Amplify Energy (AMPY) 10-K 5 Mar 20 2019 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Feb. 28, 2020	Jun. 28, 2019
Cover [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2019
Document Fiscal Year Focus	2019
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	Accelerated Filer
Entity Shell Company	false
Entity Small Business	false
Entity Emerging Growth Company	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		37,565,610
Entity Public Float			$ 76.6
Documents Incorporated by Reference	Documents Incorporated By Reference :

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 0	$ 49,704
Restricted cash	325	325
Accounts receivable	33,145	29,514
Short-term derivative instruments	5,879	18,813
Prepaid expenses and other current assets	13,238	7,241
Total current assets	52,587	105,597
Property and equipment, at cost:
Oil and natural gas properties, successful efforts method	797,005	598,331
Support equipment and facilities	140,023	108,760
Other	8,045	6,625
Accumulated depreciation, depletion and impairment	(141,350)	(85,535)
Property and equipment, net	803,723	628,181
Long-term derivative instruments	6,364	2,469
Restricted investments	4,622	94,467
Operating lease - long term right-of-use asset	4,406	0
Other long-term assets	5,837	6,129
Total assets	877,539	836,843
Current liabilities:
Accounts payable	8,310	2,345
Revenues payable	29,167	24,779
Accrued liabilities (see Note 16)	23,358	23,155
Short-term derivative instruments	253	139
Total current liabilities	61,088	50,418
Long-term debt (see Note 11)	285,000	294,000
Asset retirement obligations	90,466	75,867
Long-term derivative instruments	305	0
Operating lease liability	2,720	0
Other long-term liabilities	3,753	0
Total liabilities	443,332	420,285
Commitments and contingencies (see Note 18)
Stockholders' equity:
Preferred stock, $0.01 par value: 50,000,000 shares authorized; no shares issued and outstanding at December 31, 2019 and preferred stock, $0.0001 par value 45,000,000 shares authorized; no shares issued and outstanding at December 31, 2018	0	0
Warrants, 9,153,522 warrants issued and outstanding at December 31, 2019 and 2,173,913 warrants issued and outstanding at December 31, 2018, respectively	4,790	4,788
Common stock, $0.01 par value: 250,000,000 shares authorized; 37,566,540 shares issued and outstanding at December 31, 2019 and common stock, $0.0001 par value 300,000,000 shares authorized; 22,181,881 shares issued and outstanding at December 31, 2018	209	3
Additional paid-in capital	424,399	355,872
Accumulated earnings	4,809	55,895
Total stockholders' equity	434,207	416,558
Total liabilities and equity	$ 877,539	$ 836,843

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Dec. 31, 2019	Dec. 31, 2018
Statement Of Financial Position [Abstract]
Preferred stock, par value	$ 0.01	$ 0.0001
Preferred stock, shares authorized	50,000,000	45,000,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Warrants issued	9,153,522	2,173,913
Warrants outstanding	9,153,522	2,173,913
Common stock, par value	$ 0.01	$ 0.0001
Common stock, shares authorized	250,000,000	300,000,000
Common stock, shares issued	37,566,540	22,181,881
Common stock, shares outstanding	37,566,540	22,181,881

STATEMENTS OF CONSOLIDATED OPER

STATEMENTS OF CONSOLIDATED OPERATIONS - USD ($) shares in Thousands, $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Revenues:
Total revenues		$ 205,479	$ 275,575	$ 340,144
Costs and expenses:
Lease operating expense		74,547	123,918	114,405
Exploration		32	51	3,045
Taxes other than income		11,101	18,668	20,364
Depreciation, depletion, and amortization		35,979	55,843	52,334
Impairment expense		0	2,246	0
General and administrative expense		29,506	55,288	43,129
Accretion of asset retirement obligations		4,384	5,559	5,711
(Gain) loss on commodity derivative instruments		31,609	6,700	(8,155)
(Gain) loss on sale of properties		0	0	3,614
Other, net		485	798	943
Total costs and expenses		206,295	287,546	258,621
Operating income (loss)		(816)	(11,971)	81,523
Other income (expense):
Interest expense, net		(15,936)	(16,855)	(21,923)
Other income (expense)		16,981	(1,117)	190
Loss on lease		0	(4,247)	0
Gain (loss) on extinguishment on debt		0	0	(3,034)
Total other income (expense)		1,045	(22,219)	(24,767)
Income (loss) before reorganization items, net and income taxes		229	(34,190)	56,756
Reorganization items, net		(1,119)	(1,057)	(2,147)
Income tax benefit (expense)		2,176	50	0
Net income (loss)		1,286	(35,197)	54,609
Net income (loss) attributable to Successor/Predecessor		1,286	(35,197)	54,609
Successor/Predecessor interest in net income (loss):
Net income (loss) attributable to Successor/Predecessor		1,286	(35,197)	54,609
Net (income) loss allocated to participating restricted stockholders		(35)	0	(2,426)
Net income (loss) available to common stockholders/limited partners		$ 1,251	$ (35,197)	$ 52,183
Earnings per share/unit: (See Note 13)
Basic and diluted earnings per share/unit		$ 0.05	$ (1.20)	$ 2.09
Weighted average common shares/units outstanding:
Basic and diluted		25,000	29,301	24,959
Predecessor [Member]
Revenues:
Total revenues	$ 109,201
Costs and expenses:
Lease operating expense	35,568
Exploration	21
Taxes other than income	5,187
Depreciation, depletion, and amortization	37,717
Impairment expense	0
General and administrative expense	31,606
Accretion of asset retirement obligations	3,407
(Gain) loss on commodity derivative instruments	(23,076)
(Gain) loss on sale of properties	0
Other, net	36
Total costs and expenses	101,238
Operating income (loss)	7,963
Other income (expense):
Interest expense, net	(10,243)
Other income (expense)	8
Loss on lease	0
Gain (loss) on extinguishment on debt	0
Total other income (expense)	(10,235)
Income (loss) before reorganization items, net and income taxes	(2,272)
Reorganization items, net	(88,774)
Income tax benefit (expense)	91
Net income (loss)	(90,955)
Net income (loss) attributable to Successor/Predecessor	(90,955)
Successor/Predecessor interest in net income (loss):
Net income (loss) attributable to Successor/Predecessor	(90,955)
Net (income) loss allocated to participating restricted stockholders	0
Net income (loss) available to common stockholders/limited partners	$ (90,955)
Earnings per share/unit: (See Note 13)
Basic and diluted earnings per share/unit	$ (1.09)
Weighted average common shares/units outstanding:
Basic and diluted	83,807
Oil and Natural Gas Sales [Member]
Revenues:
Total revenues		$ 205,176	$ 274,607	$ 339,840
Oil and Natural Gas Sales [Member] | Predecessor [Member]
Revenues:
Total revenues	$ 108,970
Other Revenues [Member]
Revenues:
Total revenues		303	968	304
Other Revenues [Member] | Predecessor [Member]
Revenues:
Total revenues	231
Gathering, Processing and Transportation [Member]
Costs and expenses:
Gathering, processing, and transportation		$ 18,652	$ 18,475	$ 23,231
Gathering, Processing and Transportation [Member] | Predecessor [Member]
Costs and expenses:
Gathering, processing, and transportation	$ 10,772

STATEMENTS OF CONSOLIDATED CASH

STATEMENTS OF CONSOLIDATED CASH FLOWS - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Cash flows from operating activities:
Net income (loss)		$ 1,286	$ (35,197)	$ 54,609
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization		35,979	55,843	52,334
Impairment expense		0	2,246	0
(Gain) loss on derivative instruments		31,609	6,476	(8,155)
Cash settlements (paid) received on expired derivative instruments		30,446	4,344	10,087
Cash settlements (paid) on terminated derivatives		0	0	0
Bad debt expense		0	301	106
Deferred income tax expense (benefit)		(2,206)	0	0
Amortization and write-off of deferred financing costs		2,093	1,174	2,518
(Gain) loss on extinguishment of debt		0	0	3,034
Accretion of asset retirement obligations		4,384	5,559	5,711
(Gain) loss on sale of properties		0	0	3,614
Share-based compensation (see Note 14)		2,516	4,530	4,374
Settlement of asset retirement obligations		(633)	(259)	(767)
Write-off of other property, plant & equipment		0	1,325	0
Reorganization items, net		0	0	0
Other		0	(8)	0
Changes in operating assets and liabilities:
Accounts receivable		(2,830)	10,701	5,783
Prepaid expenses and other assets		5,578	713	623
Payables and accrued liabilities		(13,590)	(13,592)	7,925
Other		10	3,127	(15)
Net cash provided by operating activities		94,642	47,283	141,781
Cash flows from investing activities:
Cash acquired from the Merger		0	19,250	0
Additions to oil and gas properties		(52,735)	(72,709)	(55,425)
Additions to other property and equipment		(127)	(1,081)	(492)
Additions to restricted investments		(495)	(155)	(500)
Withdrawals of restricted investments		0	90,000	62,467
Proceeds from the sale of oil and natural gas properties, net of cash and cash equivalents sold		0	0	17,113
Other		0	10	503
Net cash provided by (used in) investing activities		(53,357)	35,315	23,666
Cash flows from financing activities:
Advances on revolving credit facilities		9,000	125,000	315,000
Repayments of revolving credit facilities		(63,000)	(134,000)	(397,000)
Deferred financing costs		(642)	(882)	(3,451)
Dividends to stockholders		0	(15,889)	0
Common stock repurchased and retired under the share repurchase program		0	(26,203)	0
Treasury stock acquired and retired		0	(3,340)	0
Retirement of common stock under tender offer		0	0	(35,000)
Costs incurred in conjunction with tender offer		0	(107)	(521)
Payment to holders of the Notes		(8,193)	0	0
Payment to Predecessor common unitholders		(1,250)	0	0
Contribution from management		1,500	0	0
Restricted units returned to plan		0	(406)	(847)
Other		(9)	84	9
Net cash provided by (used in) financing activities		(62,594)	(132,302)	(121,810)
Net change in cash, cash equivalents and restricted cash		(21,309)	(49,704)	43,637
Cash, cash equivalents and restricted cash, beginning of period		27,701	50,029	6,392
Cash, cash equivalents and restricted cash, end of period	$ 27,701	6,392	325	50,029
Predecessor [Member]
Cash flows from operating activities:
Net income (loss)	(90,955)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	37,717
Impairment expense	0
(Gain) loss on derivative instruments	(23,076)
Cash settlements (paid) received on expired derivative instruments	15,895
Cash settlements (paid) on terminated derivatives	94,146
Bad debt expense	0
Deferred income tax expense (benefit)	(74)
Amortization and write-off of deferred financing costs	0
(Gain) loss on extinguishment of debt	0
Accretion of asset retirement obligations	3,407
(Gain) loss on sale of properties	0
Share-based compensation (see Note 14)	3,667
Settlement of asset retirement obligations	(164)
Write-off of other property, plant & equipment	0
Reorganization items, net	68,356
Other	56
Changes in operating assets and liabilities:
Accounts receivable	1,024
Prepaid expenses and other assets	735
Payables and accrued liabilities	15,030
Other	(266)
Net cash provided by operating activities	125,498
Cash flows from investing activities:
Cash acquired from the Merger	0
Additions to oil and gas properties	(6,211)
Additions to other property and equipment	(76)
Additions to restricted investments	(209)
Withdrawals of restricted investments	0
Proceeds from the sale of oil and natural gas properties, net of cash and cash equivalents sold	0
Other	0
Net cash provided by (used in) investing activities	(6,496)
Cash flows from financing activities:
Advances on revolving credit facilities	16,600
Repayments of revolving credit facilities	(98,252)
Deferred financing costs	(8,575)
Dividends to stockholders	0
Common stock repurchased and retired under the share repurchase program	0
Treasury stock acquired and retired	0
Retirement of common stock under tender offer	0
Costs incurred in conjunction with tender offer	0
Payment to holders of the Notes	(16,446)
Payment to Predecessor common unitholders	0
Contribution from management	0
Restricted units returned to plan	(10)
Other	9
Net cash provided by (used in) financing activities	(106,674)
Net change in cash, cash equivalents and restricted cash	12,328
Cash, cash equivalents and restricted cash, beginning of period	15,373	27,701
Cash, cash equivalents and restricted cash, end of period	27,701
Midstates [Member]
Cash flows from financing activities:
Repayments of revolving credit facilities		$ 0	$ (76,559)	$ 0
Midstates [Member] | Predecessor [Member]
Cash flows from financing activities:
Repayments of revolving credit facilities	$ 0

STATEMENTS OF CONSOLIDATED AND

STATEMENTS OF CONSOLIDATED AND COMBINED EQUITY - USD ($) $ in Thousands	Total	Common Stock [Member]	Warrants [Member]	Additional Paid in Capital [Member]	Treasury Stock [Member]	Accumulated Earnings (Deficit)	Predecessor [Member]	Predecessor [Member]Common Stock [Member]	Predecessor [Member]Warrants [Member]	Predecessor [Member]Additional Paid in Capital [Member]	Predecessor [Member]Treasury Stock [Member]	Predecessor [Member]Accumulated Earnings (Deficit)	Predecessor [Member]Limited Partners Common Units [Member]
Balance at Dec. 31, 2016													$ 99,489
Net income (loss)							$ (90,955)						(90,955)
Cancellation and amortization of equity/unit-based awards													3,713
Restricted units repurchased and other													(2)
Issuance of common stock to Predecessor common unitholders													(7,707)
Issuance of warrants to Predecessor common unitholders													(4,788)
Contribution from management													1,500
Settlement with Predecessor common unitholders													(1,250)
Balance at May. 04, 2017													$ 0
Issuance of Successor common stock to holders of the Notes	$ 377,645	$ 3	$ 0	$ 377,642	$ 0	$ 0
Issuance of Successor warrants to Predecessor common unitholders							4,788	$ 0	$ 4,788	$ 0	$ 0	$ 0
Issuance of Successor common stock to Predecessor common unitholders							$ 7,707	$ 0	$ 0	$ 7,707	$ 0	$ 0
Balance at May. 04, 2017	390,140	3	4,788	385,349	0	0
Net income (loss)	1,286	0	0	0	0	1,286
Share-based compensation expense	2,516	0	0	2,516	0	0
Other	(9)	0	0	(9)	0	0
Balance at Dec. 31, 2017	393,933	3	4,788	387,856	0	1,286
Net income (loss)	54,609	0	0	0	0	54,609
Tender offer distribution	(35,520)	0	0	(35,520)	0	0
Share-based compensation expense	4,374	0	0	4,374	0	0
Restricted shares repurchased	(847)	0	0	(847)	0	0
Other	9	0	0	9	0	0
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 repurchased	(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

Organization and Basis of Prese

Organization and Basis of Presentation	12 Months Ended
	Dec. 31, 2019
Organization Consolidation And Presentation Of Financial Statements [Abstract]
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. As a result, period-to-period comparisons of our operating results may not be meaningful. The results of any one quarter should not be relied upon as an indication of future performance. 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. Legacy Amplify is the successor reporting company (the “Successor”) of Memorial Production Partners LP (“MEMP”) pursuant to Rule 15d-5 of the Securities Exchange Act of 1934, as amended. When referring to the “Predecessor” or the “Company” in reference to the period prior to Legacy Amplify emergence from bankruptcy, the intent is to refer to MEMP, the predecessor that was dissolved following the effective date of the Plan (as defined below) 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 South Texas. 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. Definitive Merger Agreement On May 5, 2019, as discussed above, the Company entered into the Merger Agreement pursuant to which Legacy Amplify merged with a subsidiary of Midstates in an all-stock merger-of-equals. Under 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 Merger closed on August 6, 2019. See Note 6 for additional information. Emergence from Voluntary Reorganization under Chapter 11 On January 16, 2017 (the “Petition Date”), MEMP and certain of its subsidiaries (collectively with MEMP, the “Debtors”) filed voluntary petitions (the cases commenced thereby, the “Chapter 11 proceedings”) under Chapter 11 of Title 11 of the United States Code (the “Bankruptcy Code” or “Chapter 11”) in the United States Bankruptcy Court for the Southern District of Texas, Houston Division (the “Bankruptcy Court”). The Debtors’ Chapter 11 proceedings were jointly administered under the caption In re: Memorial Production Partners LP, et al. Basis of Presentation Our Consolidated Financial Statements included herein have been prepared pursuant to the rule and guidelines of the Securities and Exchange Commission (the “SEC”). All 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”). Certain amounts in the prior year financial statements have been reclassified to conform to current presentation. Gain (loss) on extinguishment of deferred finance cost were previously accounted for as interest expense, net and are now being presented as gain (loss) on extinguishment of debt on our Statement of Consolidated Operations. Beginning in 2019, the Company has elected to change its reporting convention from natural gas equivalent (Mcfe) to barrels of oil equivalent (Boe). The change in presentation reflects our liquids-weighted production and reserve profile with a balanced approach to development of our oil and natural gas asset portfolio. 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”). ASC 852 requires that the financial statements, for periods subsequent to the Chapter 11 filing, distinguish transactions and events that are directly associated with the reorganization from the ongoing operations of the business. 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. The Company adopted the new accounting pronouncement related to the presentation of statement of cash flows — restricted cash in the first quarter of 2018. A retrospective change for the period from January 1, 2017 through May 4, 2017 and May 5, 2017 through December 31, 2017 on the Statement of Consolidated Cash Flows as previously presented was required due to adoption. The table below sets forth the retrospective adjustments for the periods presented: Predecessor Previously Period from January 1, 2017 through May 4, 2017 Adjustment Effect As Adjusted Period from January 1, 2017 through May 4, 2017 (In thousands) Changes in operating assets and liabilities: Restricted cash $ (7,561 ) $ 7,561 $ — Net cash provided by operating activities 117,937 7,561 125,498 Net change in cash and cash equivalents 4,767 7,561 12,328 Cash and cash equivalents, end of period 20,140 7,561 27,701 Successor Previously Period from May 5, 2017 through December 31, 2017 Adjustment Effect As Adjusted Period from May 5, 2017 through December 30, 2017 (In thousands) Changes in operating assets and liabilities: Restricted cash $ 7,561 $ (7,561 ) $ — Net cash provided by operating activities 102,203 (7,561 ) 94,642 Net change in cash and cash equivalents (13,748 ) (7,561 ) (21,309 ) Cash and cash equivalents, end of period 6,392 — 6,392 Comparability of Financial Statements to Prior Periods As discussed in further detail in Note 3 below, Legacy Amplify adopted and applied the relevant guidance provided in GAAP with respect to the accounting and financial statement disclosures for entities that have emerged from bankruptcy proceedings (“Fresh Start Accounting”). Accordingly, our Consolidated Financial Statements and Notes after May 4, 2017, are not comparable to the Consolidated Financial Statements and Notes prior to that date. To facilitate our financial statement presentations, we refer to the reorganized company in these Consolidated Financial Statements and Notes as the “Successor” for periods subsequent to May 4, 2017 and “Predecessor” for periods prior to May 5, 2017. Furthermore, our Consolidated Financial Statements and Notes have been presented with a “black line” division to delineate the lack of comparability between the Predecessor and Successor.

Emergence from Voluntary Reorga

Emergence from Voluntary Reorganization under Chapter 11	12 Months Ended
	Dec. 31, 2019
Reorganizations [Abstract]
Emergence from Voluntary Reorganization under Chapter 11	Note 2. Emergence from Voluntary Reorganization under Chapter 11 On the Petition Date, the Debtors filed voluntary petitions under the Bankruptcy Code in the Bankruptcy Court to pursue a Joint Chapter 11 Plan of Reorganization for the Debtors. The Debtors’ Chapter 11 proceedings were jointly administered under the caption In re Memorial Production Partners LP, et al. On April 14, 2017, the Bankruptcy Court entered an order (the “Confirmation Order”) approving the Plan. On the Effective Date, the Debtors satisfied the conditions to effectiveness of the Plan, the Plan became effective in accordance with its terms and Legacy Amplify emerged from bankruptcy. Although Legacy Amplify is no longer a debtor-in-possession, the Company was a debtor-in-possession from January 16, 2017 through May 4, 2017. As such, certain aspects of the Chapter 11 proceedings and related matters are described below in order to provide context to Legacy Amplify’s financial condition and results of operations for the period presented. Plan of Reorganization In accordance with the Plan, on the Effective Date: • The Successor issued (i) 25,000,000 new shares (the “New Common Shares”) of its common stock, par value $0.0001 per share (“common stock”); and (ii) warrants (the “Warrants”) to purchase up to 2,173,913 shares of Legacy Amplify’s common stock exercisable for a five-year period commencing on the Effective Date entitling their holders upon exercise thereof, on a pro rata basis, to 8% of the total issued and outstanding common shares (including common shares as of the Effective Date issuable upon full exercise of the Warrants, but excluding any common shares issuable under the Management Incentive Plan (the “MIP”)), at a per share exercise price of $42.60. • The holders of claims under the Predecessor’s revolving credit facility received a full recovery, consisting of a cash pay down and their pro rata share of the $1 billion exit senior secured reserve-based revolving credit facility (the “Emergence Credit Facility”), as further discussed in Note 11. • The 7.625% senior notes due May 2021 (“2021 Senior Notes”) and 6.875% senior notes due August 2022 (“2022 Senior Notes” and collectively, the “Notes”) were cancelled and the Predecessor’s liability thereunder discharged, and the holders of the Notes received (directly or indirectly) their pro rata share of New Common Shares representing, in the aggregate, 98% of the New Common Shares on the Effective Date (subject to dilution by the MIP and the common shares issuable upon exercise of the Warrants). Additionally, the holders of the Notes received their pro rata share of a $24.6 million cash distribution. • The Predecessor’s common units were cancelled, and each common unitholder received its pro rata share of: (i) 2% of the New Common Shares, (ii) the Warrants, and (iii) cash in an aggregate amount of approximately $1.3 million. • The holders of administrative expense claims, priority tax claims, other priority claims and general unsecured creditors of the Predecessor received in exchange for their claims payment in full in cash or otherwise had their rights unimpaired under Title 11 of the United States Code. • The Successor entered into a stockholders agreement with certain parties pursuant to which the Successor agreed to, at the direction of such stockholders, use commercially reasonable efforts to effect the sale of their common stock. • The Successor entered into a registration rights agreement with certain parties pursuant to which the Successor agreed to, among other things, file a registration statement with the SEC within 90 days of the receipt of a request from the stockholders party thereto covering the offer and resale of the common stock held by such stockholders. • The Company’s MIP became effective, such that an aggregate of 2,322,404 shares of Legacy Amplify’s common stock became available for grant pursuant to awards under the MIP. • The terms of the Predecessor’s general partner’s board of directors automatically expired on the Effective Date. The Successor formed a new seven-member board of directors consisting of the President and Chief Executive Officer, one director of the Predecessor, and five new members designated by certain parties to the plan support agreement.

