (expense)	$ (115)	$ 50

Income Taxes - Additional Infor

Income Taxes - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Line Items]
Statutory tax rate	21.00%	21.00%
Valuation Allowance	$ 300,386,000	$ 189,941,000
Increase to valuation allowance	110,500,000
Unrecognized Tax Benefits	0
United States [Member]
Income Tax Disclosure [Line Items]
Operating loss carryforwards not subject to expiration	$ 710,100,000
Operating loss carryforwards expiration year	2037
Post merger operating loss Carry forwards	$ 31,600,000
State [Member]
Income Tax Disclosure [Line Items]
Operating loss carryforwards not subject to expiration	$ 367,300,000
Operating loss carryforwards expiration year	2037
Maximum [Member] | United States [Member]
Income Tax Disclosure [Line Items]
Net operating loss carryforwards	$ 732,100,000
Maximum [Member] | State [Member]
Income Tax Disclosure [Line Items]
Net operating loss carryforwards	$ 420,300,000

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Income Tax Benefit (Provision) (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Expected tax benefit (expense) at federal statutory rate	$ 97,423	$ 7,402
State income tax benefit (expense), net of federal benefit	6,189	946
Non-deductible expenses	(45)	(3,659)
Changes in valuation allowances	(110,445)	(4,332)
State rate change, net of federal benefit	6,100	0
Non-cash compensation	(137)	(367)
Other	800	60
Total income tax benefit (expense)	$ (115)	$ 50

Income Taxes - Components of Ne

Income Taxes - Components of Net Deferred Income Tax Liabilities (Detail) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Deferred income tax assets:
Property, Plant & Equipment	$ 115,695	$ 37,075
Net operating loss carryforward	174,479	141,534
Derivatives	2,448	0
Disallowed interest expense	5,388	10,627
Accrued liabilities	1,226	1,431
Other	1,717	4,234
Total deferred income tax assets:	300,953	194,901
Valuation allowance	(300,386)	(189,941)
Net deferred income tax assets	567	4,960
Deferred income tax liabilities:
Derivatives	0	2,767
Other	567	2,193
Total deferred income tax liabilities	567	4,960
Net deferred income tax liabilities	$ 0	$ 0

Supplemental Oil and Gas Info_3

Supplemental Oil and Gas Information (Unaudited) - Schedule of Capitalized Costs Relating to Oil and Natural Gas Producing Activities (Detail) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Extractive Industries [Abstract]
Evaluated oil and natural gas properties	$ 775,167	$ 797,005
Support equipment and facilities	142,208	140,023
Accumulated depletion, depreciation, and amortization	(602,861)	(136,747)
Total	$ 314,514	$ 800,281

Supplemental Oil and Gas Info_4

Supplemental Oil and Gas Information (Unaudited) - Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development Activities (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Extractive Industries [Abstract]
Property acquisition costs, proved	$ 42	$ 150,871
Property acquisition costs, unproved	49,307	7,674
Exploration	0	0
Development	29,543	71,460
Total	$ 19,722	$ 230,005

Supplemental Oil and Gas Info_5

Supplemental Oil and Gas Information (Unaudited) - Additional Information (Detail) - MMBoe	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Extractive Industries [Abstract]
Percent of discount factor to proved reserves	10.00%
Increase (reduction) in reserves	(49.2)	(22.8)
Downward price revisions in proved reserve	50.1	25.9
Upward revision due to lower maintenance cost	10.7
Extensions and discoveries	0.46
Downward revisions due to updated well performance data		12.1
Acquisition of oil and gas properties		69.7

Supplemental Oil and Gas Info_6

Supplemental Oil and Gas Information (Unaudited) - Schedule of Product Prices Used for Valuing the Reserves (Detail)	12 Months Ended
	Dec. 31, 2020$ / MMBTU$ / bbl	Dec. 31, 2019$ / MMBTU$ / bbl
Oil [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Product prices for reserves	39.57	55.69
NGL [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Product prices for reserves	39.57	55.69
Natural Gas [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Product prices for reserves | $ / MMBTU	1.99	2.58