Fresh Start Accounting

Fresh Start Accounting	12 Months Ended
	Dec. 31, 2019
Fresh Start Accounting [Abstract]
Fresh Start Accounting	Note 3. Fresh Start Accounting Upon emergence from the Chapter 11 proceedings on May 4, 2017, Legacy Amplify adopted fresh start accounting as required by GAAP. Legacy Amplify met the requirements of fresh start accounting, which include: (i) the holders of the Predecessor’s voting common units immediately prior to the Effective Date received less than 50% of the voting shares of Legacy Amplify and (ii) the reorganization value of our assets immediately prior to the Effective Date was less than the post-petition liabilities and allowed claims. Reorganization Value The Successor’s enterprise value, as approved by the Bankruptcy Court, was estimated to be within a range of $700 million to $900 million, with a midpoint estimate of approximately $800 million. Enterprise value represents the estimated fair value of a company’s interest-bearing debt and its shareholders’ equity. Based on the estimates and assumptions utilized in our fresh start accounting process, Legacy Amplify estimated the Successor’s enterprise value to be approximately $800 million before the consideration of cash and cash equivalents on hand at the Effective Date. Reorganization value represents the fair value of the Successor’s total assets prior to the consideration of liabilities and is intended to approximate the amount a willing buyer would pay for the assets immediately after a restructuring. The reorganization value, which was derived from the Successor’s enterprise value, was allocated to our individual assets based on their estimated fair values. The following table is a reconciliation of the enterprise value to the reorganization value of the Successor assets at the Effective Date (in thousands): Enterprise value $ 800,000 Plus: Cash and cash equivalents 20,140 Plus: Other working capital liabilities 63,817 Plus: Other long-term liabilities 97,470 Reorganization value of Successor assets $ 981,427 Legacy Amplify’s assets consist primarily of producing oil and natural gas properties. The fair values of proved and unproved oil and natural gas properties were estimated using valuation techniques consistent with the income approach, converting future cash flows to a single discounted amount. 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. These inputs require significant judgments and estimates by Legacy Amplify’s management at the time of the valuation and are the most sensitive and subject to change. The underlying commodity prices embedded in Legacy Amplify’s estimated cash flows are the product of a process that begins with NYMEX forward curve pricing and is adjusted for estimated location and quality differentials, as well as other factors as necessary that Legacy Amplify’s management believed would impact realizable prices. The fair value of support equipment and facilities were estimated using a cost approach, based on current replacement costs of the assets less depreciation based on the estimated economic useful lives of the assets and age of the assets. See below under the caption “Fresh Start Adjustments” for additional information regarding assumptions used in the valuation of Legacy Amplify’s various other significant assets and liabilities. Condensed Consolidated Balance Sheet The adjustments included in the following condensed consolidated balance sheet reflected the effect of the transactions contemplated by the Plan (reflected in the column “Reorganization Adjustments”) as well as fair value and other required accounting adjustments resulting from the adoption of fresh start accounting (reflected in the column “Fresh Start Adjustments”). The explanatory notes provide additional information with regard to the adjustments recorded, the methods used to determine the fair values and significant assumptions. As of May 4, 2017 Reorganization Fresh Start Predecessor Adjustments (1) Adjustments Successor (In thousands) ASSETS Current assets: Cash and cash equivalents $ 83,050 $ (62,910 ) (2) $ — $ 20,140 Restricted cash — 7,411 (3) — 7,411 Accounts receivable 33,560 — — 33,560 Short-term derivative instruments 51,329 — — 51,329 Prepaid expenses and other current assets 10,229 675 (4) — 10,904 Total current assets 178,168 (54,824 ) — 123,344 Property and equipment, net 1,551,500 — (894,164 ) (11) 657,336 Long-term derivative instruments 33,800 — — 33,800 Restricted investments 156,443 — — 156,443 Other long-term assets 1,929 8,575 (5) — 10,504 Total assets $ 1,921,840 $ (46,249 ) $ (894,164 ) $ 981,427 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 1,501 $ 1,389 (6) $ — $ 2,890 Revenues payable 22,747 — — 22,747 Accrued liabilities 36,954 2,939 (7) (1,713 ) (12) 38,180 Current portion of long-term debt 454,799 (454,799 ) (8) — — Total current liabilities 516,001 (450,471 ) (1,713 ) 63,817 Liabilities subject to compromise 1,162,437 (1,162,437 ) (9) — — Long-term debt — 430,000 (8) — 430,000 Asset retirement obligations 158,114 — (62,928 ) (13) 95,186 Deferred tax liabilities 2,206 — — 2,206 Other long-term liabilities 2,481 — (2,403 ) (12) 78 Total liabilities 1,841,239 (1,182,908 ) (67,044 ) 591,287 Commitments and contingencies (see Note 18) Stockholders'/partners' equity: Predecessor common units 80,601 (80,601 ) (10) — — Successor warrants — 4,788 (10) — 4,788 Successor common stock — 3 (10) — 3 Successor additional paid-in capital — 1,212,469 (10) (827,120 ) (14) 385,349 Total stockholders'/ partners' equity 80,601 1,136,659 (827,120 ) 390,140 Total liabilities and equity $ 1,921,840 $ (46,249 ) $ (894,164 ) $ 981,427 Reorganization Adjustments (1) Reflected amounts recorded as of the Effective Date for the implementation of the Plan, including among other items, settlement of the Predecessor’s liabilities subject to compromise, cancellation of the Predecessor’s equity, issuance of the Successor New Common Shares and the Warrants, repayment of certain of Predecessor’s debt and settlement with holders of the Notes. (2) Reflected the changes in cash and cash equivalents, including the following (in thousands): Payment on the Predecessor's revolving credit facility $ (24,799 ) Payment to holders of the Notes (1) (16,446 ) Payment of fees related to Emergence Credit Facility (8,575 ) Funding of the professional fees escrow account (7,411 ) Payment of professional fees (4,295 ) Other (1,384 ) Changes in cash and cash equivalents $ (62,910 ) (1) The total cash settlement to the holders of the Notes was approximately $24.6 million, of which $16.4 million was paid upon emergence and $8.2 million was paid post-emergence and is reflected in accrued liabilities in the above condensed consolidated balance sheet. (3) Reflected the transfer to restricted cash to fund the professional fees escrow account. (4) Reflected the pre-payment of certain professional fees. (5) Reflected the deferred financing costs related to the Emergence Credit Facility. (6) Reflected the recognition of payables for general unsecured claims. (7) Net increase in accrued liabilities reflected the following (in thousands): Recognition of liability for settlement with holders of the Notes $ 8,193 Payment of professional fees (4,295 ) Recognition of contribution from management (1,500 ) Recognition of settlement with Predecessor common unitholders 1,250 Other (709 ) Net increase in accrued liabilities due to reorganization items $ 2,939 (8) Reflected a repayment of $24.8 million on the Predecessor’s revolving credit facility and the reclassification of $430.0 million in borrowings under the Emergence Credit Facility to long-term debt. (9) Settlement of liabilities subject to compromise and the resulting net gain were determined as follows (in thousands): Accounts payable $ 1,389 Accrued interest payable 49,796 Debt 1,111,252 Total liabilities subject to compromise of Predecessor 1,162,437 Recognition of payables for general unsecured claims (1,389 ) Recognition of settlement with holders of the Notes (24,639 ) Issuance of common stock to holders of the Notes (377,645 ) Gain on settlement of liabilities subject to compromise $ 758,764 (10) Net increase in our stockholders’/partners’ equity reflects the following (in thousands): Issuance of common stock to holders of the Notes $ 377,645 Issuance of common stock to Predecessor common unitholders 7,707 Cancellation of the Predecessor's units issued and outstanding 80,601 Recognition on gain on settlement of liabilities subject to compromise 758,764 Recognition of issuance of common stock to Predecessor common unitholders (7,707 ) Recognition of issuance of warrants to Predecessor common unitholders (4,788 ) Recognition of contribution from management 1,500 Recognition of settlement with Predecessor common unitholders (1,250 ) Par value of common stock (3 ) Change in Successor additional paid-in capital 1,212,469 Issuance of warrants to Predecessor common unitholders 4,788 Par value of common stock 3 Predecessor units issued and outstanding (80,601 ) Net increase in capital accounts $ 1,136,659 Fresh Start Adjustments (11) Reflected a decrease of property and equipment, net based on the methodology discussed above and the elimination of accumulated depreciation, depletion and impairment. The fresh start adjustments to property and equipment, net are as follow: Predecessor Fresh Start Adjustments Successor (In thousands) Property and equipment at cost: Proved oil and natural gas properties $ 3,124,137 $ (2,615,076 ) $ 509,061 Support equipment and facilities 199,463 (101,883 ) 97,580 Unproved oil and natural gas properties — 44,688 44,688 Other 15,420 (9,413 ) 6,007 Property and equipment 3,339,020 (2,681,684 ) 657,336 Accumulated depreciation, depletion and impairment (1,787,520 ) 1,787,520 — Property and equipment, net $ 1,551,500 $ (894,164 ) $ 657,336 (12) Reflected the write-off of the deferred rent and loss on sublease liabilities. (13) Reflected a decrease of $62.9 million for asset retirement obligations. The fair value of asset retirement obligations was estimated using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation include estimates of: (i) plugging and abandonment costs per well based on existing regulatory requirements; (ii) remaining life per well; (iii) future inflation factors; and (iv) a credit-adjusted risk free rate. (14) Reflected the cumulative impact of our fresh start accounting adjustments discussed above. Reorganization Items, Net The Company has incurred significant costs associated with the reorganization. These costs, which are expensed as incurred, were expected to significantly affect the Company’s results of operations. Reorganization items, net represent costs and income directly associated with Legacy Amplify’s Chapter 11 proceedings since the Petition Date. The following table summarizes the components of reorganization items, net included in the accompanying Statements of Consolidated Operations (in thousands): Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 Gain on settlement of liabilities subject to compromise $ — $ — $ — $ 758,764 Fresh start valuation adjustments — — — (827,120 ) Professional fees (430 ) (864 ) (724 ) (19,824 ) Other (627 ) (1,283 ) (395 ) (594 ) Reorganization items, net $ (1,057 ) $ (2,147 ) $ (1,119 ) $ (88,774 )

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Fresh Start Accounting Upon the Effective Date, Legacy Amplify adopted fresh start accounting as required by GAAP. We met the requirements of fresh start accounting, which include: (i) the holders of the Predecessor’s voting common units immediately prior to the Effective Date received less than 50% of the voting shares of Legacy Amplify and (ii) the reorganization value of our assets immediately prior to the Effective Date was less than the post-petition liabilities and allowed claims. Fresh start accounting involved a comprehensive valuation process in which we determined the fair value of all of Legacy Amplify’s assets and liabilities on the Effective Date. See Note 3 for additional information. 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. Additionally, management believes that any credit risk imposed by a concentration in the oil and natural gas industry is mitigated by the creditworthiness of its customer base. 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 and $1.2 million as an allowance for doubtful accounts at December 31, 2019 and 2018, respectively. 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. 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, 2019 and 2018. 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. 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 (by volume) at December 31, 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 10 and Note 18 for additional information. Debt Issuance Costs These costs are recorded 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, 2019 and 2018 and the period from May 5, 2017 through December 31, 2017 was approximately $1.2 million, $2.5 million and $2.1 million, respectively. No amortization of deferred financing cost was recorded for the period from January 1, 2017 through May 4, 2017 as the unamortized amount of deferred financing cost at December 31, 2016 was written off due to (i) the uncertainty regarding the Predecessor’s ability to cure the default that existed at December 31, 2016, (ii) the Predecessor’s inability to comply with certain financial covenants contained in our Predecessor’s revolving credit facility and (iii) the default or cross default provisions in the indentures governing the 2021 Senior Notes and 2022 Senior Notes. 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. No impairment expense related to our proved properties was recorded for the years ended December 31, 2019 and 2018, the period from May 5, 2017 through December 31, 2017 or the period from January 1, 2017 through May 4, 2017. 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 $2.2 million in impairment expense for certain unproved leasehold costs for the year ended December 31, 2019. We did not record any impairments related to unproved properties for the year ended December 31, 2018, the period from May 5, 2017 through December 31, 2017 or the period from January 1, 2017 through May 4, 2017. 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 9 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, 2019 and 2018. In May 2014, the FASB issued guidance regarding the accounting for revenue from contracts with customers. This standard includes a five-step revenue recognition model to depict the transfer of goods or services to customers in an amount that reflects the consideration we expect to be entitled to in exchange for those goods or services. Among other things, the standard also eliminates industry-specific revenue guidance and requires enhanced disclosures related to the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The standard was effective for the Company starting January 1, 2018, and the Company adopted the standard using a modified retrospective approach. See Note 5 for additional information. The following individual customers each accounted for 10% or more of total reported revenues for the period indicated: Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 Major customers: Phillips 66 27% 27% 23% 19% Sinclair Oil & Gas Company 21% 21% 19% 20% CIMA Energy n/a 10% 11% n/a BP America Production Company 13% n/a 10% 10% 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. For the years ended December 31, 2019 and 2018 and the period from May 5, 2017 through December 31, 2017 we had $0.2 million, $0.5 million and $0.4 million in capitalized interest, respectively. No capitalized interest recorded for the period from January 1, 2017 through May 4, 2017. Income Tax We are a corporation subject to federal and certain state income taxes. Our Predecessor was organized as a pass-through entity for federal and most state income tax purposes. Certain of our consolidated subsidiaries were taxed as corporations for federal and state income tax purposes. We are also subject to the Texas margin tax for activity in the state of Texas. 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 interest and penalties accrued to unrecognized tax benefits in other income (expense) in our Statement of Consolidated Operations. 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. 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. On December 22, 2017, the U.S. government enacted comprehensive tax legislation commonly referred to as the Tax Cuts and Jobs Act (the “Tax Act”). The provisions of the Tax Act that impact us include, but are not limited to, (1) reducing the U.S. federal corporate tax rate from 35% to 21%; (2) elimination of the corporate alternative minimum tax (AMT); (3) temporary bonus depreciation that will allow for full expensing of qualified property, and (4) limitations on net operating losses (NOLs) generated after December 31, 2017, to 80 percent of taxable income. Earnings Per Share/Unit Basic and diluted earnings per share/unit (“EPS” or “EPU”) is determined by dividing net income or loss available to the common stockholders/limited partners by the weighted average number of outstanding shares/units 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. Net income or loss available to the Predecessor limited partners was determined by applying the two-class method. The two-class method of computing the Predecessor’s EPU was an earnings allocation formula that determined EPU based on distributions declared. The amount of net income or loss used in the determination of EPU was reduced (or increased) by the amount of available cash that had been distributed to the Predecessor’s limited partners for that corresponding period. The remaining undistributed earnings or excess distributions over earnings were allocated to the Predecessor’s limited partners in accordance with the contractual terms of the Predecessor’s partnership agreement. The total earnings allocated to the Predecessor’s limited partners was determined by adding together the amount allocated for distributions declared and the amount allocated for the undistributed earnings or excess distributions over earnings. Basic and diluted EPU are equivalent, as all restricted common units and subordinated units participated in distributions. See Note 13 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 14 for further information. Recently Adopted Accounting Pronouncements Lease Recognition In February 2016, the Financial Accounting Standards Board (“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 15 for additional information regarding the adoption of the leases standard. New Accounting Pronouncements 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 impact of this guidance is not expected to have a material impact on the Company. Financial Instruments — Credit Losses . In May 2019 the FASB issued an accounting standards 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. The fair value option election does not apply to held-to-maturity debt securities. The new guidance is effective for annual periods beginning after December 15, 2019, and interim periods within those annual periods. The Company is currently evaluating the impact of this guidance and does not expect the guidance to have a material impact on the Company’s financial statements. 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 December 15, 2020. The Company is currently evaluating the impact of this guidance and does not expect the guidance to have a material impact on the Company's 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, 2019
Revenue From Contract With Customer [Abstract]
Revenue	Revenue from contracts with customers As discussed in Note 4, the Company adopted Accounting Standard Update (ASU) No. 2014-09, revenue from contracts with customers (ASC 606), on January 1, 2018 using the modified retrospective method of adoption. Adoption of the ASU did not require an adjustment to the opening balance of equity and did not materially change the Company's amount and timing of revenues. The Company applied the ASU only to contracts that were not completed as of January 1, 2018. The reclassification of certain fees between oil and natural gas sales and gathering, processing and transportation is the result of the Company’s assessment of the point in time at which its performance obligations under its commodity sales contracts are satisfied and control of the commodity is transferred to the customer. 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, 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, 2019 2018 (in thousands) Revenues Oil $ 192,944 $ 209,066 NGLs 22,347 42,463 Natural gas 59,316 88,311 Oil and natural gas sales $ 274,607 $ 339,840 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 $31.9 million at December 31, 2019 and $25.0 million at December 31, 2018. 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, 2019
Business Combinations [Abstract]
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 and our Predecessor 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): Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 $ 17,305 $ 205 $ 609 $ — Business Combination Acquisitions qualifying as a business combination are accounted for under the acquisition method of accounting, which requires, among other items, that assets acquired, and liabilities assumed be recognized on the condensed consolidated balance sheet at their fair values as of the acquisition date. 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 has 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 Condensed Consolidated Statements of Operations revenues of $31.8 million, direct operating expense of $34.0 million and other expenses of $0.4 million for our Oklahoma properties for the period after the Merger closed. 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 and 2018, respectively, 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 conform the classification of expenses in Midstates statements of operations to our classification for similar expenses and 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 periods presented, nor is it necessarily indicative of future results. For the Year Ended December 31, 2019 2018 (Unaudited) (In thousands, except per unit amounts) Revenues $ 336,326 $ 545,226 Net income (loss) (22,926 ) 146,845 Earnings per share: Basic $ (0.78 ) $ 3.18 Diluted $ (0.78 ) $ 3.18 2018 Acquisitions & Divestitures On May 30, 2018, we closed a transaction to divest certain of our non-core assets located in South Texas (the “South Texas Divestiture”) for total proceeds of approximately $17.1 million, including post-closing adjustments, which includes $18.6 million in cash, $0.5 million in accounts payable and $0.9 million paid in legal and advisor expenses. We recorded a loss on sale of properties of approximately $3.6 million for the year ended December 31, 2018, in “(gain) loss on sale of properties” in the accompanying Statements of Consolidated Operations. The net proceeds from the sale were used to reduce outstanding borrowings under our Emergence Credit Facility (as defined below). This disposition did not qualify as a discontinued operation. There were no material acquisitions for the year ended December 31, 2018. 2017 Acquisitions & Divestitures There were no material acquisitions or divestitures the period from January 1, 2017 through May 4, 2017 or for the period from May 5, 2017 through December 31, 2017.

Fair Value Measurements of Fina

Fair Value Measurements of Financial Instruments	12 Months Ended
	Dec. 31, 2019
Fair Value Disclosures [Abstract]
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, 2019 and 2018, 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, 2019 and December 31, 2018. 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 11 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, 2019 and December 31, 2018 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, 2019 and December 31, 2018 for each of the fair value hierarchy levels: 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 Fair Value Measurements at December 31, 2018 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 $ — $ 25,515 $ — $ 25,515 Liabilities: Commodity derivatives $ — $ 4,372 $ — $ 4,372 See Note 8 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 9 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 factors used to determine fair value include, but are not limited to, estimates of proved 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. (i) We recognized a $2.2 million impairment expense on certain unproved leasehold costs in Oklahoma for the year ended December 31, 2019 due to changes in development plans in the areas of Alfalfa, Major and Woods counties in Oklahoma. (ii) No impairment expense was recognized for the year ended December 31, 2018. (iii) No impairment expense were recognized for the period from May 5, 2017 through December 31, 2017 or the period from January 1, 2017 through May 4, 2017.

Risk Management and Derivative

Risk Management and Derivative Instruments	12 Months Ended
	Dec. 31, 2019
Derivative Instruments And Hedging Activities Disclosure [Abstract]
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, 2019, 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 $12.6 million against amounts outstanding under our Revolving Credit Facility at December 31, 2019. See Note 11 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 January 2017, in connection with our restructuring efforts, we monetized $94.1 million in commodity hedges and used a portion of the proceeds to reduce the amounts outstanding under our Predecessor’s revolving credit facility and kept the remaining portion as cash on hand for general partnership purposes. 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, 2019, the Company had the following open commodity positions: 2020 2021 2022 Natural Gas Derivative Contracts: Fixed price swap contracts: Average monthly volume (MMBtu) 600,000 487,500 300,000 Weighted-average fixed price $ 2.53 $ 2.48 $ 2.46 Collar contracts: Two-way collars Average monthly volume (MMBtu) 520,000 162,500 — Weighted-average floor price $ 2.64 $ 2.58 $ — Weighted-average ceiling price $ 2.96 $ 2.84 $ — Three-way collars Average monthly volume (MMBtu) 76,000 — — Weighted-average ceiling price $ 3.45 $ — $ — Weighted-average floor price $ 2.65 $ — $ — Weighted-average sub-floor price $ 2.15 $ — $ — Natural Gas Basis Swaps: PEPL basis swaps: Average monthly volume (MMBtu) 600,000 500,000 — Weighted-average spread $ (0.46 ) $ (0.40 ) $ — Crude Oil Derivative Contracts: Fixed price swap contracts: Average monthly volume (Bbls) 213,050 116,250 30,000 Weighted-average fixed price $ 57.28 $ 56.05 $ 55.32 Collar contracts: Two-way collars Average monthly volume (Bbls) 14,300 — — Weighted-average floor price $ 55.00 $ — $ — Weighted-average ceiling price $ 62.10 $ — $ — Three-way collars Average monthly volume (Bbls) 30,500 — — Weighted-average ceiling price $ 65.75 $ — $ — Weighted-average floor price $ 50.00 $ — $ — Weighted-average sub-floor price $ 40.00 $ — $ — NGL Derivative Contracts: Fixed price swap contracts: Average monthly volume (Bbls) 65,425 22,800 — Weighted-average fixed price $ 25.20 $ 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, 2019, we had the following interest rate swaps open positions: 2020 2021 2022 Average Monthly Notional (in thousands) $ 125,000 $ 125,000 $ 75,000 Weighted-average fixed rate 1.612 % 1.612 % 1.281 % Floating rate 1 Month LIBOR 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, 2019 and 2018. 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 New Credit Agreement. Asset Derivatives Liability Derivatives Asset Derivatives Liability Derivatives December 31, December 31, December 31, December 31, Type Balance Sheet Location 2019 2019 2018 2018 (In thousands) Commodity contracts Short-term derivative instruments $ 11,518 $ 5,887 $ 21,217 $ 2,543 Interest rate swaps Short-term derivative instruments 248 253 — — Gross fair value 11,766 6,140 21,217 2,543 Netting arrangements (5,887 ) (5,887 ) (2,404 ) (2,404 ) Net recorded fair value Short-term derivative instruments $ 5,879 $ 253 $ 18,813 $ 139 Commodity contracts Long-term derivative instruments $ 6,990 $ 973 $ 4,298 $ 1,829 Interest rate swaps Long-term derivative instruments 347 305 — — Gross fair value 7,337 1,278 4,298 1,829 Netting arrangements (973 ) (973 ) (1,829 ) (1,829 ) Net recorded fair value Long-term derivative instruments $ 6,364 $ 305 $ 2,469 $ — (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): Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 Statements of December 31, December 31, through through Operations Location 2019 2018 December 31, 2017 May 4, 2017 (Gain) loss on commodity derivatives $ 6,700 $ (8,155 ) $ 31,609 $ (23,076 ) Interest expense, net (224 ) — — —

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2019
Asset Retirement Obligation Disclosure [Abstract]
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, 2019 and 2018, the period from May 5, 2017 through December 31, 2017 and the period from January 1, 2017 through May 4, 2017 (in thousands): Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 Asset retirement obligations at beginning of period $ 76,344 $ 100,173 $ 96,127 $ 155,702 Liabilities added from acquisition or drilling (1) 9,497 89 191 6 Liabilities removed upon sale of wells — (15,702 ) — — Liabilities settled (259 ) (767 ) (633 ) (164 ) Accretion expense 5,559 5,711 4,384 3,407 Revision of estimates (2) (52 ) (13,160 ) 104 104 Asset retirement obligation at end of period 91,089 76,344 100,173 159,055 Fresh start adjustment (3) — — — (62,928 ) Less: Current Portion 623 477 713 941 Asset retirement obligations - long-term portion $ 90,466 $ 75,867 $ 99,460 $ 95,186 (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. (2) The decrease in revision of estimates for the year ended December 31, 2018 is primarily due to receiving new cost estimates from third parties regarding the estimated plugging and abandonment costs. (3) As a result of the application of fresh start accounting, the Successor recorded its asset retirement obligation at fair value as of the Effective Date.

Restricted Investments

Restricted Investments	12 Months Ended
	Dec. 31, 2019
Investments Debt And Equity Securities [Abstract]
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, December 31, 2019 2018 (In thousands) BOEM platform abandonment (See Note 18) $ 313 $ 90,162 SPBPC Collateral: Contractual pipeline and surface facilities abandonment 4,309 4,305 Restricted investments $ 4,622 $ 94,467 On June 24, 2019, the Company received the release of $90.0 million from the Beta Decommissioning Trust Account. See Note 18 for additional information related to the Beta Decommissioning Trust Account.

Debt

Debt	12 Months Ended
	Dec. 31, 2019
Debt Disclosure [Abstract]
Debt	Our consolidated debt obligations consisted of the following at the dates indicated: December 31, December 31, 2019 2018 (In thousands) Revolving Credit Facility (1) $ 285,000 $ 294,000 Long-term debt $ 285,000 $ 294,000 (1) The carrying amount of our Revolving Credit Facility and Emergence Credit Facility approximates fair value because the interest rates are variable and reflective of market rates. Revolving Credit Facility Amplify Energy Operating LLC, our wholly owned subsidiary (“OLLC”), is a party to a reserve-based revolving credit facility (the “Revolving Credit Facility”), subject to a borrowing base of $450.0 million as of December 31, 2019, which is guaranteed by us and all of our current subsidiaries. The Revolving Credit Facility matures on November 2, 2023 and has a semiannual borrowing base redetermination. The terms and conditions under the Revolving Credit Facility include (but are not limited to) the following: • at OLLC’s option, borrowings under the New 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 interest period plus 100 basis points per annum. The applicable margin for base rate loans ranges from 100 to 200 basis points, and the applicable margin for LIBOR loans and LIBOR Market loans ranges from 200 to 300 basis points, in each case depending on the percentage of the borrowing base utilized; • 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 New 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 New Credit Agreement are secured by a pledge and security interest of 100% of the equity interests held by the Company in Amplify Acquisitionco Inc. (“Acquisitionco”); • certain financial covenants, including the maintenance of (i) • 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. On June 24, 2019, as discussed in Note 18, the Company received the release of $90.0 million from the Beta Decommissioning Trust Account and used the proceeds to reduce amounts outstanding under our Revolving Credit Facility. Borrowing Base Redetermination 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. 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 were decreased from $530.0 million to $450.0 million, with the next such redetermination scheduled for spring 2020. Joinder Agreement Amendment 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. 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. 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. Letter Agreement On December 21, 2018, Legacy Amplify entered into a letter agreement relating to the New Credit Agreement (the “Letter Agreement”). Pursuant to the Letter Agreement, the parties to the New Credit Agreement agreed, among other things, to: • extend the date by which OLLC was required to show compliance with certain minimum hedging requirements set forth in the New Credit Agreement from December 31, 2018 to February 28, 2019; and • subject to certain conditions, waive the requirement that OLLC deliver to the Agent within 60 days after the closing date of the New Credit Agreement control agreements with respect to certain deposit accounts held or maintained by each Loan Party (as defined in the New Credit Agreement) on the closing date of the New Credit Agreement. Emergence Credit Facility On May 4, 2017, OLLC, as borrower, entered into the Amended and Restated Credit Agreement (the “Emergence Credit Agreement”) among Acquisitionco, as parent guarantor, the lenders from time to time party thereto and Wells Fargo Bank, National Association, as administrative agent. Pursuant to the Emergence Credit Agreement the lenders party thereto agreed to provide OLLC with the Emergence Credit Facility (the loans thereunder, the “Loans”). On November 2, 2018, in connection with our entrance into the Revolving Credit Facility, the Emergence Credit Facility was terminated and repaid in full. At December 31, 2018, $3.0 million of deferred financing costs related to the Emergence Credit Facility was written off resulting in a loss on extinguishment of debt. Predecessor’s Revolving Credit Facility Our Predecessor was a party to a $2.0 billion revolving credit facility, which was guaranteed by us and all of our current and future subsidiaries (other than certain immaterial subsidiaries). On the Effective Date, the holders of claims under the Predecessor’s revolving credit facility received a full recovery, which included a $24.8 million pay down and their pro rata share of the Emergence Credit Facility. See Note 2 for additional information. Weighted-Average Interest Rates The following table presents the weighted-average interest rates paid on variable-rate debt obligations for the periods presented: Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 Revolving Credit Facility 4.76% 4.96% n/a n/a Emergence Credit Facility n/a 5.75% 5.08% n/a Predecessor's revolving credit facility n/a n/a n/a 4.18% Senior Notes On April 17, 2013, May 23, 2013 and October 10, 2013, our Predecessor and Finance Corp. (collectively, the “Issuers”) issued $300.0 million, $100.0 million and $300.0 million, respectively, of the 2021 Senior Notes. The 2021 Senior Notes were fully and unconditionally guaranteed (subject to customary release provisions) on a joint and several basis by the Guarantor Subsidiaries and by certain subsidiaries of the Predecessor. The 2021 Senior Notes would have matured on May 1, 2021 with interest accruing at a rate of 7.625% per annum and were payable semi-annually in arrears on May 1 and November 1 of each year. The 2021 Senior Notes were governed by an indenture and were subject to optional redemption at prices specified in the indenture plus accrued and unpaid interest, if any. On July 17, 2014, the Issuers completed a private placement of $500.0 million aggregate principal amount of the 2022 Senior Notes. The 2022 Senior Notes were issued at 98.485% of par and were fully and unconditionally guaranteed (subject to customary release provisions) on a joint and several basis by the Guarantor Subsidiaries and by certain subsidiaries of the Predecessor. The 2022 Senior Notes would have matured on August 1, 2022 with interest accruing at 6.875% per annum and were payable semi-annually in arrears on February 1 and August 1 of each year. The 2022 Senior Notes were governed by an indenture and were subject to optional redemption at prices specified in the indenture plus accrued and unpaid interest, if any. The Company’s voluntary petitions as described in Note 2 constituted an event of default that accelerated the obligations under the Notes. For the period from January 17, 2017 through May 4, 2017 our contractual interest that was not recorded on the Notes was approximately $24.2 million. On the Effective Date, the Notes were cancelled and the Predecessor’s liability thereunder discharged, and the holders of the Notes received their pro rata share of the New Common Shares. Additionally, the holders of the Notes received their pro rata share of a $24.6 million cash distribution. Letters of credit At December 31, 2019, we had $1.7 million letters of credit outstanding, all related to operations at our Wyoming properties. Unamortized Deferred Financing Costs Unamortized deferred financing costs associated with our Revolving Credit Facility was $4.7 million at December 31, 2019. 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. On November 2, 2018, in connection with our entrance into the Revolving Credit Facility, the Emergence Credit Facility was terminated and repaid in full. The remaining deferred financing costs of $3.0 million was written off resulting in a loss on extinguishment of debt.

Equity (Deficit)

Equity (Deficit)	12 Months Ended
	Dec. 31, 2019
Equity [Abstract]
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, 2016 (Predecessor) 83,827,920 Restricted common units issued — Restricted common units forfeited (12,952 ) Restricted common units repurchased (1) (14,681 ) Balance, May 4, 2017 (Predecessor) 83,800,287 Cancellation of Predecessor common units (83,800,287 ) Balance, May 4, 2017 (Predecessor) — Issuance of Successor common stock 25,000,000 Balance, May 5, 2017 (Successor) 25,000,000 Issuance of Successor common stock — Balance, December 31, 2017 (Successor) 25,000,000 Issuance of common stock — Restricted stock units vested 163,700 Repurchase of common shares (65,152 ) Restricted common stock repurchased and retired under tender offer (2,916,667 ) Balance, December 31, 2018 (Successor) 22,181,881 Issuance of common stock — Restricted stock units vested 412,938 Repurchase of common shares (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 (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 (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 (1) Restricted common units were generally net-settled by our Predecessor unitholders to cover the required withholding tax upon vesting. The Predecessor unitholders surrendered units with value equivalent to the employees’ minimum statutory obligation for the applicable income and other employment taxes. Total payments remitted for the employees’ tax obligations to the appropriate taxing authorities were less than approximately $0.1 million for the period from January 1, 2017 through May 4, 2017. These net-settlements had the effect of unit repurchases by the Company as they reduced the number of units that would have otherwise been outstanding as a result of the vesting and did not represent an expense to the Company. Emergence from Legacy Amplify Bankruptcy In accordance with the Plan, on the Effective Date: • Legacy Amplify issued 25,000,000 New Common Shares and Warrants to purchase up to 2,173,913 shares of its common stock; • the Predecessor common units were cancelled; and • each Predecessor common unitholder received its pro rata share of: (i) 2% of the New Common Shares, (ii) the Warrants, and (iii) cash in an aggregate amount of approximately $1.3 million. On the Effective Date, there were 25,000,000 New Common Shares issued and outstanding. Treasury Stock As of August 5, 2019, Midstates had 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, 2019. Warrants On the Effective Date, 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 MIP), 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. As of August 5, 2019, Midstates had 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 “ Midstates Warrants”). The Midstates Warrants expire on April 21, 2020. As a result of the Merger, the value of the outstanding Midstates Warrants was adjusted downward based on the low stock price and estimated fair value as of the Merger date. See Note 6 for additional information regarding the purchase price allocation of the Merger. Share Repurchase Program 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. 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. Cash Dividend Payment 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. The amount of future dividends is subject to discretionary approval by the board of directors. Tender Offer On November 19, 2018, Legacy Amplify’s board of directors announced the commencement of a tender offer to purchase 2,916,667 shares of Legacy Amplify’s common stock. On December 19, 2018, upon the terms and subject to the conditions described in the Offer to Purchase dated November 19, 2018, as amended, Legacy Amplify repurchased an aggregate of 2,916,667 shares of Legacy Amplify common stock at a price of $12.00 per share, for a total cost of approximately $35.0 million (excluding fees and expenses relating to the offer).

Earnings per Share_Unit

Earnings per Share/Unit	12 Months Ended
	Dec. 31, 2019
Earnings Per Share [Abstract]
Earnings per Share/Unit	The following sets forth the calculation of earnings (loss) per share/unit, or EPS/EPU, for the periods indicated (in thousands, except per unit amounts): Successor Predecessor Period from For the For the May 5, 2017 Period from Year Ended Year Ended through January 1, December 31, December 31, December 31, 2017 through 2019 2018 2017 May 4, 2017 Net income (loss) attributable to Successor/Predecessor $ (35,197 ) $ 54,609 $ 1,286 $ (90,955 ) Less: Net income (loss) allocated to participating restricted stockholders — 2,426 35 — Basic and diluted earnings available to common stockholders/limited partners $ (35,197 ) $ 52,183 $ 1,251 $ (90,955 ) Common shares/units: Common shares/units outstanding — basic 29,301 24,959 25,000 83,807 Dilutive effect of potential common shares — — — — Common shares/units outstanding — diluted 29,301 24,959 25,000 83,807 Net earnings per share/unit: Basic $ (1.20 ) $ 2.09 $ 0.05 $ (1.09 ) Diluted $ (1.20 ) $ 2.09 $ 0.05 $ (1.09 ) Antidilutive stock options (1) — — 517 — Antidilutive warrants (2) 9,154 2,174 2,174 — (1) Amount represents options to purchase common stock that are excluded from the diluted net earnings per share calculations because of their antidilutive effect. (2) 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, 2019
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
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, 2019, 626,404 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, 2019, 2,004,934 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 $0.8 million at December 31, 2019. We expect to recognize the unrecognized compensation cost for these awards over a weighted-average period of 1.8 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 May 5, 2017 (Successor) 614,754 $ 13.77 Granted (2) 173,070 $ 12.87 Forfeited (105,032 ) $ 13.77 Vested — $ — TSUs outstanding at December 31, 2017 (Successor) 682,792 $ 13.54 Granted (3) 437,000 $ 10.51 Forfeited (4) (363,513 ) $ 13.55 Vested (158,255 ) $ 13.44 TSUs outstanding at December 31, 2018 598,024 $ 11.35 Granted (5) 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 (6) 0.933 Converted TSUs 394,245 TSUs outstanding at August 6, 2019 (7) 394,245 $ 5.12 Granted (8) 17,500 $ 6.14 Forfeited (38,652 ) $ 5.12 Vested (81,723 ) $ 5.12 TSUs outstanding at December 31, 2019 291,370 $ 5.18 (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 May 5, 2017 through December 31, 2017 was $2.2 million based on a grant date market price ranging from $10.00 to $13.77 per share. (3) The aggregate grant date fair value of TSUs issued for the year ended December 31, 2018 was $4.6 million based on a grant date market price ranging from $9.30 to $11.00 per share. (4) Certain Legacy Amplify departing executives forfeited 298,354 TSUs during the year ended December 31, 2018, in connection with their separation and retirement agreements. (5) 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. (6) The merger ratio used to convert Legacy Amplify TSUs into newly issued TSUs. ( 7 ) 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. ( 8 ) 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. 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, 2019. 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, 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 Share price targets $ 12.50 $ 15.00 $ 17.50 Risk-free interest rate: Awards Issued on May 14, 2018 2.68 % 2.68 % 2.68 % Awards Issued on July 1, 2018 2.61 % 2.61 % 2.61 % Awards Issued on August 1, 2018 2.76 % 2.76 % 2.76 % Awards Issued on October 1, 2018 2.88 % 2.88 % 2.88 % Awards Issued on November 1, 2018 2.89 % 2.89 % 2.89 % Dividend yield — — — Expected volatility: Awards Issued on May 14, 2018 50.0 % 50.0 % 50.0 % Awards Issued on July 1, 2018 50.0 % 50.0 % 50.0 % Awards Issued on August 1, 2018 55.0 % 55.0 % 55.0 % Awards Issued on October 1, 2018 53.0 % 53.0 % 53.0 % Awards Issued on November 1, 2018 54.0 % 54.0 % 54.0 % Calculated fair value per PSU: Awards Issued on May 14, 2018 $ 9.71 $ 8.52 $ 7.48 Awards Issued on July 1, 2018 $ 9.87 $ 8.72 $ 7.68 Awards Issued on August 1, 2018 $ 9.79 $ 8.66 $ 7.65 Awards Issued on October 1, 2018 $ 8.54 $ 7.57 $ 6.66 Awards Issued on November 1, 2018 $ 7.65 $ 6.72 $ 5.88 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, 2017 (Successor) — $ — Granted (2) 395,500 $ 8.14 Forfeited (2,000 ) $ 7.59 Vested — $ — PSUs outstanding at December 31, 2018 393,500 $ 8.14 Granted (3) 17,750 $ 4.06 Forfeited (22,750 ) $ 7.59 Vested — $ — PSUs outstanding at August 5, 2019 388,500 $ 7.98 Ratio to convert PSUs (4) 0.933 Converted PSUs 362,471 PSUs outstanding on August 6, 2019 (5) 362,471 $ 2.11 Granted (6) 17,500 $ 2.87 Forfeited (74,078 ) $ 2.11 Vested — $ — PSUs outstanding at December 31, 2019 305,893 $ 2.15 (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 year ended December 31, 2018 was $3.2 million based on a calculated fair value price ranging from $5.88 to $9.87 per share. (3) 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. (4) The merger ratio used to convert Legacy Amplify PSUs into newly issued Company PSUs. ( 5 ) 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. ( 6 ) 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. Emergence Awards On May 4, 2017, the Legacy Amplify board of directors approved grants of restricted stock unit awards and restricted stock options (collectively the “Emergence Awards”) to certain of Legacy Amplify employees, including Legacy Amplify’s executive officers. Emergence Awards generally vest annually in three equal installments on each of the first three anniversaries of the Effective Date, subject to the grantee’s continued employment through each such vesting date. However, upon a grantee’s termination of employment by the Company without Cause, or due to death or Disability, or the grantee resigns from Service for Good Reason (as such terms are defined in the respective Emergence Award agreement), all unvested restricted stock unit awards shall fully vest upon such termination or resignation date. Moreover, (i) upon a grantee’s termination of employment by the Company without Cause, or due to death or Disability, or the grantee resigns from Service for Good Reason (as such terms are defined in the respective Emergence Award agreement), any portion of the then unvested restricted stock options that would have vested had the grantee continued his or her Service during the 12 months following such termination or resignation shall vest on such termination or resignation date and (ii) upon a grantee’s termination of employment by the Company without Cause or the grantee resigns from Service for Good Reason, in each case, following a Change of Control, all unvested restricted stock options shall fully vest as of such termination or resignation date. Notwithstanding the foregoing, the vesting of such Emergence Awards may be subject to and limited by employment-related agreements by and between the Company and grantee. Restricted Stock Options Restricted stock options 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 fair value for restricted stock options granted during the year ended December 31, 2017 had been estimated using Black-Scholes option pricing model using the following assumptions: Awards Issued in Successor Period Risk-free interest rate 2.06 % Dividend yield — Expected life (in years) 6.0 Expected volatility 50.0 % Strike Price $ 21.58 Calculated fair value per stock option $ 5.01 The following table summarizes information regarding the restricted stock option awards granted under the Legacy Amplify MIP for the period presented: Weighted- Average Grant Number of Date Fair Value Options per Option (1) Restricted stock options outstanding at May 5, 2017 (Successor) 614,754 $ 5.01 Granted 1,876 $ 5.01 Forfeited (99,232 ) $ 5.01 Vested — $ — Restricted stock options outstanding at December 31, 2017 (Successor) 517,398 $ 5.01 Granted — $ — Forfeited (2) (161,243 ) $ 5.01 Vested (356,155 ) $ 5.01 Restricted stock options outstanding at December 31, 2018 — $ — (1) Determined by dividing the aggregate grant date fair value of awards by the number of awards issued. (2) In connection with certain grants awarded in 2018 pursuant to the Legacy Amplify MIP, all remaining unvested restricted stock options were forfeited. Stock Option Modification On April 27, 2018, in connection with the separation and retirement of certain Legacy Amplify executives, the board of directors of Legacy Amplify approved the acceleration of the vesting schedule for 298,354 unvested restricted stock option awards with an exercisable period of two years that otherwise would have been forfeited upon an involuntary termination. The acceleration of the restricted stock options vesting schedule represented an improbable to probable modification. The grant-date fair value compensation cost of approximately $0.5 million was reversed and the modified-date grant fair value compensation cost of $0.3 million was recognized during the year ended December 31, 2018. The modified-date grant fair value was estimated at December 31, 2018 using the Black-Scholes option pricing model using the following assumptions: Awards Issued in Successor Period Risk-free interest rate 2.49 % Dividend yield — Expected life (in years) 2.0 Expected volatility 50.0 % Strike Price $ 21.58 Calculated fair value per stock option $ 0.85 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, 2019, 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, 2019. We expect to recognize the unrecognized compensation cost for these awards over a weighted-average period of 2.2 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 May 5, 2017 (Successor) — $ — Granted (2) 16,341 $ 13.77 Forfeited — $ — Vested — $ — Board RSUs outstanding at December 31, 2017 (Successor) 16,341 $ 13.77 Granted (3) 28,708 $ 10.45 Forfeited — $ — Vested (5,445 ) $ 13.77 Board RSUs outstanding at December 31, 2018 39,604 $ 11.36 Granted (4) 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 (5) 0.933 Converted Board RSUs 30,616 Board RSUs outstanding on August 6, 2019 (6) 30,616 $ 5.12 Granted — $ — Forfeited — $ — Vested (14,459 ) $ 5.12 Board RSUs outstanding at December 31, 2019 16,157 $ 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 in 2017 was $0.2 million based on grant date market price of $13.77 per share. (3) The aggregate grant date fair value of Board RSUs issued in 2018 was $0.3 million based on a grant date market price of $10.45 per share. (4) 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. (5) The merger ratio used to convert Legacy Amplify Board RSUs into newly issued Company Board RSUs. (6) 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. Predecessor Restricted Common Units In December 2011, the board of directors of our Predecessor’s general partner adopted the Memorial Production Partners GP LLC Long-Term Incentive Plan (“LTIP”) for employees, officers, consultants and directors of the general partner and any of its affiliates, who perform services for the Predecessor. The LTIP authorized the grant of restricted units, phantom units, unit options, unit appreciation rights, distribution equivalent rights (“DERs”), other unit-based awards and unit awards. The LTIP initially limited the number of common units that could be delivered pursuant to awards under the plan to 2,142,221 common units. Common units that were cancelled, forfeited or withheld to satisfy exercise prices or tax withholding obligations would have been available for delivery pursuant to other awards. The LTIP was administered by the board of directors of our Predecessor’s general partner or a committee thereof. The restricted common units awarded were subject to restrictions on transferability, customary forfeiture provisions and typically graded vesting provisions in which one-third of each award vested on the first, second, and third anniversaries of the date of grant. Award recipients had all the rights of a Predecessor with respect to the restricted common units, including the right to receive distributions thereon if and when distributions were made by the Predecessor to its unitholders. The term “restricted common unit” represented a time-vested unit. Such awards were non-vested until the required service period expired. The restricted common units granted were accounted for as equity-classified awards. The grant-date fair value was recognized as compensation cost on a straight-line basis over the requisite service period and forfeitures accounted for as they occur. The fair value of the restricted unit awards granted to the independent directors of our Predecessor’s general partner was also recognized as compensation cost on a straight-line basis over the requisite service period. Compensation costs were recorded as direct general and administrative expenses. On May 1, 2017, the Company effectively cancelled the unvested restricted common unit awards under the LTIP and recorded $2.3 million in compensation expense. The following table summarizes information regarding restricted common unit awards for the periods presented: Weighted- Average Grant Number of Date Fair Value Units per Unit (1) Restricted common units outstanding at December 31, 2016 (Predecessor) 432,160 $ 15.00 Granted — $ — Forfeited (12,952 ) $ 9.51 Vested (43,045 ) $ 10.40 Cancelled (376,163 ) $ 15.72 Restricted common units outstanding at May 4, 2017 (Predecessor) — $ — (1) Determined by dividing the aggregate grant date fair value of awards by the number of awards issued. Predecessor Phantom Units The following table summarizes information regarding the Predecessor’s phantom unit awards granted under the LTIP: Number of Units Phantom units outstanding at December 31, 2016 (Predecessor) 5,980,693 Granted — Forfeited (132,347 ) Vested (155,601 ) Phantom units outstanding at May 4, 2017 (Predecessor) 5,692,745 Cancelled (5,692,745 ) Phantom units outstanding at December 31, 2017 (Successor) — Phantom units issued to non-employee directors of our Predecessor in January 2016 vested on the first anniversary of the date of grant and were settled in cash for less than $0.1 million. Phantom units issued to certain employees in June 2016 were scheduled to vest in substantially equal one-third increments on the first, second, and third anniversaries of the date of grant. The awards included distribution equivalent rights (“DERs”) pursuant to which the recipient would receive, upon vesting, receive a cash payment with respect to each phantom unit equal to any cash distributions that we pay to a holder of a common unit. DERs were treated as additional compensation expense. Upon vesting, the phantom units were scheduled to be settled through an amount of cash in a single lump sum payment equal to the product of (y) the closing price of our common units on the vesting date and (z) the number of such vested phantom units. In lieu of a cash payment, the board of directors of our Predecessor’s general partner, in its discretion, was permitted to elect for the recipient to receive either a number of common units equal to the number of such vested phantom units or a combination of cash and common units. Upon emergence from bankruptcy, the remaining awards were settled in cash for less than $0.1 million. 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): Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 Equity classified awards TSUs (Successor) $ 1,797 $ 1,445 $ 1,906 $ — PSUs (Successor) 981 1,404 — — Board RSUs (Successor) 264 142 41 — Restricted stock options (Successor) — (214 ) 569 — Restricted common units (Predecessor) — — — 3,713 Liability classified awards Phantom units (Predecessor) — — — (46 ) $ 3,042 $ 2,777 $ 2,516 $ 3,667

Leases

Leases	12 Months Ended
	Dec. 31, 2019
Leases [Abstract]
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, 2019, 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. The following table presents the Company’s right-of-use assets and lease liabilities as of December 31, 2019. December 31, 2019 (In thousands) Right-of-use asset $ 4,406 Lease liabilities: Current lease liability 1,712 Long-term lease liability 2,720 Total lease liability $ 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 2020 $ 1,603 $ 688 $ 2,291 2021 1,631 536 2,167 2022 140 59 199 2023 and thereafter — — — Total lease payments $ 3,374 $ 1,283 $ 4,657 Less: interest $ 177 $ 48 $ 225 Present value of lease liabilities $ 3,197 $ 1,235 $ 4,432 The following is a schedule of the Company’s future contractual payment for operating leases prepared in accordance with accounting standards prior to the adoption of ASC 842, as of December 31, 2018 (in thousands): Payment or Settlement Due by Period Operating leases Total 2019 2020 2021 2022 2023 Thereafter Operating leases $ 11,846 $ 5,893 $ 2,072 $ 2,109 $ 337 $ 205 $ 1,230 The weighted average remaining lease terms and discount rate for all of our operating leases were as follow as of December 31, 2019: December 31, 2019 Weighted average remaining lease term (years): Office leases 1.50 Vehicles 0.44 Office equipment 0.08 Weighted average discount rate: Office leases 3.63 % Vehicles 0.84 % Office equipment 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. 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. We have instituted internal controls going forward to monitor and evaluate new leases for appropriate accounting under the new guidance.