Supplemental Oil and Gas Info_7

Supplemental Oil and Gas Information (Unaudited) - Schedule of Net Reserves (Detail)	12 Months Ended
	Dec. 31, 2020MBoeMMBoebblMMcf	Dec. 31, 2019MBoebblMMcf
Supplemental Oil And Gas Reserve Information [Line Items]
Extensions and discoveries | MMBoe	0.46
Oil [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, Beginning of year	70,772	69,624
Extensions and discoveries	291	301
Production	(3,887)	(3,498)
Revision of previous estimates	(20,500)	(13,084)
Proved developed and undeveloped reserves, End of year	46,676	70,772
Proved developed reserves, Beginning of year	53,476	54,147
Proved developed reserves, End of year	35,613	53,476
Proved undeveloped reserves, Beginning of year	17,296	15,477
Proved undeveloped reserves, End of year	11,063	17,296
Purchase of minerals in place		17,429
Natural Gas [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, Beginning of year | MMcf	377,869	293,959
Extensions and discoveries | MMcf	655	576
Production | MMcf	(27,473)	(26,489)
Revision of previous estimates | MMcf	(76,912)	(92,586)
Proved developed and undeveloped reserves, End of year | MMcf	274,139	377,869
Proved developed reserves, Beginning of year | MMcf	320,731	232,110
Proved developed reserves, End of year | MMcf	252,218	320,731
Proved undeveloped reserves, Beginning of year | MMcf	57,138	61,849
Proved undeveloped reserves, End of year | MMcf	21,921	57,138
Purchase of minerals in place | MMcf		202,409
NGLs [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, Beginning of year	29,252	21,572
Extensions and discoveries	61	44
Production	(1,725)	(1,343)
Revision of previous estimates	(6,104)	(9,554)
Proved developed and undeveloped reserves, End of year	21,484	29,252
Proved developed reserves, Beginning of year	23,646	17,324
Proved developed reserves, End of year	19,009	23,646
Proved undeveloped reserves, Beginning of year	5,606	4,248
Proved undeveloped reserves, End of year	2,475	5,606
Purchase of minerals in place		18,533
Proved Reserves, Total
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, Beginning of year | MBoe	163,002	140,189
Production | MBoe	(10,190)	(9,256)
Revision of previous estimates | MBoe	(39,424)	(38,069)
Proved developed and undeveloped reserves, End of year | MBoe	113,849	163,002
Extensions and discoveries | MBoe	461	441
Proved developed reserves, Beginning of year | MBoe	130,577	110,156
Proved developed reserves, End of year | MBoe	96,658	130,577
Proved undeveloped reserves, Beginning of year | MBoe	32,425	30,033
Proved undeveloped reserves, End of year | MBoe	17,191	32,425
Purchase of minerals in place | MBoe		69,697

Supplemental Oil and Gas Info_8

Supplemental Oil and Gas Information (Unaudited) -Standardized Measure of Discounted Future Net Cash Flows (Detail) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Extractive Industries [Abstract]
Future cash inflows	$ 2,410,260	$ 5,146,288
Future production costs	(1,589,945)	(2,917,262)
Future development costs	(375,146)	(567,423)
Future income tax expense	0	0
Future net cash flows for estimated timing of cash flows	445,169	1,661,603
10% annual discount for estimated timing of cash flows	(147,358)	(745,042)
Standardized measure of discounted future net cash flows	$ 297,811	$ 916,561	$ 1,113,029

Supplemental Oil and Gas Info_9

Supplemental Oil and Gas Information (Unaudited) - Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Extractive Industries [Abstract]
Beginning of year	$ 916,561	$ 1,113,029
Sale of oil and natural gas produced, net of production costs	(47,687)	(113,545)
Purchase of minerals in place	0	408,370
Extensions and discoveries	3,687	5,334
Changes in prices and costs	(548,429)	(623,592)
Previously estimated development costs incurred	49,144	84,341
Net changes in future development costs	89,997	110,892
Revisions of previous quantities	(150,245)	(183,300)
Accretion of discount	91,657	92,998
Change in production rates and other	(106,874)	22,034
End of year	$ 297,811	$ 916,561