Supplemental Disclosures to the

Supplemental Disclosures to the Consolidated Balance Sheet and Condensed Statement of Cash Flows	12 Months Ended
	Dec. 31, 2019
Supplemental Disclosures To Condensed Consolidated Statements Of Cash Flows [Abstract]
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, 2019 2018 Accrued lease operating expense $ 11,794 $ 10,469 Accrued capital expenditures 5,515 4,349 Accrued general and administrative expense 3,126 4,393 Operating lease liability 1,712 — Asset retirement obligations 623 477 Accrued ad valorem tax 520 729 Accrued interest payable 36 2,476 Other 32 262 Accrued liabilities $ 23,358 $ 23,155 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, 2019 2018 Cash and cash equivalents $ — $ 49,704 Restricted cash 325 325 Total cash, cash equivalents and restricted cash $ 325 $ 50,029 Supplemental Cash Flows Supplemental cash flow for the periods presented (in thousands): Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 Supplemental cash flows: Cash paid for interest, net of amounts capitalized $ 15,937 $ 17,083 $ 12,109 $ 6,598 Cash paid for reorganization items, net 1,057 2,399 7,943 11,999 Noncash investing and financing activities: Increase (decrease) in capital expenditures in payables and accrued liabilities 2,143 (156 ) (1,080 ) 3,173 Asset retirement obligation removal related to divestitures — (15,702 ) — — 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, 2019
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Agreements The Predecessor and certain of our former affiliates entered into various documents and agreements. These agreements were negotiated among affiliated parties and, consequently, were not the result of arm’s-length negotiations.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2019
Commitments And Contingencies Disclosure [Abstract]
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. Other than the Chapter 11 proceedings discussed herein, based on facts currently available, 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, 2019 and 2018, we had no environmental reserves recorded. Third-Party Midstream Transaction In October 2017, Legacy Amplify recognized an approximately $17.0 million gain in connection with the sale of a third-party midstream entity with whom our natural gas gathering and processing agreements entitled us to a percentage of the proceeds in the event of a sale. 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. Sinking Fund Trust Agreement Beta Operating Company, LLC (“Beta”) 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, 2019, 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. On October 5, 2018, the Company received approximately $61.5 million from the trust account (the “Beta Decommissioning Trust Account”). On November 20, 2018, the Company received an additional $1.0 million from the Beta Decommissioning Trust Account that had been withheld from the initial payment on October 5, 2018. The cash released to the Company’s balance sheet was made pursuant to an order of the Bankruptcy Court dated February 9, 2018, which allowed for the release of Beta cash subject to certain conditions that have since been satisfied. 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. 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, 2019 and 2018, the period from May 5, 2017 through December 31, 2017, and the period from January 1, 2017 through May 4, 2017, we recognized $7.5 million, $8.6 million, $6.3 million and $3.1 million of rent expense, respectively. See Note 15 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, 2019, we had a CO 2 2 2 Payment or Settlement Due by Period Purchase commitment Total 2020 2021 2022 2023 2024 Thereafter CO 2 $ 4,365 $ 4,365 $ — $ — $ — $ — $ — Minimum Volume Commitment At December 31, 2019, we had a long-term minimum volume commitment with a third party associated with a certain portion of our properties located in Oklahoma and East Texas. The table below outlines the payment commitments associated with this minimum volume commitment (in thousands): Payment or Settlement Due by Period Minimum volume commitment Total 2020 2021 2022 2023 2024 Thereafter Midstream services $ 11,781 $ 3,967 $ 3,788 $ 3,746 $ 280 $ — $ — 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 is not meeting the minimum volume required under these contractual provisions. The commitment fee/expense for June through December 2019 was $0.7 million and the average estimated fee for 2020 is expected to be $0.1 million per month.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Income Tax	Note 19. Income Tax Amplify Energy is a corporation and as a result, is subject to U.S. federal, state and local income taxes. On December 22, 2017, the U.S. government enacted comprehensive tax legislation commonly referred to as the Tax Cuts and Jobs Act (the “Tax Act”). The provisions of the Tax Act that impact us include, but are not limited to, (1) reducing the U.S. federal corporate tax rate from 35% to 21%; (2) elimination of the corporate alternative minimum tax (AMT); (3) temporary bonus depreciation that will allow for full expensing of qualified property, and (4) limitations on net operating losses (NOLs) generated after December 31, 2017, to 80% of taxable income. The components of income tax benefit (expense) are as follows: Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 (In thousands) (In thousands) Current taxes: Federal $ — $ — $ 4 $ — State 50 — (34 ) 17 Total current income tax benefit (expense) 50 — (30 ) 17 Deferred taxes: Federal — — 1,933 71 State — — 273 3 Total deferred income tax benefit (expense) — — 2,206 74 Total income tax benefit (expense) $ 50 $ — $ 2,176 $ 91 The actual income tax benefit (expense) differs from the expected amount computed by applying the federal statutory corporate tax rate of 21% in 2019, 21% in 2018 and 35% in 2017 as follows: Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 (In thousands) (In thousands) Expected tax benefit (expense) at federal statutory rate $ 7,402 $ 11,468 $ 310 $ 5,764 State income tax benefit (expense), net of federal benefit 946 1,108 240 30 Non-deductible expenses (3,659 ) 1,328 (187 ) — Changes in valuation allowances (4,332 ) (14,194 ) 24,767 — Remeasurement of federal deferred tax assets due rate change — — (22,958 ) — Pass-through entities (1) — — — (5,686 ) Non-cash compensation (367 ) — — — Other 60 290 4 (17 ) Total income tax benefit (expense) $ 50 $ — $ 2,176 $ 91 (1) MEMP, a publicly traded partnership with qualifying income, was a pass-through entity for federal income tax purposes. 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, 2019 2018 Deferred income tax assets: Property, Plant & Equipment $ 37,075 $ 2,208 Net operating loss carryforward 141,534 19,085 Disallowed interest expense 10,627 5,748 Accrued liabilities 1,431 1,387 Other 4,234 307 Total deferred income tax assets: 194,901 28,735 Valuation allowance (189,941 ) (23,934 ) Net deferred income tax assets 4,960 4,801 Deferred income tax liabilities: Derivatives $ 2,767 $ 4,801 Other 2,193 — Total deferred income tax liabilities 4,960 4,801 Net deferred income tax liabilities $ — $ — As of December 31, 2019, the Company had approximately $618.0 million of federal net operating loss carryovers of which $590.6 million have no expiration date and the remaining will expire in year 2037. As of December 31, 2019, the Company had approximately $238.5 million of state net operating loss carryovers of which $203.9 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, 2019, a valuation allowance of $189.9 million had been recorded which is an increase to the valuation allowance of $166.0 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, 2019. Tax Audits and Settlements. Currently, the Internal Revenue Service (IRS) is auditing our 2017 tax year; however, there have been no proposed adjustments or resolutions communicated to the Company. Our income tax years 2018 and 2019 remain open and subject to examination by the IRS. For state and local jurisdictions, our 2017 through 2019 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.

Quarterly Financial Information

Quarterly Financial Information (Unaudited)	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Information (Unaudited)	Note 20. Quarterly Financial Information (Unaudited) The following tables present selected quarterly financial data for the periods indicated. Earnings per share/unit are computed independently for each of the quarters presented and the sum of the quarterly earnings per share/unit may not necessarily equal the total for the year. For the year ended December 31, 2019 First Second Third Fourth Quarter Quarter Quarter Quarter (In thousands, except per share amounts) Revenues $ 65,155 $ 59,532 $ 72,959 $ 77,929 Operating income (loss) (27,251 ) 23,527 14,807 (23,054 ) Net income (loss) (31,477 ) 18,641 5,157 (27,518 ) Net income (loss) attributable to Successor (31,477 ) 18,641 5,157 (27,518 ) Net income (loss) available to common stockholders (31,477 ) 17,913 5,029 (27,518 ) Basic and diluted earnings per share $ (1.42 ) $ 0.80 $ 0.15 $ (0.71 ) For the year ended December 31, 2018 First Second Third Fourth Quarter Quarter Quarter Quarter (In thousands, except per share/unit amounts) Revenues $ 87,932 $ 90,988 $ 85,522 $ 75,702 Operating income (loss) 9,529 (18,226 ) 3,206 87,014 Net income (loss) 3,239 (25,279 ) (2,598 ) 79,247 Net income (loss) attributable to Successor 3,239 (25,279 ) (2,598 ) 79,247 Net income (loss) available to common stockholders 3,156 (25,279 ) (2,598 ) 75,727 Basic and diluted earnings per share 0.13 (1.01 ) (0.10 ) 3.06 See Notes 4 and 13 for additional information regarding earnings per share/unit.

Supplemental Oil and Gas Inform

Supplemental Oil and Gas Information (Unaudited)	12 Months Ended
	Dec. 31, 2019
Extractive Industries [Abstract]
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, 2019 2018 (In thousands) Evaluated oil and natural gas properties $ 797,005 $ 598,331 Support equipment and facilities 140,023 108,760 Accumulated depletion, depreciation, and amortization (136,747 ) (82,389 ) Total $ 800,281 $ 624,702 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: Successor Predecessor Period from For the For the May 5, 2017 Period from Year Ended Year Ended through January 1, December 31, December 31, December 31, 2017 through 2019 2018 2017 May 4, 2017 (In thousands) (In thousands) Property acquisition costs, proved $ 150,871 $ — $ — $ — Property acquisition costs, unproved 7,674 — — — Exploration — — — — Development 71,460 42,878 51,925 9,573 Total $ 230,005 $ 42,878 $ 51,925 $ 9,573 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 Cawley, Gillespie and Associates (“CG&A”) to prepare our reserves estimates for all of our estimated proved reserves (by volume) at December 31, 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: 2019 2018 2017 Oil ($/Bbl): WTI (1) $ 55.69 $ 65.56 $ 51.34 NGL ($/Bbl): WTI (1) $ 55.69 $ 65.56 $ 51.34 Natural Gas ($/MMbtu): Henry Hub (2) $ 2.58 $ 3.10 $ 2.98 (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, 2019 Oil Gas NGLs Total (MBbls) (MMcf) (MBbls) (MBoe) Proved developed and undeveloped reserves: Beginning of year 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 year 70,772 377,869 29,252 163,002 Proved developed reserves: Beginning of year 54,147 232,110 17,324 110,156 End of year 53,476 320,731 23,646 130,577 Proved undeveloped reserves: Beginning of year 15,477 61,849 4,248 30,033 End of year 17,296 57,138 5,606 32,425 For the Year Ended December 31, 2018 (Successor) Oil Gas NGLs Total (MBbls) (MMcf) (MBbls) (MBoe) Proved developed and undeveloped reserves: Beginning of period 72,004 406,558 25,189 164,953 Extensions and discoveries 1,207 2,910 231 1,923 Production (3,335 ) (29,176 ) (1,496 ) (9,694 ) Sale of minerals in place (159 ) (56,328 ) (1,469 ) (11,016 ) Revision of previous estimates (93 ) (30,005 ) (883 ) (5,977 ) End of period 69,624 293,959 21,572 140,189 Proved developed reserves: Beginning of period 50,014 299,481 17,982 117,910 End of period 54,147 232,110 17,324 110,156 Proved undeveloped reserves: Beginning of period 21,990 107,077 7,207 47,043 End of period 15,477 61,849 4,248 30,033 For the period from May 5, 2017 through December 31, 2017 (Successor) Oil Gas NGLs Total (MBbls) (MMcf) (MBbls) (MBoe) Proved developed and undeveloped reserves: Beginning of period 80,960 419,472 30,572 181,444 Extensions and discoveries 121 4,900 261 1,199 Production (2,380 ) (21,885 ) (1,114 ) (7,142 ) Revision of previous estimates (6,697 ) 4,071 (4,530 ) (10,548 ) End of period 72,004 406,558 25,189 164,953 Proved developed reserves: Beginning of period 57,803 297,101 21,963 129,283 End of period 50,014 299,481 17,982 117,910 Proved undeveloped reserves: Beginning of period 23,157 122,371 8,609 52,161 End of period 21,990 107,077 7,207 47,043 For the period from January 1, 2017 through May 4, 2017 (Predecessor) Oil Gas NGLs Total (MBbls) (MMcf) (MBbls) (MBoe) Proved developed and undeveloped reserves: Beginning of year 65,741 371,016 25,184 152,761 Extensions and discoveries 53 45 8 69 Production (1,204 ) (12,411 ) (616 ) (3,890 ) Revision of previous estimates 16,370 60,822 5,996 32,504 End of year 80,960 419,472 30,572 181,444 Proved developed reserves: Beginning of year 45,536 280,035 18,923 111,132 End of year 57,803 297,101 21,963 129,283 Proved undeveloped reserves: Beginning of year 20,205 90,981 6,261 41,630 End of year 23,157 122,371 8,609 52,161 Noteworthy amounts included in the categories of proved reserve changes in the above tables include: • 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. • The 24.7 MMBoe reduction in reserves for the year ended December 31, 2018 is primarily due to a 4.6 MMBoe upward pricing revision and a 10.6 MMBoe downward revision due to updated well performance data and future anticipated development and maintenance cost increases. We divested 11.0 MMBoe during the year ended December 31, 2018. We added 1.9 MMBoe during the year ended December 31, 2018 due to extensions and discoveries. • The 16.5 MMBoe reduction in reserves for the period from May 5, 2017 through December 31, 2017 is primarily due to a 2.2 MMBoe upward pricing revision and a 12.8 MMBoe downward revision due to updated well performance data and future anticipated development and maintenance cost increases. We added 1.2 MMBoe during the period from May 5, 2017 through December 31, 2017 due to extensions and discoveries. • The 28.7 MMBoe increase in reserves for the January 1, 2017 through May 4, 2017 is primarily due to a 34.1 MMBoe upward pricing revision and a 1.5 MMBoe downward revision due to updated well performance data. Proved undeveloped reserves increased primarily due to upward pricing during the period from January 1, 2017 through May 4, 2017. See Note 6 for additional information on acquisitions and divestitures. 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: Successor Predecessor Period from For the For the May 5, 2017 Period from Year Ended Year Ended through January 1, December 31, December 31, December 31, 2017 through 2019 2018 2017 May 4, 2017 (In thousands) (In thousands) Future cash inflows $ 5,146,288 $ 6,000,268 $ 5,149,623 $ 5,246,487 Future production costs (2,917,262 ) (3,280,778 ) (2,982,035 ) (3,275,952 ) Future development costs (567,423 ) (474,413 ) (530,133 ) (492,610 ) Future income tax expense — — — — Future net cash flows for estimated timing of cash flows 1,661,603 2,245,077 1,637,455 1,477,925 10% annual discount for estimated timing of cash flows (745,042 ) (1,132,048 ) (869,784 ) (786,836 ) Standardized measure of discounted future net cash flows $ 916,561 $ 1,113,029 $ 767,671 $ 691,089 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 three year period ended December 31, 2019: Successor Predecessor Period from For the For the May 5, 2017 Period from Year Ended Year Ended through January 1, December 31, December 31, December 31, 2017 through 2019 2018 2017 May 4, 2017 (In thousands) (In thousands) Beginning of year $ 1,113,029 $ 767,671 $ 691,089 $ 395,841 Sale of oil and natural gas produced, net of production costs (113,545 ) (181,841 ) (100,946 ) (57,420 ) Purchase of minerals in place 408,370 — — — Sale of minerals in place — (29,036 ) — — Extensions and discoveries 5,334 27,157 7,187 1,320 Changes in prices and costs (623,592 ) 507,888 161,106 306,375 Previously estimated development costs incurred 84,341 73,761 61,851 9,227 Net changes in future development costs 110,892 24,396 (31,438 ) (55,333 ) Revisions of previous quantities (183,300 ) (86,812 ) (27,060 ) 99,591 Accretion of discount 92,998 51,769 46,072 13,195 Change in production rates and other 22,034 (41,924 ) (40,190 ) (21,707 ) End of year $ 916,561 $ 1,113,029 $ 767,671 $ 691,089

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2019
Subsequent Events [Abstract]
Subsequent Events	Departure of Certain Officers On January 30, 2020, Richard P. Smiley notified the Company of his intent to resign from his current position as Senior Vice President, Operations. Mr. Smiley intends to remain in his role at the Company to assist with an orderly transition of his responsibilities. Mr. Smiley did not resign from the position of Senior Vice President, Operations due to any disagreement with the Company or any matter relating to the Company’s operations, policies or practices.

Organization and Basis of Pre_2

Organization and Basis of Presentation (Policies)	12 Months Ended
	Dec. 31, 2019
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. As a result, period-to-period comparisons of our operating results may not be meaningful. The results of any one quarter should not be relied upon as an indication of future performance. 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. Legacy Amplify is the successor reporting company (the “Successor”) of Memorial Production Partners LP (“MEMP”) pursuant to Rule 15d-5 of the Securities Exchange Act of 1934, as amended. When referring to the “Predecessor” or the “Company” in reference to the period prior to Legacy Amplify emergence from bankruptcy, the intent is to refer to MEMP, the predecessor that was dissolved following the effective date of the Plan (as defined below) 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 South Texas. 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.
Definitive Merger Agreement	Definitive Merger Agreement On May 5, 2019, as discussed above, the Company entered into the Merger Agreement pursuant to which Legacy Amplify merged with a subsidiary of Midstates in an all-stock merger-of-equals. Under 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 Merger closed on August 6, 2019. See Note 6 for additional information.
Emergence from Voluntary Reorganization under Chapter 11	Emergence from Voluntary Reorganization under Chapter 11 On January 16, 2017 (the “Petition Date”), MEMP and certain of its subsidiaries (collectively with MEMP, the “Debtors”) filed voluntary petitions (the cases commenced thereby, the “Chapter 11 proceedings”) under Chapter 11 of Title 11 of the United States Code (the “Bankruptcy Code” or “Chapter 11”) in the United States Bankruptcy Court for the Southern District of Texas, Houston Division (the “Bankruptcy Court”). The Debtors’ Chapter 11 proceedings were jointly administered under the caption In re: Memorial Production Partners LP, et al.
Basis of Presentation	Basis of Presentation Our Consolidated Financial Statements included herein have been prepared pursuant to the rule and guidelines of the Securities and Exchange Commission (the “SEC”). All 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”). Certain amounts in the prior year financial statements have been reclassified to conform to current presentation. Gain (loss) on extinguishment of deferred finance cost were previously accounted for as interest expense, net and are now being presented as gain (loss) on extinguishment of debt on our Statement of Consolidated Operations. Beginning in 2019, the Company has elected to change its reporting convention from natural gas equivalent (Mcfe) to barrels of oil equivalent (Boe). The change in presentation reflects our liquids-weighted production and reserve profile with a balanced approach to development of our oil and natural gas asset portfolio. 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”). ASC 852 requires that the financial statements, for periods subsequent to the Chapter 11 filing, distinguish transactions and events that are directly associated with the reorganization from the ongoing operations of the business. 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. The Company adopted the new accounting pronouncement related to the presentation of statement of cash flows — restricted cash in the first quarter of 2018. A retrospective change for the period from January 1, 2017 through May 4, 2017 and May 5, 2017 through December 31, 2017 on the Statement of Consolidated Cash Flows as previously presented was required due to adoption. The table below sets forth the retrospective adjustments for the periods presented: Predecessor Previously Period from January 1, 2017 through May 4, 2017 Adjustment Effect As Adjusted Period from January 1, 2017 through May 4, 2017 (In thousands) Changes in operating assets and liabilities: Restricted cash $ (7,561 ) $ 7,561 $ — Net cash provided by operating activities 117,937 7,561 125,498 Net change in cash and cash equivalents 4,767 7,561 12,328 Cash and cash equivalents, end of period 20,140 7,561 27,701 Successor Previously Period from May 5, 2017 through December 31, 2017 Adjustment Effect As Adjusted Period from May 5, 2017 through December 30, 2017 (In thousands) Changes in operating assets and liabilities: Restricted cash $ 7,561 $ (7,561 ) $ — Net cash provided by operating activities 102,203 (7,561 ) 94,642 Net change in cash and cash equivalents (13,748 ) (7,561 ) (21,309 ) Cash and cash equivalents, end of period 6,392 — 6,392
Comparability of Financial Statements to Prior Periods	Comparability of Financial Statements to Prior Periods As discussed in further detail in Note 3 below, Legacy Amplify adopted and applied the relevant guidance provided in GAAP with respect to the accounting and financial statement disclosures for entities that have emerged from bankruptcy proceedings (“Fresh Start Accounting”). Accordingly, our Consolidated Financial Statements and Notes after May 4, 2017, are not comparable to the Consolidated Financial Statements and Notes prior to that date. To facilitate our financial statement presentations, we refer to the reorganized company in these Consolidated Financial Statements and Notes as the “Successor” for periods subsequent to May 4, 2017 and “Predecessor” for periods prior to May 5, 2017. Furthermore, our Consolidated Financial Statements and Notes have been presented with a “black line” division to delineate the lack of comparability between the Predecessor and Successor.
Fresh Start Accounting	Fresh Start Accounting Upon the Effective Date, Legacy Amplify adopted fresh start accounting as required by GAAP. We met the requirements of fresh start accounting, which include: (i) the holders of the Predecessor’s voting common units immediately prior to the Effective Date received less than 50% of the voting shares of Legacy Amplify and (ii) the reorganization value of our assets immediately prior to the Effective Date was less than the post-petition liabilities and allowed claims. Fresh start accounting involved a comprehensive valuation process in which we determined the fair value of all of Legacy Amplify’s assets and liabilities on the Effective Date. See Note 3 for additional information.
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. Additionally, management believes that any credit risk imposed by a concentration in the oil and natural gas industry is mitigated by the creditworthiness of its customer base. 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 and $1.2 million as an allowance for doubtful accounts at December 31, 2019 and 2018, respectively. 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.
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, 2019 and 2018.
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. 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 (by volume) at December 31, 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 10 and Note 18 for additional information.
Debt Issuance Costs	Debt Issuance Costs These costs are recorded 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, 2019 and 2018 and the period from May 5, 2017 through December 31, 2017 was approximately $1.2 million, $2.5 million and $2.1 million, respectively. No amortization of deferred financing cost was recorded for the period from January 1, 2017 through May 4, 2017 as the unamortized amount of deferred financing cost at December 31, 2016 was written off due to (i) the uncertainty regarding the Predecessor’s ability to cure the default that existed at December 31, 2016, (ii) the Predecessor’s inability to comply with certain financial covenants contained in our Predecessor’s revolving credit facility and (iii) the default or cross default provisions in the indentures governing the 2021 Senior Notes and 2022 Senior Notes.
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. No impairment expense related to our proved properties was recorded for the years ended December 31, 2019 and 2018, the period from May 5, 2017 through December 31, 2017 or the period from January 1, 2017 through May 4, 2017. 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 $2.2 million in impairment expense for certain unproved leasehold costs for the year ended December 31, 2019. We did not record any impairments related to unproved properties for the year ended December 31, 2018, the period from May 5, 2017 through December 31, 2017 or the period from January 1, 2017 through May 4, 2017. 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 9 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, 2019 and 2018. In May 2014, the FASB issued guidance regarding the accounting for revenue from contracts with customers. This standard includes a five-step revenue recognition model to depict the transfer of goods or services to customers in an amount that reflects the consideration we expect to be entitled to in exchange for those goods or services. Among other things, the standard also eliminates industry-specific revenue guidance and requires enhanced disclosures related to the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The standard was effective for the Company starting January 1, 2018, and the Company adopted the standard using a modified retrospective approach. See Note 5 for additional information. The following individual customers each accounted for 10% or more of total reported revenues for the period indicated: Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 Major customers: Phillips 66 27% 27% 23% 19% Sinclair Oil & Gas Company 21% 21% 19% 20% CIMA Energy n/a 10% 11% n/a BP America Production Company 13% n/a 10% 10%
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. For the years ended December 31, 2019 and 2018 and the period from May 5, 2017 through December 31, 2017 we had $0.2 million, $0.5 million and $0.4 million in capitalized interest, respectively. No capitalized interest recorded for the period from January 1, 2017 through May 4, 2017.
Income Tax	Income Tax We are a corporation subject to federal and certain state income taxes. Our Predecessor was organized as a pass-through entity for federal and most state income tax purposes. Certain of our consolidated subsidiaries were taxed as corporations for federal and state income tax purposes. We are also subject to the Texas margin tax for activity in the state of Texas. 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 interest and penalties accrued to unrecognized tax benefits in other income (expense) in our Statement of Consolidated Operations. 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. 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. On December 22, 2017, the U.S. government enacted comprehensive tax legislation commonly referred to as the Tax Cuts and Jobs Act (the “Tax Act”). The provisions of the Tax Act that impact us include, but are not limited to, (1) reducing the U.S. federal corporate tax rate from 35% to 21%; (2) elimination of the corporate alternative minimum tax (AMT); (3) temporary bonus depreciation that will allow for full expensing of qualified property, and (4) limitations on net operating losses (NOLs) generated after December 31, 2017, to 80 percent of taxable income.
Earnings Per Share/Unit	Earnings Per Share/Unit Basic and diluted earnings per share/unit (“EPS” or “EPU”) is determined by dividing net income or loss available to the common stockholders/limited partners by the weighted average number of outstanding shares/units 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. Net income or loss available to the Predecessor limited partners was determined by applying the two-class method. The two-class method of computing the Predecessor’s EPU was an earnings allocation formula that determined EPU based on distributions declared. The amount of net income or loss used in the determination of EPU was reduced (or increased) by the amount of available cash that had been distributed to the Predecessor’s limited partners for that corresponding period. The remaining undistributed earnings or excess distributions over earnings were allocated to the Predecessor’s limited partners in accordance with the contractual terms of the Predecessor’s partnership agreement. The total earnings allocated to the Predecessor’s limited partners was determined by adding together the amount allocated for distributions declared and the amount allocated for the undistributed earnings or excess distributions over earnings. Basic and diluted EPU are equivalent, as all restricted common units and subordinated units participated in distributions. See Note 13 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 14 for further information.
Recently Adopted Accounting Pronouncements	Recently Adopted Accounting Pronouncements Lease Recognition In February 2016, the Financial Accounting Standards Board (“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 15 for additional information regarding the adoption of the leases standard.
New Accounting Pronouncements	New Accounting Pronouncements 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 impact of this guidance is not expected to have a material impact on the Company. Financial Instruments — Credit Losses . In May 2019 the FASB issued an accounting standards 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. The fair value option election does not apply to held-to-maturity debt securities. The new guidance is effective for annual periods beginning after December 15, 2019, and interim periods within those annual periods. The Company is currently evaluating the impact of this guidance and does not expect the guidance to have a material impact on the Company’s financial statements. 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 December 15, 2020. The Company is currently evaluating the impact of this guidance and does not expect the guidance to have a material impact on the Company's 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.

Organization and Basis of Pre_3

Organization and Basis of Presentation (Tables)	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Summary of Prior Period Adjustments in Cash Flows	The table below sets forth the retrospective adjustments for the periods presented: Predecessor Previously Period from January 1, 2017 through May 4, 2017 Adjustment Effect As Adjusted Period from January 1, 2017 through May 4, 2017 (In thousands) Changes in operating assets and liabilities: Restricted cash $ (7,561 ) $ 7,561 $ — Net cash provided by operating activities 117,937 7,561 125,498 Net change in cash and cash equivalents 4,767 7,561 12,328 Cash and cash equivalents, end of period 20,140 7,561 27,701 Successor Previously Period from May 5, 2017 through December 31, 2017 Adjustment Effect As Adjusted Period from May 5, 2017 through December 30, 2017 (In thousands) Changes in operating assets and liabilities: Restricted cash $ 7,561 $ (7,561 ) $ — Net cash provided by operating activities 102,203 (7,561 ) 94,642 Net change in cash and cash equivalents (13,748 ) (7,561 ) (21,309 ) Cash and cash equivalents, end of period 6,392 — 6,392

Fresh Start Accounting (Tables)

Fresh Start Accounting (Tables)	12 Months Ended
	Dec. 31, 2019
Fresh Start Accounting [Abstract]
Reconciliation of the Enterprise Value to the Reorganization Value	The following table is a reconciliation of the enterprise value to the reorganization value of the Successor assets at the Effective Date (in thousands): Enterprise value $ 800,000 Plus: Cash and cash equivalents 20,140 Plus: Other working capital liabilities 63,817 Plus: Other long-term liabilities 97,470 Reorganization value of Successor assets $ 981,427
Schedule of Reorganization and Fresh Start Adjustments	The adjustments included in the following condensed consolidated balance sheet reflected the effect of the transactions contemplated by the Plan (reflected in the column “Reorganization Adjustments”) as well as fair value and other required accounting adjustments resulting from the adoption of fresh start accounting (reflected in the column “Fresh Start Adjustments”). The explanatory notes provide additional information with regard to the adjustments recorded, the methods used to determine the fair values and significant assumptions. As of May 4, 2017 Reorganization Fresh Start Predecessor Adjustments (1) Adjustments Successor (In thousands) ASSETS Current assets: Cash and cash equivalents $ 83,050 $ (62,910 ) (2) $ — $ 20,140 Restricted cash — 7,411 (3) — 7,411 Accounts receivable 33,560 — — 33,560 Short-term derivative instruments 51,329 — — 51,329 Prepaid expenses and other current assets 10,229 675 (4) — 10,904 Total current assets 178,168 (54,824 ) — 123,344 Property and equipment, net 1,551,500 — (894,164 ) (11) 657,336 Long-term derivative instruments 33,800 — — 33,800 Restricted investments 156,443 — — 156,443 Other long-term assets 1,929 8,575 (5) — 10,504 Total assets $ 1,921,840 $ (46,249 ) $ (894,164 ) $ 981,427 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 1,501 $ 1,389 (6) $ — $ 2,890 Revenues payable 22,747 — — 22,747 Accrued liabilities 36,954 2,939 (7) (1,713 ) (12) 38,180 Current portion of long-term debt 454,799 (454,799 ) (8) — — Total current liabilities 516,001 (450,471 ) (1,713 ) 63,817 Liabilities subject to compromise 1,162,437 (1,162,437 ) (9) — — Long-term debt — 430,000 (8) — 430,000 Asset retirement obligations 158,114 — (62,928 ) (13) 95,186 Deferred tax liabilities 2,206 — — 2,206 Other long-term liabilities 2,481 — (2,403 ) (12) 78 Total liabilities 1,841,239 (1,182,908 ) (67,044 ) 591,287 Commitments and contingencies (see Note 18) Stockholders'/partners' equity: Predecessor common units 80,601 (80,601 ) (10) — — Successor warrants — 4,788 (10) — 4,788 Successor common stock — 3 (10) — 3 Successor additional paid-in capital — 1,212,469 (10) (827,120 ) (14) 385,349 Total stockholders'/ partners' equity 80,601 1,136,659 (827,120 ) 390,140 Total liabilities and equity $ 1,921,840 $ (46,249 ) $ (894,164 ) $ 981,427 Reorganization Adjustments (1) Reflected amounts recorded as of the Effective Date for the implementation of the Plan, including among other items, settlement of the Predecessor’s liabilities subject to compromise, cancellation of the Predecessor’s equity, issuance of the Successor New Common Shares and the Warrants, repayment of certain of Predecessor’s debt and settlement with holders of the Notes. (2) Reflected the changes in cash and cash equivalents, including the following (in thousands): Payment on the Predecessor's revolving credit facility $ (24,799 ) Payment to holders of the Notes (1) (16,446 ) Payment of fees related to Emergence Credit Facility (8,575 ) Funding of the professional fees escrow account (7,411 ) Payment of professional fees (4,295 ) Other (1,384 ) Changes in cash and cash equivalents $ (62,910 ) (1) The total cash settlement to the holders of the Notes was approximately $24.6 million, of which $16.4 million was paid upon emergence and $8.2 million was paid post-emergence and is reflected in accrued liabilities in the above condensed consolidated balance sheet. (3) Reflected the transfer to restricted cash to fund the professional fees escrow account. (4) Reflected the pre-payment of certain professional fees. (5) Reflected the deferred financing costs related to the Emergence Credit Facility. (6) Reflected the recognition of payables for general unsecured claims. (7) Net increase in accrued liabilities reflected the following (in thousands): Recognition of liability for settlement with holders of the Notes $ 8,193 Payment of professional fees (4,295 ) Recognition of contribution from management (1,500 ) Recognition of settlement with Predecessor common unitholders 1,250 Other (709 ) Net increase in accrued liabilities due to reorganization items $ 2,939 (8) Reflected a repayment of $24.8 million on the Predecessor’s revolving credit facility and the reclassification of $430.0 million in borrowings under the Emergence Credit Facility to long-term debt. (9) Settlement of liabilities subject to compromise and the resulting net gain were determined as follows (in thousands): Accounts payable $ 1,389 Accrued interest payable 49,796 Debt 1,111,252 Total liabilities subject to compromise of Predecessor 1,162,437 Recognition of payables for general unsecured claims (1,389 ) Recognition of settlement with holders of the Notes (24,639 ) Issuance of common stock to holders of the Notes (377,645 ) Gain on settlement of liabilities subject to compromise $ 758,764 (10) Net increase in our stockholders’/partners’ equity reflects the following (in thousands): Issuance of common stock to holders of the Notes $ 377,645 Issuance of common stock to Predecessor common unitholders 7,707 Cancellation of the Predecessor's units issued and outstanding 80,601 Recognition on gain on settlement of liabilities subject to compromise 758,764 Recognition of issuance of common stock to Predecessor common unitholders (7,707 ) Recognition of issuance of warrants to Predecessor common unitholders (4,788 ) Recognition of contribution from management 1,500 Recognition of settlement with Predecessor common unitholders (1,250 ) Par value of common stock (3 ) Change in Successor additional paid-in capital 1,212,469 Issuance of warrants to Predecessor common unitholders 4,788 Par value of common stock 3 Predecessor units issued and outstanding (80,601 ) Net increase in capital accounts $ 1,136,659 Fresh Start Adjustments (11) Reflected a decrease of property and equipment, net based on the methodology discussed above and the elimination of accumulated depreciation, depletion and impairment. The fresh start adjustments to property and equipment, net are as follow: Predecessor Fresh Start Adjustments Successor (In thousands) Property and equipment at cost: Proved oil and natural gas properties $ 3,124,137 $ (2,615,076 ) $ 509,061 Support equipment and facilities 199,463 (101,883 ) 97,580 Unproved oil and natural gas properties — 44,688 44,688 Other 15,420 (9,413 ) 6,007 Property and equipment 3,339,020 (2,681,684 ) 657,336 Accumulated depreciation, depletion and impairment (1,787,520 ) 1,787,520 — Property and equipment, net $ 1,551,500 $ (894,164 ) $ 657,336 (12) Reflected the write-off of the deferred rent and loss on sublease liabilities. (13) Reflected a decrease of $62.9 million for asset retirement obligations. The fair value of asset retirement obligations was estimated using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation include estimates of: (i) plugging and abandonment costs per well based on existing regulatory requirements; (ii) remaining life per well; (iii) future inflation factors; and (iv) a credit-adjusted risk free rate. (14) Reflected the cumulative impact of our fresh start accounting adjustments discussed above.
Schedule of Reorganization Items, Net	The following table summarizes the components of reorganization items, net included in the accompanying Statements of Consolidated Operations (in thousands): Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 Gain on settlement of liabilities subject to compromise $ — $ — $ — $ 758,764 Fresh start valuation adjustments — — — (827,120 ) Professional fees (430 ) (864 ) (724 ) (19,824 ) Other (627 ) (1,283 ) (395 ) (594 ) Reorganization items, net $ (1,057 ) $ (2,147 ) $ (1,119 ) $ (88,774 )

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2019
Accounting Policies [Abstract]
Major Customers	The following individual customers each accounted for 10% or more of total reported revenues for the period indicated: Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 Major customers: Phillips 66 27% 27% 23% 19% Sinclair Oil & Gas Company 21% 21% 19% 20% CIMA Energy n/a 10% 11% n/a BP America Production Company 13% n/a 10% 10%

Revenue (Tables)

Revenue (Tables)	12 Months Ended
	Dec. 31, 2019
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, 2019 2018 (in thousands) Revenues Oil $ 192,944 $ 209,066 NGLs 22,347 42,463 Natural gas 59,316 88,311 Oil and natural gas sales $ 274,607 $ 339,840

Acquisitions and Divestitures (

Acquisitions and Divestitures (Tables)	12 Months Ended
	Dec. 31, 2019
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): Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 $ 17,305 $ 205 $ 609 $ —
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 and 2018, respectively, 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 2018 (Unaudited) (In thousands, except per unit amounts) Revenues $ 336,326 $ 545,226 Net income (loss) (22,926 ) 146,845 Earnings per share: Basic $ (0.78 ) $ 3.18 Diluted $ (0.78 ) $ 3.18

Fair Value Measurements of Fi_2

Fair Value Measurements of Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2019
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, 2019 and December 31, 2018 for each of the fair value hierarchy levels: 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 Fair Value Measurements at December 31, 2018 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 $ — $ 25,515 $ — $ 25,515 Liabilities: Commodity derivatives $ — $ 4,372 $ — $ 4,372

Risk Management and Derivativ_2

Risk Management and Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2019
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Open Commodity Positions	At December 31, 2019, the Company had the following open commodity positions: 2020 2021 2022 Natural Gas Derivative Contracts: Fixed price swap contracts: Average monthly volume (MMBtu) 600,000 487,500 300,000 Weighted-average fixed price $ 2.53 $ 2.48 $ 2.46 Collar contracts: Two-way collars Average monthly volume (MMBtu) 520,000 162,500 — Weighted-average floor price $ 2.64 $ 2.58 $ — Weighted-average ceiling price $ 2.96 $ 2.84 $ — Three-way collars Average monthly volume (MMBtu) 76,000 — — Weighted-average ceiling price $ 3.45 $ — $ — Weighted-average floor price $ 2.65 $ — $ — Weighted-average sub-floor price $ 2.15 $ — $ — Natural Gas Basis Swaps: PEPL basis swaps: Average monthly volume (MMBtu) 600,000 500,000 — Weighted-average spread $ (0.46 ) $ (0.40 ) $ — Crude Oil Derivative Contracts: Fixed price swap contracts: Average monthly volume (Bbls) 213,050 116,250 30,000 Weighted-average fixed price $ 57.28 $ 56.05 $ 55.32 Collar contracts: Two-way collars Average monthly volume (Bbls) 14,300 — — Weighted-average floor price $ 55.00 $ — $ — Weighted-average ceiling price $ 62.10 $ — $ — Three-way collars Average monthly volume (Bbls) 30,500 — — Weighted-average ceiling price $ 65.75 $ — $ — Weighted-average floor price $ 50.00 $ — $ — Weighted-average sub-floor price $ 40.00 $ — $ — NGL Derivative Contracts: Fixed price swap contracts: Average monthly volume (Bbls) 65,425 22,800 — Weighted-average fixed price $ 25.20 $ 24.25 $ —
Interest Rate Swap Open Positions	2020 2021 2022 Average Monthly Notional (in thousands) $ 125,000 $ 125,000 $ 75,000 Weighted-average fixed rate 1.612 % 1.612 % 1.281 % Floating rate 1 Month LIBOR 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, 2019 and 2018. 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 New Credit Agreement. Asset Derivatives Liability Derivatives Asset Derivatives Liability Derivatives December 31, December 31, December 31, December 31, Type Balance Sheet Location 2019 2019 2018 2018 (In thousands) Commodity contracts Short-term derivative instruments $ 11,518 $ 5,887 $ 21,217 $ 2,543 Interest rate swaps Short-term derivative instruments 248 253 — — Gross fair value 11,766 6,140 21,217 2,543 Netting arrangements (5,887 ) (5,887 ) (2,404 ) (2,404 ) Net recorded fair value Short-term derivative instruments $ 5,879 $ 253 $ 18,813 $ 139 Commodity contracts Long-term derivative instruments $ 6,990 $ 973 $ 4,298 $ 1,829 Interest rate swaps Long-term derivative instruments 347 305 — — Gross fair value 7,337 1,278 4,298 1,829 Netting arrangements (973 ) (973 ) (1,829 ) (1,829 ) Net recorded fair value Long-term derivative instruments $ 6,364 $ 305 $ 2,469 $ —
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): Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 Statements of December 31, December 31, through through Operations Location 2019 2018 December 31, 2017 May 4, 2017 (Gain) loss on commodity derivatives $ 6,700 $ (8,155 ) $ 31,609 $ (23,076 ) Interest expense, net (224 ) — — —

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2019
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, 2019 and 2018, the period from May 5, 2017 through December 31, 2017 and the period from January 1, 2017 through May 4, 2017 (in thousands): Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 Asset retirement obligations at beginning of period $ 76,344 $ 100,173 $ 96,127 $ 155,702 Liabilities added from acquisition or drilling (1) 9,497 89 191 6 Liabilities removed upon sale of wells — (15,702 ) — — Liabilities settled (259 ) (767 ) (633 ) (164 ) Accretion expense 5,559 5,711 4,384 3,407 Revision of estimates (2) (52 ) (13,160 ) 104 104 Asset retirement obligation at end of period 91,089 76,344 100,173 159,055 Fresh start adjustment (3) — — — (62,928 ) Less: Current Portion 623 477 713 941 Asset retirement obligations - long-term portion $ 90,466 $ 75,867 $ 99,460 $ 95,186 (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. (2) The decrease in revision of estimates for the year ended December 31, 2018 is primarily due to receiving new cost estimates from third parties regarding the estimated plugging and abandonment costs. (3) As a result of the application of fresh start accounting, the Successor recorded its asset retirement obligation at fair value as of the Effective Date.

Restricted Investments (Tables)

Restricted Investments (Tables)	12 Months Ended
	Dec. 31, 2019
Investments Debt And Equity Securities [Abstract]
Restricted Investment Balances	The components of the restricted investment balances are as follows December 31, December 31, 2019 2018 (In thousands) BOEM platform abandonment (See Note 18) $ 313 $ 90,162 SPBPC Collateral: Contractual pipeline and surface facilities abandonment 4,309 4,305 Restricted investments $ 4,622 $ 94,467

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2019
Debt Disclosure [Abstract]
Consolidated Debt Obligations	Our consolidated debt obligations consisted of the following at the dates indicated: December 31, December 31, 2019 2018 (In thousands) Revolving Credit Facility (1) $ 285,000 $ 294,000 Long-term debt $ 285,000 $ 294,000 (1) The carrying amount of our Revolving Credit Facility and Emergence 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: Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 Revolving Credit Facility 4.76% 4.96% n/a n/a Emergence Credit Facility n/a 5.75% 5.08% n/a Predecessor's revolving credit facility n/a n/a n/a 4.18%

Equity (Deficit) (Tables)

Equity (Deficit) (Tables)	12 Months Ended
	Dec. 31, 2019
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, 2016 (Predecessor) 83,827,920 Restricted common units issued — Restricted common units forfeited (12,952 ) Restricted common units repurchased (1) (14,681 ) Balance, May 4, 2017 (Predecessor) 83,800,287 Cancellation of Predecessor common units (83,800,287 ) Balance, May 4, 2017 (Predecessor) — Issuance of Successor common stock 25,000,000 Balance, May 5, 2017 (Successor) 25,000,000 Issuance of Successor common stock — Balance, December 31, 2017 (Successor) 25,000,000 Issuance of common stock — Restricted stock units vested 163,700 Repurchase of common shares (65,152 ) Restricted common stock repurchased and retired under tender offer (2,916,667 ) Balance, December 31, 2018 (Successor) 22,181,881 Issuance of common stock — Restricted stock units vested 412,938 Repurchase of common shares (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 (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 (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 (1) Restricted common units were generally net-settled by our Predecessor unitholders to cover the required withholding tax upon vesting. The Predecessor unitholders surrendered units with value equivalent to the employees’ minimum statutory obligation for the applicable income and other employment taxes. Total payments remitted for the employees’ tax obligations to the appropriate taxing authorities were less than approximately $0.1 million for the period from January 1, 2017 through May 4, 2017. These net-settlements had the effect of unit repurchases by the Company as they reduced the number of units that would have otherwise been outstanding as a result of the vesting and did not represent an expense to the Company.
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_Unit (Tables

Earnings per Share/Unit (Tables)	12 Months Ended
	Dec. 31, 2019
Earnings Per Share [Abstract]
Calculation of Earnings (Loss) per Share/Unit	The following sets forth the calculation of earnings (loss) per share/unit, or EPS/EPU, for the periods indicated (in thousands, except per unit amounts): Successor Predecessor Period from For the For the May 5, 2017 Period from Year Ended Year Ended through January 1, December 31, December 31, December 31, 2017 through 2019 2018 2017 May 4, 2017 Net income (loss) attributable to Successor/Predecessor $ (35,197 ) $ 54,609 $ 1,286 $ (90,955 ) Less: Net income (loss) allocated to participating restricted stockholders — 2,426 35 — Basic and diluted earnings available to common stockholders/limited partners $ (35,197 ) $ 52,183 $ 1,251 $ (90,955 ) Common shares/units: Common shares/units outstanding — basic 29,301 24,959 25,000 83,807 Dilutive effect of potential common shares — — — — Common shares/units outstanding — diluted 29,301 24,959 25,000 83,807 Net earnings per share/unit: Basic $ (1.20 ) $ 2.09 $ 0.05 $ (1.09 ) Diluted $ (1.20 ) $ 2.09 $ 0.05 $ (1.09 ) Antidilutive stock options (1) — — 517 — Antidilutive warrants (2) 9,154 2,174 2,174 — (1) Amount represents options to purchase common stock that are excluded from the diluted net earnings per share calculations because of their antidilutive effect. (2) 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, 2019
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 restricted common unit awards for the periods presented: Weighted- Average Grant Number of Date Fair Value Units per Unit (1) Restricted common units outstanding at December 31, 2016 (Predecessor) 432,160 $ 15.00 Granted — $ — Forfeited (12,952 ) $ 9.51 Vested (43,045 ) $ 10.40 Cancelled (376,163 ) $ 15.72 Restricted common units outstanding at May 4, 2017 (Predecessor) — $ — (1) Determined by dividing the aggregate grant date fair value of awards by the number of awards issued.
Summary of Modified-Date Grant Fair Value Estimated Using Black-Scholes Option Pricing Model	The fair value for restricted stock options granted during the year ended December 31, 2017 had been estimated using Black-Scholes option pricing model using the following assumptions: Awards Issued in Successor Period Risk-free interest rate 2.06 % Dividend yield — Expected life (in years) 6.0 Expected volatility 50.0 % Strike Price $ 21.58 Calculated fair value per stock option $ 5.01 The modified-date grant fair value was estimated at December 31, 2018 using the Black-Scholes option pricing model using the following assumptions: Awards Issued in Successor Period Risk-free interest rate 2.49 % Dividend yield — Expected life (in years) 2.0 Expected volatility 50.0 % Strike Price $ 21.58 Calculated fair value per stock option $ 0.85
Summary of Stock Option Awards	The following table summarizes information regarding the restricted stock option awards granted under the Legacy Amplify MIP for the period presented: Weighted- Average Grant Number of Date Fair Value Options per Option (1) Restricted stock options outstanding at May 5, 2017 (Successor) 614,754 $ 5.01 Granted 1,876 $ 5.01 Forfeited (99,232 ) $ 5.01 Vested — $ — Restricted stock options outstanding at December 31, 2017 (Successor) 517,398 $ 5.01 Granted — $ — Forfeited (2) (161,243 ) $ 5.01 Vested (356,155 ) $ 5.01 Restricted stock options outstanding at December 31, 2018 — $ — (1) Determined by dividing the aggregate grant date fair value of awards by the number of awards issued. (2) In connection with certain grants awarded in 2018 pursuant to the Legacy Amplify MIP, all remaining unvested restricted stock options were forfeited.
Summary of Information Regarding Phantom Unit Awards	The following table summarizes information regarding the Predecessor’s phantom unit awards granted under the LTIP: Number of Units Phantom units outstanding at December 31, 2016 (Predecessor) 5,980,693 Granted — Forfeited (132,347 ) Vested (155,601 ) Phantom units outstanding at May 4, 2017 (Predecessor) 5,692,745 Cancelled (5,692,745 ) Phantom units outstanding at December 31, 2017 (Successor) —
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): Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 Equity classified awards TSUs (Successor) $ 1,797 $ 1,445 $ 1,906 $ — PSUs (Successor) 981 1,404 — — Board RSUs (Successor) 264 142 41 — Restricted stock options (Successor) — (214 ) 569 — Restricted common units (Predecessor) — — — 3,713 Liability classified awards Phantom units (Predecessor) — — — (46 ) $ 3,042 $ 2,777 $ 2,516 $ 3,667
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 May 5, 2017 (Successor) — $ — Granted (2) 16,341 $ 13.77 Forfeited — $ — Vested — $ — Board RSUs outstanding at December 31, 2017 (Successor) 16,341 $ 13.77 Granted (3) 28,708 $ 10.45 Forfeited — $ — Vested (5,445 ) $ 13.77 Board RSUs outstanding at December 31, 2018 39,604 $ 11.36 Granted (4) 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 (5) 0.933 Converted Board RSUs 30,616 Board RSUs outstanding on August 6, 2019 (6) 30,616 $ 5.12 Granted — $ — Forfeited — $ — Vested (14,459 ) $ 5.12 Board RSUs outstanding at December 31, 2019 16,157 $ 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 in 2017 was $0.2 million based on grant date market price of $13.77 per share. (3) The aggregate grant date fair value of Board RSUs issued in 2018 was $0.3 million based on a grant date market price of $10.45 per share. (4) 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. (5) The merger ratio used to convert Legacy Amplify Board RSUs into newly issued Company Board RSUs. (6) 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 May 5, 2017 (Successor) 614,754 $ 13.77 Granted (2) 173,070 $ 12.87 Forfeited (105,032 ) $ 13.77 Vested — $ — TSUs outstanding at December 31, 2017 (Successor) 682,792 $ 13.54 Granted (3) 437,000 $ 10.51 Forfeited (4) (363,513 ) $ 13.55 Vested (158,255 ) $ 13.44 TSUs outstanding at December 31, 2018 598,024 $ 11.35 Granted (5) 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 (6) 0.933 Converted TSUs 394,245 TSUs outstanding at August 6, 2019 (7) 394,245 $ 5.12 Granted (8) 17,500 $ 6.14 Forfeited (38,652 ) $ 5.12 Vested (81,723 ) $ 5.12 TSUs outstanding at December 31, 2019 291,370 $ 5.18 (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 May 5, 2017 through December 31, 2017 was $2.2 million based on a grant date market price ranging from $10.00 to $13.77 per share. (3) The aggregate grant date fair value of TSUs issued for the year ended December 31, 2018 was $4.6 million based on a grant date market price ranging from $9.30 to $11.00 per share. (4) Certain Legacy Amplify departing executives forfeited 298,354 TSUs during the year ended December 31, 2018, in connection with their separation and retirement agreements. (5) 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. (6) The merger ratio used to convert Legacy Amplify TSUs into newly issued TSUs. ( 7 ) 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. ( 8 ) 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.
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, 2017 (Successor) — $ — Granted (2) 395,500 $ 8.14 Forfeited (2,000 ) $ 7.59 Vested — $ — PSUs outstanding at December 31, 2018 393,500 $ 8.14 Granted (3) 17,750 $ 4.06 Forfeited (22,750 ) $ 7.59 Vested — $ — PSUs outstanding at August 5, 2019 388,500 $ 7.98 Ratio to convert PSUs (4) 0.933 Converted PSUs 362,471 PSUs outstanding on August 6, 2019 (5) 362,471 $ 2.11 Granted (6) 17,500 $ 2.87 Forfeited (74,078 ) $ 2.11 Vested — $ — PSUs outstanding at December 31, 2019 305,893 $ 2.15 (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 year ended December 31, 2018 was $3.2 million based on a calculated fair value price ranging from $5.88 to $9.87 per share. (3) 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. (4) The merger ratio used to convert Legacy Amplify PSUs into newly issued Company PSUs. ( 5 ) 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. ( 6 ) 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.
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, 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 Share price targets $ 12.50 $ 15.00 $ 17.50 Risk-free interest rate: Awards Issued on May 14, 2018 2.68 % 2.68 % 2.68 % Awards Issued on July 1, 2018 2.61 % 2.61 % 2.61 % Awards Issued on August 1, 2018 2.76 % 2.76 % 2.76 % Awards Issued on October 1, 2018 2.88 % 2.88 % 2.88 % Awards Issued on November 1, 2018 2.89 % 2.89 % 2.89 % Dividend yield — — — Expected volatility: Awards Issued on May 14, 2018 50.0 % 50.0 % 50.0 % Awards Issued on July 1, 2018 50.0 % 50.0 % 50.0 % Awards Issued on August 1, 2018 55.0 % 55.0 % 55.0 % Awards Issued on October 1, 2018 53.0 % 53.0 % 53.0 % Awards Issued on November 1, 2018 54.0 % 54.0 % 54.0 % Calculated fair value per PSU: Awards Issued on May 14, 2018 $ 9.71 $ 8.52 $ 7.48 Awards Issued on July 1, 2018 $ 9.87 $ 8.72 $ 7.68 Awards Issued on August 1, 2018 $ 9.79 $ 8.66 $ 7.65 Awards Issued on October 1, 2018 $ 8.54 $ 7.57 $ 6.66 Awards Issued on November 1, 2018 $ 7.65 $ 6.72 $ 5.88

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2019
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 as of December 31, 2019. December 31, 2019 (In thousands) Right-of-use asset $ 4,406 Lease liabilities: Current lease liability 1,712 Long-term lease liability 2,720 Total lease liability $ 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 2020 $ 1,603 $ 688 $ 2,291 2021 1,631 536 2,167 2022 140 59 199 2023 and thereafter — — — Total lease payments $ 3,374 $ 1,283 $ 4,657 Less: interest $ 177 $ 48 $ 225 Present value of lease liabilities $ 3,197 $ 1,235 $ 4,432
Schedule of Future Contractual Payment for Operating Leases	The following is a schedule of the Company’s future contractual payment for operating leases prepared in accordance with accounting standards prior to the adoption of ASC 842, as of December 31, 2018 (in thousands): Payment or Settlement Due by Period Operating leases Total 2019 2020 2021 2022 2023 Thereafter Operating leases $ 11,846 $ 5,893 $ 2,072 $ 2,109 $ 337 $ 205 $ 1,230
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 were as follow as of December 31, 2019: December 31, 2019 Weighted average remaining lease term (years): Office leases 1.50 Vehicles 0.44 Office equipment 0.08 Weighted average discount rate: Office leases 3.63 % Vehicles 0.84 % Office equipment 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, 2019
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, 2019 2018 Accrued lease operating expense $ 11,794 $ 10,469 Accrued capital expenditures 5,515 4,349 Accrued general and administrative expense 3,126 4,393 Operating lease liability 1,712 — Asset retirement obligations 623 477 Accrued ad valorem tax 520 729 Accrued interest payable 36 2,476 Other 32 262 Accrued liabilities $ 23,358 $ 23,155
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, 2019 2018 Cash and cash equivalents $ — $ 49,704 Restricted cash 325 325 Total cash, cash equivalents and restricted cash $ 325 $ 50,029
Summary of Supplemental Cash Flows	Supplemental cash flow for the periods presented (in thousands): Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 Supplemental cash flows: Cash paid for interest, net of amounts capitalized $ 15,937 $ 17,083 $ 12,109 $ 6,598 Cash paid for reorganization items, net 1,057 2,399 7,943 11,999 Noncash investing and financing activities: Increase (decrease) in capital expenditures in payables and accrued liabilities 2,143 (156 ) (1,080 ) 3,173 Asset retirement obligation removal related to divestitures — (15,702 ) — — 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, 2019
Commitments And Contingencies Disclosure [Abstract]
Purchase Commitments Under the Contracts	At December 31, 2019, we had a CO 2 2 2 Payment or Settlement Due by Period Purchase commitment Total 2020 2021 2022 2023 2024 Thereafter CO 2 $ 4,365 $ 4,365 $ — $ — $ — $ — $ — At December 31, 2019, we had a long-term minimum volume commitment with a third party associated with a certain portion of our properties located in Oklahoma and East Texas. The table below outlines the payment commitments associated with this minimum volume commitment (in thousands): Payment or Settlement Due by Period Minimum volume commitment Total 2020 2021 2022 2023 2024 Thereafter Midstream services $ 11,781 $ 3,967 $ 3,788 $ 3,746 $ 280 $ — $ —

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Components of Income Tax Expense (Benefit)	The components of income tax benefit (expense) are as follows: Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 (In thousands) (In thousands) Current taxes: Federal $ — $ — $ 4 $ — State 50 — (34 ) 17 Total current income tax benefit (expense) 50 — (30 ) 17 Deferred taxes: Federal — — 1,933 71 State — — 273 3 Total deferred income tax benefit (expense) — — 2,206 74 Total income tax benefit (expense) $ 50 $ — $ 2,176 $ 91
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 2019, 21% in 2018 and 35% in 2017 as follows: Successor Predecessor For the For the Period from Period from Year Ended Year Ended May 5, 2017 January 1, 2017 December 31, December 31, through through 2019 2018 December 31, 2017 May 4, 2017 (In thousands) (In thousands) Expected tax benefit (expense) at federal statutory rate $ 7,402 $ 11,468 $ 310 $ 5,764 State income tax benefit (expense), net of federal benefit 946 1,108 240 30 Non-deductible expenses (3,659 ) 1,328 (187 ) — Changes in valuation allowances (4,332 ) (14,194 ) 24,767 — Remeasurement of federal deferred tax assets due rate change — — (22,958 ) — Pass-through entities (1) — — — (5,686 ) Non-cash compensation (367 ) — — — Other 60 290 4 (17 ) Total income tax benefit (expense) $ 50 $ — $ 2,176 $ 91 (1) MEMP, a publicly traded partnership with qualifying income, was a pass-through entity for federal income tax purposes.
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, 2019 2018 Deferred income tax assets: Property, Plant & Equipment $ 37,075 $ 2,208 Net operating loss carryforward 141,534 19,085 Disallowed interest expense 10,627 5,748 Accrued liabilities 1,431 1,387 Other 4,234 307 Total deferred income tax assets: 194,901 28,735 Valuation allowance (189,941 ) (23,934 ) Net deferred income tax assets 4,960 4,801 Deferred income tax liabilities: Derivatives $ 2,767 $ 4,801 Other 2,193 — Total deferred income tax liabilities 4,960 4,801 Net deferred income tax liabilities $ — $ —

Quarterly Financial Informati_2

Quarterly Financial Information (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data	The following tables present selected quarterly financial data for the periods indicated. Earnings per share/unit are computed independently for each of the quarters presented and the sum of the quarterly earnings per share/unit may not necessarily equal the total for the year. For the year ended December 31, 2019 First Second Third Fourth Quarter Quarter Quarter Quarter (In thousands, except per share amounts) Revenues $ 65,155 $ 59,532 $ 72,959 $ 77,929 Operating income (loss) (27,251 ) 23,527 14,807 (23,054 ) Net income (loss) (31,477 ) 18,641 5,157 (27,518 ) Net income (loss) attributable to Successor (31,477 ) 18,641 5,157 (27,518 ) Net income (loss) available to common stockholders (31,477 ) 17,913 5,029 (27,518 ) Basic and diluted earnings per share $ (1.42 ) $ 0.80 $ 0.15 $ (0.71 ) For the year ended December 31, 2018 First Second Third Fourth Quarter Quarter Quarter Quarter (In thousands, except per share/unit amounts) Revenues $ 87,932 $ 90,988 $ 85,522 $ 75,702 Operating income (loss) 9,529 (18,226 ) 3,206 87,014 Net income (loss) 3,239 (25,279 ) (2,598 ) 79,247 Net income (loss) attributable to Successor 3,239 (25,279 ) (2,598 ) 79,247 Net income (loss) available to common stockholders 3,156 (25,279 ) (2,598 ) 75,727 Basic and diluted earnings per share 0.13 (1.01 ) (0.10 ) 3.06

Supplemental Oil and Gas Info_2

Supplemental Oil and Gas Information (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2019
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, 2019 2018 (In thousands) Evaluated oil and natural gas properties $ 797,005 $ 598,331 Support equipment and facilities 140,023 108,760 Accumulated depletion, depreciation, and amortization (136,747 ) (82,389 ) Total $ 800,281 $ 624,702
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: Successor Predecessor Period from For the For the May 5, 2017 Period from Year Ended Year Ended through January 1, December 31, December 31, December 31, 2017 through 2019 2018 2017 May 4, 2017 (In thousands) (In thousands) Property acquisition costs, proved $ 150,871 $ — $ — $ — Property acquisition costs, unproved 7,674 — — — Exploration — — — — Development 71,460 42,878 51,925 9,573 Total $ 230,005 $ 42,878 $ 51,925 $ 9,573
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: 2019 2018 2017 Oil ($/Bbl): WTI (1) $ 55.69 $ 65.56 $ 51.34 NGL ($/Bbl): WTI (1) $ 55.69 $ 65.56 $ 51.34 Natural Gas ($/MMbtu): Henry Hub (2) $ 2.58 $ 3.10 $ 2.98 (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, 2019 Oil Gas NGLs Total (MBbls) (MMcf) (MBbls) (MBoe) Proved developed and undeveloped reserves: Beginning of year 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 year 70,772 377,869 29,252 163,002 Proved developed reserves: Beginning of year 54,147 232,110 17,324 110,156 End of year 53,476 320,731 23,646 130,577 Proved undeveloped reserves: Beginning of year 15,477 61,849 4,248 30,033 End of year 17,296 57,138 5,606 32,425 For the Year Ended December 31, 2018 (Successor) Oil Gas NGLs Total (MBbls) (MMcf) (MBbls) (MBoe) Proved developed and undeveloped reserves: Beginning of period 72,004 406,558 25,189 164,953 Extensions and discoveries 1,207 2,910 231 1,923 Production (3,335 ) (29,176 ) (1,496 ) (9,694 ) Sale of minerals in place (159 ) (56,328 ) (1,469 ) (11,016 ) Revision of previous estimates (93 ) (30,005 ) (883 ) (5,977 ) End of period 69,624 293,959 21,572 140,189 Proved developed reserves: Beginning of period 50,014 299,481 17,982 117,910 End of period 54,147 232,110 17,324 110,156 Proved undeveloped reserves: Beginning of period 21,990 107,077 7,207 47,043 End of period 15,477 61,849 4,248 30,033 For the period from May 5, 2017 through December 31, 2017 (Successor) Oil Gas NGLs Total (MBbls) (MMcf) (MBbls) (MBoe) Proved developed and undeveloped reserves: Beginning of period 80,960 419,472 30,572 181,444 Extensions and discoveries 121 4,900 261 1,199 Production (2,380 ) (21,885 ) (1,114 ) (7,142 ) Revision of previous estimates (6,697 ) 4,071 (4,530 ) (10,548 ) End of period 72,004 406,558 25,189 164,953 Proved developed reserves: Beginning of period 57,803 297,101 21,963 129,283 End of period 50,014 299,481 17,982 117,910 Proved undeveloped reserves: Beginning of period 23,157 122,371 8,609 52,161 End of period 21,990 107,077 7,207 47,043 For the period from January 1, 2017 through May 4, 2017 (Predecessor) Oil Gas NGLs Total (MBbls) (MMcf) (MBbls) (MBoe) Proved developed and undeveloped reserves: Beginning of year 65,741 371,016 25,184 152,761 Extensions and discoveries 53 45 8 69 Production (1,204 ) (12,411 ) (616 ) (3,890 ) Revision of previous estimates 16,370 60,822 5,996 32,504 End of year 80,960 419,472 30,572 181,444 Proved developed reserves: Beginning of year 45,536 280,035 18,923 111,132 End of year 57,803 297,101 21,963 129,283 Proved undeveloped reserves: Beginning of year 20,205 90,981 6,261 41,630 End of year 23,157 122,371 8,609 52,161
Standardized Measure of Discounted Future Net Cash Flows	The standardized measure of discounted future net cash flows is as follows: Successor Predecessor Period from For the For the May 5, 2017 Period from Year Ended Year Ended through January 1, December 31, December 31, December 31, 2017 through 2019 2018 2017 May 4, 2017 (In thousands) (In thousands) Future cash inflows $ 5,146,288 $ 6,000,268 $ 5,149,623 $ 5,246,487 Future production costs (2,917,262 ) (3,280,778 ) (2,982,035 ) (3,275,952 ) Future development costs (567,423 ) (474,413 ) (530,133 ) (492,610 ) Future income tax expense — — — — Future net cash flows for estimated timing of cash flows 1,661,603 2,245,077 1,637,455 1,477,925 10% annual discount for estimated timing of cash flows (745,042 ) (1,132,048 ) (869,784 ) (786,836 ) Standardized measure of discounted future net cash flows $ 916,561 $ 1,113,029 $ 767,671 $ 691,089
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 three year period ended December 31, 2019: Successor Predecessor Period from For the For the May 5, 2017 Period from Year Ended Year Ended through January 1, December 31, December 31, December 31, 2017 through 2019 2018 2017 May 4, 2017 (In thousands) (In thousands) Beginning of year $ 1,113,029 $ 767,671 $ 691,089 $ 395,841 Sale of oil and natural gas produced, net of production costs (113,545 ) (181,841 ) (100,946 ) (57,420 ) Purchase of minerals in place 408,370 — — — Sale of minerals in place — (29,036 ) — — Extensions and discoveries 5,334 27,157 7,187 1,320 Changes in prices and costs (623,592 ) 507,888 161,106 306,375 Previously estimated development costs incurred 84,341 73,761 61,851 9,227 Net changes in future development costs 110,892 24,396 (31,438 ) (55,333 ) Revisions of previous quantities (183,300 ) (86,812 ) (27,060 ) 99,591 Accretion of discount 92,998 51,769 46,072 13,195 Change in production rates and other 22,034 (41,924 ) (40,190 ) (21,707 ) End of year $ 916,561 $ 1,113,029 $ 767,671 $ 691,089

Organization and Basis of Pre_4

Organization and Basis of Presentation - Additional Information (Detail)	Aug. 06, 2019shares	Dec. 31, 2019Segmentshares
Consolidation And Basis Of Presentation [Line Items]
Number of reportable business segments | Segment		1
Legacy Amplify [Member]
Consolidation And Basis Of Presentation [Line Items]
Number of common stock share for each share | shares	0.933	0.933

Organization and Basis of Pre_5

Organization and Basis of Presentation - Summary of Prior Period Adjustments in Cash Flows (Details) - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Restricted cash		$ 0
Net cash provided by operating activities		94,642	$ 47,283	$ 141,781
Net change in cash and cash equivalents		(21,309)
Cash and cash equivalents	$ 20,140	6,392	$ 0	$ 49,704
Previously Reported [Member]
Restricted cash		7,561
Net cash provided by operating activities		102,203
Net change in cash and cash equivalents		(13,748)
Cash and cash equivalents		6,392
Adjustment Effect [Member]
Restricted cash		(7,561)
Net cash provided by operating activities		(7,561)
Net change in cash and cash equivalents		(7,561)
Cash and cash equivalents		$ 0
Predecessor [Member]
Restricted cash	0
Net cash provided by operating activities	125,498
Net change in cash and cash equivalents	12,328
Cash and cash equivalents	27,701
Predecessor [Member] | Previously Reported [Member]
Restricted cash	(7,561)
Net cash provided by operating activities	117,937
Net change in cash and cash equivalents	4,767
Cash and cash equivalents	20,140
Predecessor [Member] | Adjustment Effect [Member]
Restricted cash	7,561
Net cash provided by operating activities	7,561
Net change in cash and cash equivalents	7,561
Cash and cash equivalents	$ 7,561

Emergence from Voluntary Reor_2

Emergence from Voluntary Reorganization under Chapter 11 - Additional Information (Detail) - USD ($)	May 04, 2017	Jun. 30, 2019	Dec. 31, 2017	Dec. 31, 2018	Dec. 31, 2019
Reorganizations [Line Items]
Common stock, par value				$ 0.0001	$ 0.01
Warrant issued during period				2,173,913	9,153,522
Plan Of Reorganization
Reorganizations [Line Items]
Percentage of new common shares issued to predecessor	2.00%
Aggregate cash amount to predecessor	$ 1,300,000
Plan Of Reorganization | Management Incentive Plan [Member]
Reorganizations [Line Items]
Aggregate shares of common stock available for grants	2,322,404
Noteholder Plan Support Agreement [Member]
Reorganizations [Line Items]
Percentage of new common shares issued	98.00%
Unsecured noteholders to receive pro rata share of cash distribution	$ 24,600,000
Credit Facility [Member] | Plan Of Reorganization
Reorganizations [Line Items]
Revolving credit facility	$ 1,000,000,000
Warrants [Member]
Reorganizations [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
Common Stock [Member]
Reorganizations [Line Items]
Stock issued during period	25,000,000	0	0	0
Common stock, par value	$ 0.0001

Fresh Start Accounting - Additi

Fresh Start Accounting - Additional Information (Detail) - USD ($)	May 04, 2017	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Fresh Start Adjustment [Line Items]
Enterprise value	$ 800,000,000	$ 800,000,000
Repayment of predecessor's revolving credit facility			$ 63,000,000	$ 134,000,000	$ 397,000,000
Fresh Start Adjustments [Member]
Fresh Start Adjustment [Line Items]
Decrease in asset retirement obligations	62,900,000
Predecessor [Member]
Fresh Start Adjustment [Line Items]
Repayment of predecessor's revolving credit facility		98,252,000
Predecessor [Member] | Reorganization Adjustments [Member]
Fresh Start Adjustment [Line Items]
Repayment of predecessor's revolving credit facility	24,800,000
Reclassification of borrowings under the emergence credit facility to long-term debt	430,000,000
Maximum [Member]
Fresh Start Adjustment [Line Items]
Percentage of voting shares to be received by voting share holders				50.00%
Enterprise value	$ 900,000,000	$ 900,000,000
Maximum [Member] | Predecessor [Member]
Fresh Start Adjustment [Line Items]
Percentage of voting shares to be received by voting share holders	50.00%	50.00%
Minimum [Member]
Fresh Start Adjustment [Line Items]
Enterprise value	$ 700,000,000	$ 700,000,000

Fresh Start Accounting - Reconc

Fresh Start Accounting - Reconciliation of the Enterprise Value to the Reorganization Value (Detail) $ in Thousands	May 04, 2017USD ($)
Reorganizations [Abstract]
Enterprise value	$ 800,000
Plus: Cash and cash equivalents	20,140
Plus: Other working capital liabilities	63,817
Plus: Other long-term liabilities	97,470
Reorganization value of Successor assets	$ 981,427

Fresh Start Accounting - Applic

Fresh Start Accounting - Application of Fresh Start Accounting to Balance Sheet (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	May 04, 2017
Current assets:
Cash and cash equivalents	$ 0	$ 49,704	$ 6,392	$ 20,140
Restricted cash	325	325		7,411
Accounts receivable	33,145	29,514		33,560
Short-term derivative instruments	5,879	18,813		51,329
Prepaid expenses and other current assets	13,238	7,241		10,904
Total current assets	52,587	105,597		123,344
Property and equipment, net				657,336
Long-term derivative instruments	6,364	2,469		33,800
Restricted investments	4,622	94,467		156,443
Other long-term assets	5,837	6,129		10,504
Total assets	877,539	836,843		981,427
Current liabilities:
Accounts payable	8,310	2,345		2,890
Revenues payable	29,167	24,779		22,747
Accrued liabilities	23,358	23,155		38,180
Current portion of long-term debt				0
Total current liabilities	61,088	50,418		63,817
Liabilities subject to compromise				0
Long-term debt	285,000	294,000		430,000
Asset retirement obligations	90,466	75,867	99,460	95,186
Deferred tax liabilities	0	0		2,206
Other long-term liabilities	3,753	0		78
Total liabilities	443,332	420,285		591,287
Commitments and contingencies (see Note 18)				0
Stockholders' equity:
Predecessor common units				0
Successor warrants	4,790	4,788		4,788
Successor common stock	209	3		3
Additional paid-in capital	424,399	355,872		385,349
Total stockholders' equity	434,207	416,558	$ 393,933	390,140
Total liabilities and equity	$ 877,539	$ 836,843		981,427
Reorganization Adjustments [Member]
Current assets:
Cash and cash equivalents				(62,910)
Restricted cash				7,411
Accounts receivable				0
Short-term derivative instruments				0
Prepaid expenses and other current assets				675
Total current assets				(54,824)
Property and equipment, net				0
Long-term derivative instruments				0
Restricted investments				0
Other long-term assets				8,575
Total assets				(46,249)
Current liabilities:
Accounts payable				1,389
Revenues payable				0
Accrued liabilities				2,939
Current portion of long-term debt				(454,799)
Total current liabilities				(450,471)
Liabilities subject to compromise				(1,162,437)
Long-term debt				430,000
Asset retirement obligations				0
Deferred tax liabilities				0
Other long-term liabilities				0
Total liabilities				(1,182,908)
Commitments and contingencies (see Note 18)				0
Stockholders' equity:
Predecessor common units				(80,601)
Successor warrants				4,788
Successor common stock				3
Additional paid-in capital				1,212,469
Total stockholders'/ partners' equity				1,136,659
Total liabilities and equity				(46,249)
Fresh Start Adjustments [Member]
Current assets:
Cash and cash equivalents				0
Restricted cash				0
Accounts receivable				0
Short-term derivative instruments				0
Prepaid expenses and other current assets				0
Total current assets				0
Property and equipment, net				(894,164)
Long-term derivative instruments				0
Restricted investments				0
Other long-term assets				0
Total assets				(894,164)
Current liabilities:
Accounts payable				0
Revenues payable				0
Accrued liabilities				(1,713)
Current portion of long-term debt				0
Total current liabilities				(1,713)
Liabilities subject to compromise				0
Long-term debt				0
Asset retirement obligations				(62,928)
Deferred tax liabilities				0
Other long-term liabilities				(2,403)
Total liabilities				(67,044)
Commitments and contingencies (see Note 18)				0
Stockholders' equity:
Predecessor common units				0
Successor warrants				0
Successor common stock				0
Additional paid-in capital				(827,120)
Total stockholders'/ partners' equity				(827,120)
Total liabilities and equity				(894,164)
Predecessor [Member]
Current assets:
Cash and cash equivalents				27,701
Property and equipment, net				1,551,500
Current liabilities:
Asset retirement obligations				95,186
Predecessor [Member] | Balances Prior to Reorganization and Fresh Start Adjustments [Member]
Current assets:
Cash and cash equivalents				83,050
Restricted cash				0
Accounts receivable				33,560
Short-term derivative instruments				51,329
Prepaid expenses and other current assets				10,229
Total current assets				178,168
Property and equipment, net				1,551,500
Long-term derivative instruments				33,800
Restricted investments				156,443
Other long-term assets				1,929
Total assets				1,921,840
Current liabilities:
Accounts payable				1,501
Revenues payable				22,747
Accrued liabilities				36,954
Current portion of long-term debt				454,799
Total current liabilities				516,001
Liabilities subject to compromise				1,162,437
Long-term debt				0
Asset retirement obligations				158,114
Deferred tax liabilities				2,206
Other long-term liabilities				2,481
Total liabilities				1,841,239
Commitments and contingencies (see Note 18)				0
Stockholders' equity:
Predecessor common units				80,601
Successor warrants				0
Successor common stock				0
Additional paid-in capital				0
Total stockholders'/ partners' equity				80,601
Total liabilities and equity				1,921,840
Predecessor [Member] | Reorganization Adjustments [Member]
Current liabilities:
Liabilities subject to compromise				$ (1,162,437)

Fresh Start Accounting - Summar

Fresh Start Accounting - Summary of Changes in Cash and Cash Equivalents (Details) - USD ($) $ in Thousands		May 04, 2017	Dec. 31, 2017
Changes in cash and cash equivalents			$ (21,309)
Reorganization Adjustments [Member]
Payment on the Predecessor's revolving credit facility		$ (24,799)
Payment to holders of the Notes	[1]	(16,446)
Payment of fees related to Emergence Credit Facility		(8,575)
Funding of the professional fees escrow account		(7,411)
Payment of professional fees		(4,295)
Other		(1,384)
Changes in cash and cash equivalents		$ (62,910)
[1]	The total cash settlement to the holders of the Notes was approximately $24.6 million, of which $16.4 million was paid upon emergence and $8.2 million was paid post-emergence and is reflected in accrued liabilities in the above condensed consolidated balance sheet.

Fresh Start Accounting - Summ_2

Fresh Start Accounting - Summary of Changes in Cash and Cash Equivalents (Parenthetical) (Details) - Reorganization Adjustments [Member] $ in Thousands	May 04, 2017USD ($)
Total cash settlement to the holders of the notes	$ 16,446	[1]
Paid Upon Emergence [Member]
Total cash settlement to the holders of the notes	16,400
Paid Post-emergence [Member] | Accrued Liabilities [Member]
Total cash settlement to the holders of the notes	8,200
Notes [Member]
Total cash settlement to the holders of the notes	$ 24,600
[1]	The total cash settlement to the holders of the Notes was approximately $24.6 million, of which $16.4 million was paid upon emergence and $8.2 million was paid post-emergence and is reflected in accrued liabilities in the above condensed consolidated balance sheet.

Fresh Start Accounting - Summ_3

Fresh Start Accounting - Summary of Net Increase in Accrued liabilities (Details) - Reorganization Adjustments [Member] $ in Thousands	May 04, 2017USD ($)
Net Increase in Accrued Liabilities [Abstract]
Recognition of liability for settlement with holders of the Notes	$ 8,193
Payment of professional fees	(4,295)
Recognition of contribution from management	(1,500)
Recognition of settlement with Predecessor common unitholders	1,250
Other	(709)
Net increase in accrued liabilities due to reorganization items	$ 2,939

Fresh Start Accounting - Schedu

Fresh Start Accounting - Schedule of Settlement of Liabilities Subject to Compromise and Resulting Net Gain (Detail) - USD ($) $ in Thousands	May 04, 2017	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Fresh Start Adjustment [Line Items]
Total liabilities subject to compromise of Predecessor	$ 0	$ 0
Gain on settlement of liabilities subject to compromise			$ 0	$ 0	$ 0
Predecessor [Member]
Fresh Start Adjustment [Line Items]
Gain on settlement of liabilities subject to compromise		758,764
Reorganization Adjustments [Member]
Fresh Start Adjustment [Line Items]
Total liabilities subject to compromise of Predecessor	1,162,437	1,162,437
Recognition of payables for general unsecured claims	(1,389)
Payment to holders of the Notes	(24,639)
Issuance of common stock to holders of the Notes	(377,645)
Gain on settlement of liabilities subject to compromise	758,764
Reorganization Adjustments [Member] | Predecessor [Member]
Fresh Start Adjustment [Line Items]
Accounts payable	1,389	1,389
Accrued interest payable	49,796	49,796
Debt	1,111,252	1,111,252
Total liabilities subject to compromise of Predecessor	$ 1,162,437	$ 1,162,437

Fresh Start Accounting - Sche_2

Fresh Start Accounting - Schedule of Net Increase in Stockholders'/Partners' Equity (Detail) - USD ($) $ in Thousands	May 04, 2017	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Fresh Start Adjustment [Line Items]
Recognition on gain on settlement of liabilities subject to compromise			$ 0	$ 0	$ 0
Par value of common stock		$ (377,645)
Par value of common stock	$ 3	3		$ 209	$ 3
Predecessor [Member]
Fresh Start Adjustment [Line Items]
Recognition on gain on settlement of liabilities subject to compromise		758,764
Reorganization Adjustments [Member]
Fresh Start Adjustment [Line Items]
Issuance of common stock	377,645
Recognition on gain on settlement of liabilities subject to compromise	758,764
Recognition of contribution from management	1,500
Par value of common stock	(3)
Change in Successor additional paid-in capital	1,212,469	1,212,469
Par value of common stock	3	3
Net increase in capital accounts	1,136,659
Reorganization Adjustments [Member] | Predecessor [Member]
Fresh Start Adjustment [Line Items]
Issuance of common stock	7,707
Cancellation of the Predecessor's units issued and outstanding	80,601
Recognition of issuance of common stock to Predecessor common unitholders	(7,707)
Recognition of issuance of warrants to Predecessor common unitholders	(4,788)
Recognition of settlement with Predecessor common unitholders	(1,250)
Issuance of warrants to Predecessor common unitholders	4,788
Predecessor units issued and outstanding	$ (80,601)	$ (80,601)

Fresh Start Accounting - Sche_3

Fresh Start Accounting - Schedule of Fresh Start Adjustments to Property and Equipment, Net (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018	May 04, 2017
Property and equipment, at cost:
Oil and natural gas properties, successful efforts method	$ 797,005	$ 598,331	$ 657,336
Support equipment and facilities	140,023	108,760
Other	8,045	6,625	6,007
Accumulated depreciation, depletion and impairment	$ (141,350)	$ (85,535)	0
Property and equipment, net			657,336
Predecessor [Member]
Property and equipment, at cost:
Oil and natural gas properties, successful efforts method			3,339,020
Other			15,420
Accumulated depreciation, depletion and impairment			(1,787,520)
Property and equipment, net			1,551,500
Support Equipment and Facilities [Member]
Property and equipment, at cost:
Support equipment and facilities			97,580
Support Equipment and Facilities [Member] | Predecessor [Member]
Property and equipment, at cost:
Support equipment and facilities			199,463
Fresh Start Adjustments [Member]
Property and equipment, at cost:
Oil and natural gas properties, successful efforts method			(2,681,684)
Other			(9,413)
Accumulated depreciation, depletion and impairment			1,787,520
Property and equipment, net			(894,164)
Fresh Start Adjustments [Member] | Support Equipment and Facilities [Member]
Property and equipment, at cost:
Support equipment and facilities			(101,883)
Proved Oil and Natural Gas Properties [Member]
Property and equipment, at cost:
Oil and natural gas properties, successful efforts method			509,061
Proved Oil and Natural Gas Properties [Member] | Predecessor [Member]
Property and equipment, at cost:
Oil and natural gas properties, successful efforts method			3,124,137
Proved Oil and Natural Gas Properties [Member] | Fresh Start Adjustments [Member]
Property and equipment, at cost:
Oil and natural gas properties, successful efforts method			(2,615,076)
Unproved Oil and Natural Gas Properties [Member]
Property and equipment, at cost:
Oil and natural gas properties, successful efforts method			44,688
Unproved Oil and Natural Gas Properties [Member] | Predecessor [Member]
Property and equipment, at cost:
Oil and natural gas properties, successful efforts method			0
Unproved Oil and Natural Gas Properties [Member] | Fresh Start Adjustments [Member]
Property and equipment, at cost:
Oil and natural gas properties, successful efforts method			$ 44,688

Fresh Start Accounting - Sche_4

Fresh Start Accounting - Schedule of Reorganization Items, net (Detail) - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Fresh Start Adjustment [Line Items]
Gain on settlement of liabilities subject to compromise		$ 0	$ 0	$ 0
Fresh start valuation adjustments		0	0	0
Professional fees		(724)	(430)	(864)
Other		(395)	(627)	(1,283)
Reorganization items, net		$ (1,119)	$ (1,057)	$ (2,147)
Predecessor [Member]
Fresh Start Adjustment [Line Items]
Gain on settlement of liabilities subject to compromise	$ 758,764
Fresh start valuation adjustments	(827,120)
Professional fees	(19,824)
Other	(594)
Reorganization items, net	$ (88,774)

Summary of Significant Accoun_3

Summary of Significant Accounting Policies - Additional Information (Detail) - USD ($)	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Summary Of Significant Accounting Policies [Line Items]
Allowance for doubtful accounts			$ 1,500,000	$ 1,200,000
Capitalized exploratory drilling costs pending evaluation			0	0
Amortization expense including write-off of debt issuance costs		$ 2,100,000	1,200,000	2,500,000
Impairment expense for proved/unproved properties		0	2,246,000	0
Capitalized interest		400,000	$ 200,000	$ 500,000
Chance of tax benefit likely to be realized			greater than 50%
Federal corporate tax rate			21.00%	21.00%	35.00%
Tax cuts and jobs act of 2017, limitations on NOLs percentage of taxable income			80.00%		80.00%
Customer Concentration Risk [Member] | Revenues [Member]
Summary Of Significant Accounting Policies [Line Items]
Percentage of total revenue			10.00%
Predecessor [Member]
Summary Of Significant Accounting Policies [Line Items]
Amortization expense including write-off of debt issuance costs	$ 0
Impairment expense for proved/unproved properties	0
Capitalized interest	0
Proved Developed And Producing Oil And Gas Properties
Summary Of Significant Accounting Policies [Line Items]
Impairment expense for proved/unproved properties		$ 0	$ 0	$ 0
Proved Developed And Producing Oil And Gas Properties | Predecessor [Member]
Summary Of Significant Accounting Policies [Line Items]
Impairment expense for proved/unproved properties	$ 0
Unproved Oil and Natural Gas Properties [Member]
Summary Of Significant Accounting Policies [Line Items]
Impairment expense for unproved leasehold costs			$ 2,200,000
Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Percentage of voting shares to be received by voting share holders			50.00%
Maximum [Member] | Predecessor [Member]
Summary Of Significant Accounting Policies [Line Items]
Percentage of voting shares to be received by voting share holders	50.00%
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
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

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Major Customers (Detail) - Customer Concentration Risk [Member] - Revenues [Member]	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
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%	27.00%
Sinclair Oil & Gas Company [Member]
Significant Accounting Policies [Line Items]
Total Reported Revenues		19.00%	21.00%	21.00%
BP America Production Company [Member]
Significant Accounting Policies [Line Items]
Total Reported Revenues		10.00%	13.00%	0.00%
CIMA Energy [Member]
Significant Accounting Policies [Line Items]
Total Reported Revenues		11.00%	0.00%	10.00%
Predecessor [Member] | Phillips 66 [Member]
Significant Accounting Policies [Line Items]
Total Reported Revenues	19.00%
Predecessor [Member] | Sinclair Oil & Gas Company [Member]
Significant Accounting Policies [Line Items]
Total Reported Revenues	20.00%
Predecessor [Member] | BP America Production Company [Member]
Significant Accounting Policies [Line Items]
Total Reported Revenues	10.00%
Predecessor [Member] | CIMA Energy [Member]
Significant Accounting Policies [Line Items]
Total Reported Revenues	0.00%

Revenue - Summary of Revenues D

Revenue - Summary of Revenues Disaggregated (Detail) - USD ($) $ in Thousands	3 Months Ended								8 Months Ended	12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Revenues:
Total revenues	$ 77,929	$ 72,959	$ 59,532	$ 65,155	$ 75,702	$ 85,522	$ 90,988	$ 87,932	$ 205,479	$ 275,575	$ 340,144
Oil and Natural Gas Sales [Member]
Revenues:
Total revenues									$ 205,176	274,607	339,840
Oil [Member]
Revenues:
Total revenues										192,944	209,066
NGLs [Member]
Revenues:
Total revenues										22,347	42,463
Natural Gas [Member]
Revenues:
Total revenues										$ 59,316	$ 88,311

Revenue - Additional Informatio

Revenue - Additional Information (Detail) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Revenue From Contract With Customer [Abstract]
Accounts receivable attributable to revenue contracts with customers	$ 31.9	$ 25

Acquisitions and Divestitures -

Acquisitions and Divestitures - Acquisition and Divestiture Related Expenses (Detail) - General and Administrative Expense [Member] - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Business Acquisition [Line Items]
Business Acquisition and Divestiture, Related Expenses		$ 609	$ 17,305	$ 205
Predecessor [Member]
Business Acquisition [Line Items]
Business Acquisition and Divestiture, Related Expenses	$ 0

Acquisitions and Divestitures_2

Acquisitions and Divestitures - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Thousands	May 05, 2019	May 30, 2018	Dec. 31, 2019	Dec. 31, 2018	Sep. 30, 2019	Jan. 01, 2019	Dec. 31, 2017	May 04, 2017
Business Acquisition And Divestiture [Line Items]
Common stock, par value			$ 0.01	$ 0.0001
Measurement period adjustment amount of increase asset retirement obligations liability			$ 91,089	$ 76,344			$ 100,173	$ 96,127
Operating lease - long term right-of-use asset			4,406	0
Operating Liabilities			4,432
Accounts payable			8,310	2,345				$ 2,890
Disposal Group Not Discontinued Operation [Member]
Business Acquisition And Divestiture [Line Items]
(Gain) loss on sale of properties				3,600
Disposal Group Not Discontinued Operation [Member] | South Texas Divestiture [Member]
Business Acquisition And Divestiture [Line Items]
Total net proceeds from divestitures		$ 17,100
Proceeds from divestitures		18,600
Accounts payable		500
Legal and advisor expenses		$ 900		$ 0
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_3

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_4

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_5

Acquisitions and Divestitures - Summary of Unaudited Pro Forma Financial Information (Detail) - Legacy Amplify, Midstates and Midstates Holdings, Inc. [Member] - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Business Acquisition [Line Items]
Revenues	$ 336,326	$ 545,226
Net income (loss)	$ (22,926)	$ 146,845
Earnings per share:
Basic	$ (0.78)	$ 3.18
Diluted	$ (0.78)	$ 3.18

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, 2019	Dec. 31, 2018
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	$ 19,104
Total liabilities	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
Total liabilities	0
Significant Other Observable Inputs (Level 2) [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	19,104
Total liabilities	7,419
Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	0
Total liabilities	0
Commodity derivatives [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total assets	18,509	$ 25,515
Total liabilities	6,861	4,372
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	18,509	25,515
Total liabilities	6,861	4,372
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	595
Total liabilities	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
Total liabilities	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	595
Total liabilities	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
Total liabilities	$ 0

Fair Value Measurements of Fi_4

Fair Value Measurements of Financial Instruments - Additional Information (Detail) - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Assets And Liabilities Carrying Value And Fair Value [Line Items]
Impairment expense of unproved properties			$ 2,200
Impairment expense of proved oil and natural gas properties		$ 0	$ 2,246	$ 0
Predecessor [Member]
Assets And Liabilities Carrying Value And Fair Value [Line Items]
Impairment expense of proved oil and natural gas properties	$ 0

Risk Management and Derivativ_3

Risk Management and Derivative Instruments - Additional Information (Detail) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2017	Dec. 31, 2019
Derivative Instruments Gain Loss [Line Items]
Conditional rights of set-off under ISDA Master Agreement reduce the maximum amount of loss due to credit risk		$ 12.6
Commodity derivatives [Member]
Derivative Instruments Gain Loss [Line Items]
Cash settlement receipt	$ 94.1

Risk Management and Derivativ_4

Risk Management and Derivative Instruments - Open Commodity Positions (Detail)	12 Months Ended
	Dec. 31, 2019MMBTU$ / MMBTU$ / bblbbl
Natural Gas Derivative Contracts Fixed Price Swap 2022 [Member]
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	300,000
Weighted-average fixed price | $ / MMBTU	2.46
Natural Gas Derivative Two Way Collars Contracts 2022 [Member]
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	0
Weighted-average floor price	0
Weighted-average ceiling price	0
Crude Oil Derivative Contracts Fixed Price Swap 2022 [Member]
Derivative [Line Items]
Average monthly volume (Bbls) | bbl	30,000
Weighted-average fixed price	55.32
Natural Gas Derivative Three Way Collars Contracts 2022 [Member]
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	0
Weighted-average floor price	0
Weighted-average ceiling price	0
Weighted-average sub-floor price	0
Crude Oil Derivative Two Way Collars Contracts 2022 [Member]
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	0
Weighted-average floor price	0
Weighted-average ceiling price	0
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	0
Weighted-average floor price	0
Weighted-average ceiling price	0
Weighted-average sub-floor price	0
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	487,500
Weighted-average fixed price | $ / MMBTU	2.48
Natural Gas Derivative Two Way Collars Contracts 2021 [Member]
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	162,500
Weighted-average floor price	2.58
Weighted-average ceiling price	2.84
Natural Gas Derivative Three Way Collars Contracts 2021 [Member]
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	0
Weighted-average floor price	0
Weighted-average ceiling price	0
Weighted-average sub-floor price	0
Crude Oil Derivative Three Way Collars Contracts 2021 [Member]
Derivative [Line Items]
Average monthly volume (Bbls) | bbl	0
Weighted-average floor price	0
Weighted-average ceiling price	0
Weighted-average sub-floor price	0
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	116,250
Weighted-average fixed price	56.05
Crude Oil Derivative Two Way Collars Contracts 2021 [Member]
Derivative [Line Items]
Average monthly volume (Bbls) | bbl	0
Weighted-average floor price	0
Weighted-average ceiling price	0
NGL Derivative Contracts Fixed Price Swap 2021 [Member]
Derivative [Line Items]
Average monthly volume (Bbls) | bbl	22,800
Weighted-average fixed price	24.25
Natural Gas Derivative Contracts Fixed Price Swap 2020 [Member]
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	600,000
Weighted-average fixed price | $ / MMBTU	2.53
Natural Gas Derivative Two Way Collars Contracts 2020 [Member]
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	520,000
Weighted-average floor price	2.64
Weighted-average ceiling price	2.96
Natural Gas Derivative Three Way Collars Contracts 2020 [Member]
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	76,000
Weighted-average floor price	2.65
Weighted-average ceiling price	3.45
Weighted-average sub-floor price	2.15
Crude Oil Derivative Three Way Collars Contracts 2020 [Member]
Derivative [Line Items]
Average monthly volume (Bbls) | bbl	30,500
Weighted-average floor price	50
Weighted-average ceiling price	65.75
Weighted-average sub-floor price	40
Natural Gas P E P L Basis Swaps Two Thousand Twenty
Derivative [Line Items]
Average monthly volume (MMBtu) | MMBTU	600,000
Weighted-average spread | $ / MMBTU	(0.46)
Crude Oil Derivative Contracts Fixed Price Swap 2020 [Member]
Derivative [Line Items]
Average monthly volume (Bbls) | bbl	213,050
Weighted-average fixed price	57.28
Crude Oil Derivative Two Way Collars Contracts 2020 [Member]
Derivative [Line Items]
Average monthly volume (Bbls) | bbl	14,300
Weighted-average floor price	55
Weighted-average ceiling price	62.10
NGL Derivative Contracts Fixed Price Swap 2020 [Member]
Derivative [Line Items]
Average monthly volume (Bbls) | bbl	65,425
Weighted-average fixed price	25.20

Risk Management and Derivativ_5

Risk Management and Derivative Instruments - Interest Rate Swap Open Positions (Detail)	12 Months Ended
	Dec. 31, 2019USD ($)
Interest Rate Swap Open Position 2020 [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 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, 2019	Dec. 31, 2018	May 04, 2017
Derivative Instruments and Hedges, Assets [Abstract]
Asset Derivatives, Net recorded fair value	$ 5,879	$ 18,813	$ 51,329
Asset Derivatives, Net recorded fair value	6,364	2,469	$ 33,800
Liability Derivatives, Net recorded fair value	253	139
Liability Derivatives, Net recorded fair value	305	0
Short-Term Derivative Instruments [Member]
Derivative Instruments and Hedges, Assets [Abstract]
Asset Derivatives, Gross fair value	11,766	21,217
Asset Derivatives, Netting arrangements	(5,887)	(2,404)
Asset Derivatives, Net recorded fair value	5,879	18,813
Liability Derivatives, Gross fair value	6,140	2,543
Liability Derivatives, Netting arrangements	(5,887)	(2,404)
Liability Derivatives, Net recorded fair value	253	139
Short-Term Derivative Instruments [Member] | Commodity derivatives [Member]
Derivative Instruments and Hedges, Assets [Abstract]
Asset Derivatives, Gross fair value	11,518	21,217
Liability Derivatives, Gross fair value	5,887	2,543
Short-Term Derivative Instruments [Member] | Interest Rate Swaps [Member]
Derivative Instruments and Hedges, Assets [Abstract]
Asset Derivatives, Gross fair value	248	0
Liability Derivatives, Gross fair value	253	0
Long-Term Derivative Instruments [Member]
Derivative Instruments and Hedges, Assets [Abstract]
Asset Derivatives, Gross fair value	7,337	4,298
Asset Derivatives, Netting arrangements	(973)	(1,829)
Asset Derivatives, Net recorded fair value	6,364	2,469
Liability Derivatives, Gross fair value	1,278	1,829
Liability Derivatives, Netting arrangements	(973)	(1,829)
Liability Derivatives, Net recorded fair value	305	0
Long-Term Derivative Instruments [Member] | Commodity derivatives [Member]
Derivative Instruments and Hedges, Assets [Abstract]
Asset Derivatives, Gross fair value	6,990	4,298
Liability Derivatives, Gross fair value	973	1,829
Long-Term Derivative Instruments [Member] | Interest Rate Swaps [Member]
Derivative Instruments and Hedges, Assets [Abstract]
Asset Derivatives, Gross fair value	347	0
Liability Derivatives, Gross fair value	$ 305	$ 0

Risk Management and Derivativ_7

Risk Management and Derivative Instruments - Unrealized and Realized Gains and Losses Related to Derivative Instruments (Detail) - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Derivative Instruments Gain Loss [Line Items]
(Gain) loss on commodity derivative instruments		$ 31,609	$ 6,700	$ (8,155)
Interest expense, net		(15,936)	(16,855)	(21,923)
Predecessor [Member]
Derivative Instruments Gain Loss [Line Items]
(Gain) loss on commodity derivative instruments	$ (23,076)
Interest expense, net	(10,243)
Commodity derivatives [Member]
Derivative Instruments Gain Loss [Line Items]
(Gain) loss on commodity derivative instruments		31,609	6,700	(8,155)
Commodity derivatives [Member] | Predecessor [Member]
Derivative Instruments Gain Loss [Line Items]
(Gain) loss on commodity derivative instruments	(23,076)
Interest rate derivatives [Member]
Derivative Instruments Gain Loss [Line Items]
Interest expense, net		$ 0	$ (224)	$ 0
Interest rate derivatives [Member] | Predecessor [Member]
Derivative Instruments Gain Loss [Line Items]
Interest expense, net	$ 0

Asset Retirement Obligations -

Asset Retirement Obligations - Summary of Changes in Asset Retirement Obligations (Detail) - USD ($) $ in Thousands		4 Months Ended	8 Months Ended	12 Months Ended
		May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Asset Retirement Obligations [Line Items]
Asset retirement obligations at beginning of period			$ 96,127	$ 76,344	$ 100,173
Liabilities added from acquisition or drilling	[1]		191	9,497	89
Liabilities removed upon sale of wells			0	0	(15,702)
Liabilities settled			(633)	(259)	(767)
Accretion expense			4,384	5,559	5,711
Revision of estimates	[2]		104	(52)	(13,160)
Asset retirement obligation at end of period		$ 96,127	100,173	91,089	76,344
Fresh start adjustment	[3]		0	0	0
Less: Current Portion			713	623	477
Asset retirement obligations - long-term portion		95,186	99,460	$ 90,466	$ 75,867
Predecessor [Member]
Asset Retirement Obligations [Line Items]
Asset retirement obligations at beginning of period		155,702	$ 159,055
Liabilities added from acquisition or drilling	[1]	6
Liabilities removed upon sale of wells		0
Liabilities settled		(164)
Accretion expense		3,407
Revision of estimates	[2]	104
Asset retirement obligation at end of period		159,055
Fresh start adjustment	[3]	(62,928)
Less: Current Portion		941
Asset retirement obligations - long-term portion		$ 95,186
[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.
[2]	The decrease in revision of estimates for the year ended December 31, 2018 is primarily due to receiving new cost estimates from third parties regarding the estimated plugging and abandonment costs.
[3]	As a result of the application of fresh start accounting, the Successor recorded its asset retirement obligation at fair value as of the Effective Date.

Restricted Investments - Restri

Restricted Investments - Restricted Investment Balances (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018	May 04, 2017
Schedule Of Investments [Line Items]
Restricted investments	$ 4,622	$ 94,467	$ 156,443
BOEM platform abandonment [Member]
Schedule Of Investments [Line Items]
Restricted investments	313	90,162
SPBPC Collateral Contractual pipeline and surface facilities abandonment [Member]
Schedule Of Investments [Line Items]
Restricted investments	$ 4,309	$ 4,305

Restricted Investments - Additi

Restricted Investments - Additional Information (Detail) - USD ($) $ in Millions	Jun. 24, 2019	Nov. 20, 2018	Oct. 05, 2018
Investments Debt And Equity Securities [Abstract]
Proceeds from Beta Decommissioning Trust account	$ 90	$ 1	$ 61.5

Debt - Consolidated Debt Obliga

Debt - Consolidated Debt Obligations (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018	May 04, 2017
Line Of Credit Facility [Line Items]
Long-term debt	$ 285,000	$ 294,000	$ 430,000
Credit Facility [Member]
Line Of Credit Facility [Line Items]
Aggregate principal outstanding	$ 285,000	$ 294,000

Debt - Credit Facility - Additi

Debt - Credit Facility - Additional Information (Detail) - USD ($)

Jun. 24, 2019

Dec. 21, 2018

Nov. 20, 2018

Nov. 02, 2018

Oct. 05, 2018

May 04, 2017

May 04, 2017

Dec. 31, 2017

Dec. 31, 2019

Dec. 31, 2018

Nov. 08, 2019

Nov. 07, 2019

Aug. 06, 2019

Aug. 05, 2019

Line Of Credit Facility [Line Items]

Proceeds from Beta Decommissioning Trust account

$ 90,000,000

$ 1,000,000

$ 61,500,000

Gain (loss) on extinguishment of debt

$ 3,000,000

$ 0

$ 0

$ (3,034,000)

Repayment of predecessor's revolving credit facility

$ 63,000,000

134,000,000

$ 397,000,000

Letters of credit outstanding

1,700,000

Predecessor [Member]

Line Of Credit Facility [Line Items]

Gain (loss) on extinguishment of debt

$ 0

Repayment of predecessor's revolving credit facility

$ 98,252,000

Predecessor $2.0 billion revolving credit facility, variable-rate, due March 2018 [Member]

Line Of Credit Facility [Line Items]

Revolving credit facility, maximum borrowing capacity

2,000,000,000

Predecessor $2.0 billion revolving credit facility, variable-rate, due March 2018 [Member] | Predecessor [Member]

Line Of Credit Facility [Line Items]

Repayment of predecessor's revolving credit facility

$ 24,800,000

New Credit Agreement [Member]

Line Of Credit Facility [Line Items]

Extended hedging requirements

Extend the date by which OLLC was required to show compliance with certain minimum hedging requirements set forth in the New Credit Agreement from December 31, 2018 to February 28, 2019

Extended date after the closing date

60 days

Credit Facility [Member]

Line Of Credit Facility [Line Items]

Borrowing base

$ 450,000,000

$ 450,000,000

$ 530,000,000

$ 530,000,000

$ 425,000,000

Maturity date

Nov. 2, 2023

LIBOR rate interest period

1 month

Credit Facility [Member] | Amplify Acquisitionco Inc

Line Of Credit Facility [Line Items]

Pledge and security interest

100.00%

Credit Facility [Member] | Minimum [Member]

Line Of Credit Facility [Line Items]

Current ratio

1.00%

Credit Facility [Member] | Minimum [Member] | Oil and Gas Properties [Member]

Line Of Credit Facility [Line Items]

Secured by percentage of mortgages

85.00%

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%

Credit Facility [Member] | Maximum [Member]

Line Of Credit Facility [Line Items]

Total debt to EBITDAX

4.00%

Credit Facility [Member] | Federal Funds Effective Rate [Member]

Line Of Credit Facility [Line Items]

Debt instrument, basis spread on variable rate

0.50%

Credit Facility [Member] | LIBOR [Member]

Line Of Credit Facility [Line Items]

Debt instrument, basis spread on variable rate

1.00%

Credit Facility [Member] | LIBOR [Member] | Minimum [Member]

Line Of Credit Facility [Line Items]

Debt instrument, basis spread on variable rate

2.00%

Credit Facility [Member] | LIBOR [Member] | Maximum [Member]

Line Of Credit Facility [Line Items]

Debt instrument, basis spread on variable rate

3.00%

Credit Facility [Member] | Base Rate [Member] | Minimum [Member]

Line Of Credit Facility [Line Items]

Debt instrument, basis spread on variable rate

1.00%

Credit Facility [Member] | Base Rate [Member] | Maximum [Member]

Line Of Credit Facility [Line Items]

Debt instrument, basis spread on variable rate

2.00%

Credit Facility

Line Of Credit Facility [Line Items]

Gain (loss) on extinguishment of debt

$ 3,000,000

Debt - Summary of Weighted-Aver

Debt - Summary of Weighted-Average Interest Rates Paid on Variable-Rate Debt Obligations (Detail)	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Credit Facility [Member]
Line Of Credit Facility [Line Items]
Revolving credit facility, weighted-average interest rates			4.76%	4.96%
Emergence Credit Facility [Member]
Line Of Credit Facility [Line Items]
Revolving credit facility, weighted-average interest rates		5.08%		5.75%
Predecessor's Revolving Credit Facility [Member] | Predecessor [Member]
Line Of Credit Facility [Line Items]
Revolving credit facility, weighted-average interest rates	4.18%

Debt - Senior Notes - Additiona

Debt - Senior Notes - Additional Information (Detail) - USD ($) $ in Millions	May 04, 2017	May 04, 2017	Dec. 31, 2019	Jul. 17, 2014	Oct. 10, 2013	May 23, 2013	Apr. 17, 2013
Noteholder Plan Support Agreement [Member]
Debt Instrument [Line Items]
Unsecured noteholders to receive pro rata share of cash distribution	$ 24.6
Predecessor [Member] | Noteholder Plan Support Agreement [Member]
Debt Instrument [Line Items]
Unsecured noteholders to receive pro rata share of cash distribution	$ 24.6
Senior Notes [Member] | Predecessor [Member]
Debt Instrument [Line Items]
Unrecorded contractual interest		$ 24.2
2021 Senior Notes [Member]
Debt Instrument [Line Items]
Senior notes			7.625%
Maturity date			May 1, 2021
2021 Senior Notes [Member] | Private Placement of Debt [Member]
Debt Instrument [Line Items]
Face amount of senior notes at time of issuance					$ 300	$ 100	$ 300
2022 Senior Notes [Member]
Debt Instrument [Line Items]
Maturity date			Aug. 1, 2022
2022 Senior Notes [Member] | Private Placement of Debt [Member]
Debt Instrument [Line Items]
Face amount of senior notes at time of issuance				$ 500
Senior notes				6.875%
Senior notes issued at par				98.485%

Debt - Unamortized Deferred Fin

Debt - Unamortized Deferred Financing Costs - Additional Information (Detail) - USD ($) $ in Thousands	Nov. 02, 2018	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Line Of Credit Facility [Line Items]
Gain (loss) on extinguishment of debt	$ 3,000	$ 0	$ 0	$ (3,034)
Successor Credit Facility [Member]
Line Of Credit Facility [Line Items]
Unamortized deferred financing costs			$ 4,700

Equity (Deficit)- Additional In

Equity (Deficit)- Additional Information (Detail) - USD ($)	Dec. 18, 2019	Nov. 05, 2019	Sep. 18, 2019	Aug. 06, 2019	Dec. 19, 2018	Nov. 19, 2018	May 04, 2017	Dec. 31, 2019	Jun. 30, 2019	Dec. 31, 2017	Dec. 31, 2018	Aug. 05, 2019	Dec. 21, 2018
Equity And Distributions [Line Items]
Common stock, shares authorized								250,000,000			300,000,000
Common stock, par value								$ 0.01			$ 0.0001
Common stock, shares issued							25,000,000	37,566,540			22,181,881
Common stock, shares outstanding							25,000,000	37,566,540			22,181,881
Treasury shares outstanding								0
Warrants outstanding								9,153,522			2,173,913
Warrant expiry date												Apr. 21, 2020
Stock repurchase authorized amount				$ 25,000,000
Shares repurchased during period								4,195,247
Total cost of share repurchase								$ 24,900,000
Average price per share repurchased								$ 6.28
Dividends declared per share		$ 0.20		$ 0.20
Dividends paid	$ 7,700,000		$ 8,200,000
Dividend declared date		Nov. 5, 2019		Aug. 6, 2019
Dividend payable record date		Dec. 4, 2019		Sep. 4, 2019
Predecessor [Member]
Equity And Distributions [Line Items]
Percentage of new common shares issued to predecessor							2.00%
Aggregate cash amount to predecessor							$ 1,300,000
Common Stock [Member]
Equity And Distributions [Line Items]
Common stock, par value							$ 0.0001
Stock issued during period							25,000,000		0	0	0
Common stock, shares outstanding							25,000,000	37,566,540	22,305,256	25,000,000	22,181,881	22,334,010
Stock repurchase authorized amount													$ 25,000,000
Shares repurchased during period									169,400
Average common stock price									$ 7.35
Total cost of share repurchase									$ 1,300,000
Common Stock [Member] | Tender Offer [Member]
Equity And Distributions [Line Items]
Shares repurchased during period					2,916,667
Total cost of share repurchase					$ 35,000,000
Tender offer commencement date											Nov. 19, 2018
Tender offer to purchase common stock shares						2,916,667
Price of common stock					$ 12
Warrants [Member]
Equity And Distributions [Line Items]
Warrant issued during period							2,173,913
Warrant life period							5 years
Percentage of common shares to be issued upon exercise of warrants							8.00%
Warrant exercise price							$ 42.60
Midstates [Member]
Equity And Distributions [Line Items]
Treasury shares outstanding												205,861
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

Equity (Deficit) - Summary of C

Equity (Deficit) - Summary of Changes in Number of Outstanding Common Units and Shares of Common Stock (Detail) - shares		May 04, 2017	Aug. 05, 2019	May 04, 2017	Dec. 31, 2019	Jun. 30, 2019	Aug. 05, 2019	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Summary of Changes in Number of Outstanding Units/Shares [Line Item]
Beginning balance						22,181,881	22,181,881	25,000,000	22,181,881
Ending balance		25,000,000		25,000,000	37,566,540				37,566,540	22,181,881
Common Shares/Units [Member]
Summary of Changes in Number of Outstanding Units/Shares [Line Item]
Beginning balance			22,305,256		22,334,010	22,181,881	22,181,881	25,000,000	22,181,881	25,000,000
Issuance of common stock		25,000,000				0		0		0
Restricted stock units vested			38,181		682,552	412,938				163,700
Repurchase of common shares			(9,427)		(31,697)	(120,163)				(65,152)
Restricted Common Stock Repurchased and Retired Under Tender Offer										(2,916,667)
Ending balance		25,000,000	22,334,010	25,000,000	37,566,540	22,305,256	22,334,010	25,000,000	37,566,540	22,181,881
Common stock repurchased and retired under share repurchase program					(4,195,247)	(169,400)
Ratio to convert Amplify shares					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)
Predecessor [Member] | Limited Partners Common Units [Member]
Summary of Changes in Number of Outstanding Units/Shares [Line Item]
Beginning balance				83,827,920				83,800,287
Beginning balance								0
Restricted common units issued				0
Restricted common units/shares forfeited				(12,952)
Restricted common units/shares repurchased	[1]			(14,681)
Cancellation of Predecessor common units				(83,800,287)
Ending balance		83,800,287		83,800,287
Ending balance		0		0
[1]	Restricted common units were generally net-settled by our Predecessor unitholders to cover the required withholding tax upon vesting. The Predecessor unitholders surrendered units with value equivalent to the employees’ minimum statutory obligation for the applicable income and other employment taxes. Total payments remitted for the employees’ tax obligations to the appropriate taxing authorities were less than approximately $0.1 million for the period from January 1, 2017 through May 4, 2017. These net-settlements had the effect of unit repurchases by the Company as they reduced the number of units that would have otherwise been outstanding as a result of the vesting and did not represent an expense to the Company.

Equity (Deficit) - Summary of_2

Equity (Deficit) - Summary of Changes in Number of Outstanding Common Units and Shares of Common Stock (Parenthetical) (Detail) $ in Millions	4 Months Ended
	May 04, 2017USD ($)
Limited Partners Common Units [Member] | Maximum [Member] | Predecessor [Member]
Summary of Changes in Number of Outstanding Units/Shares [Line Item]
Withholding tax withheld and paid related to vesting of restricted common units	$ 0.1

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_Unit - Calcu

Earnings per Share/Unit - Calculation of Earnings (Loss) per Share/Unit (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands		3 Months Ended								4 Months Ended	8 Months Ended	12 Months Ended
		Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Earnings Per Share/Unit [Line Items]
Net income (loss) attributable to Successor/Predecessor		$ (27,518)	$ 5,157	$ 18,641	$ (31,477)	$ 79,247	$ (2,598)	$ (25,279)	$ 3,239		$ 1,286	$ (35,197)	$ 54,609
Less: Net income (loss) allocated to participating restricted stockholders											35	0	2,426
Basic and diluted earnings available to common stockholders/limited partners											$ 1,251	$ (35,197)	$ 52,183
Common shares/units:
Common shares/units outstanding — basic											25,000	29,301	24,959
Common shares/units outstanding — diluted											25,000	29,301	24,959
Net earnings per share/unit:
Basic											$ 0.05	$ (1.20)	$ 2.09
Diluted											$ 0.05	$ (1.20)	$ 2.09
Predecessor [Member]
Earnings Per Share/Unit [Line Items]
Net income (loss) attributable to Successor/Predecessor										$ (90,955)
Less: Net income (loss) allocated to participating restricted stockholders										0
Basic and diluted earnings available to common stockholders/limited partners										$ (90,955)
Common shares/units:
Common shares/units outstanding — basic										83,807
Common shares/units outstanding — diluted										83,807
Net earnings per share/unit:
Basic										$ (1.09)
Diluted										$ (1.09)
Stock Options [Member]
Net earnings per share/unit:
Antidilutive stock options or warrants	[1]										517
Warrants [Member]
Net earnings per share/unit:
Antidilutive stock options or warrants	[2]										2,174	9,154	2,174
[1]	Amount represents options to purchase common stock that are excluded from the diluted net earnings per share calculations because of their antidilutive effect.
[2]	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)

Aug. 06, 2019$ / sharesshares

Aug. 05, 2019shares

Mar. 07, 2019shares

Apr. 27, 2018shares

May 01, 2017USD ($)

Jun. 30, 2016

May 04, 2017USD ($)shares

Dec. 31, 2019USD ($)$ / sharesshares

Aug. 05, 2019shares

Dec. 31, 2017USD ($)shares

Dec. 31, 2019USD ($)Installment$ / sharesshares

Dec. 31, 2018USD ($)$ / sharesshares

Dec. 31, 2017shares

Dec. 31, 2016USD ($)shares

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Common stock, par value | $ / shares

$ 0.01

$ 0.01

$ 0.0001

Number of vesting annually equal installments | Installment

3

Vesting date description

Emergence Awards generally vest annually in three equal installments on each of the first three anniversaries of the Effective Date, subject to the grantee’s continued employment through each such vesting date.

Share-based compensation (see Note 14) | $

$ 2,516,000

$ 4,530,000

$ 4,374,000

Predecessor [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Share-based compensation (see Note 14) | $

$ 3,667,000

TSUs [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Unrecognized compensation cost | $

$ 800,000

$ 800,000

Weighted-average period of unrecognized compensation cost

1 year 9 months 18 days

PSUs [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Unrecognized compensation cost | $

$ 100,000

$ 100,000

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%

Phantom Units [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Unvested restricted stock option awards

0

0

Phantom Units [Member] | Predecessor [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Unvested restricted stock option awards

5,692,745

5,980,693

Shares vested

155,601

Shares granted

0

Shares cancelled

132,347

Phantom Units [Member] | Maximum [Member] | Predecessor [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Phantom units settled in cash | $

$ 100,000

Phantom Units [Member] | Non-Employee Directors [Member] | Predecessor [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Vesting period date

2016-01

Phantom Units [Member] | First Anniversary Market-Vesting Date [Member] | Non-Employee Directors [Member] | Maximum [Member] | Predecessor [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Phantom units settled in cash | $

$ 100,000

Phantom Units [Member] | First Anniversary Market-Vesting Date [Member] | Certain Employee [Member] | Predecessor [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Stock units vesting percentage

33.33%

Phantom Units [Member] | Second Anniversary Market-Vesting Date [Member] | Certain Employee [Member] | Predecessor [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Stock units vesting percentage

33.33%

Phantom Units [Member] | Third Anniversary Of Grant Date [Member] | Certain Employee [Member] | Predecessor [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Stock units vesting percentage

33.33%

Restricted Stock Options [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Unvested restricted stock option awards

298,354

Expected life (in years)

2 years

2 years

6 years

Grant-date fair value compensation | $

$ 500,000

Modified-date grant fair value compensation cost recognized | $

$ 300,000

Midstates Restricted Stock Units [Member] | Market Condition Awards [Member] | Non-Employee Director [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Unvested restricted stock option awards

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]

Unvested restricted stock option awards

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]

Unvested restricted stock option awards

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)

2,004,934

2,004,934

Unvested restricted stock option awards

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]

Number of common stock share for each share

0.933

Shares available for future distribution (in shares)

104,503

104,503

Weighted-average period of unrecognized compensation cost

2 years 2 months 12 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.

Unvested restricted stock option awards

30,616

[1]

32,814

0

16,157

32,814

16,341

16,157

39,604

16,341

Shares vested

14,459

49,723

0

5,445

Shares granted

0

42,933

[2]

16,341

[3]

28,708

[4]

Shares cancelled

0

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 | $

$ 100,000

$ 100,000

MEMP [Member] | Predecessor Restricted Common Units [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Number of common units for awards authorized

2,142,221

2,142,221

Long Term Incentive Plan [Member] | Predecessor [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Share-based compensation (see Note 14) | $

$ 2,300,000

Legacy Amplify [Member]

Share Based Compensation Arrangement By Share Based Payment Award [Line Items]

Common stock, par value | $ / shares

$ 0.0001

Number of common stock share for each share

0.933

0.933

Shares available for future distribution (in shares)

626,404

626,404

[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. The merger ratio used to convert Legacy Amplify Board RSUs into newly issued Company Board RSUs. 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 in 2017 was $0.2 million based on grant date market price of $13.77 per share.

[4]

The aggregate grant date fair value of Board RSUs issued in 2018 was $0.3 million based on a grant date market price of $10.45 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, 2017		Dec. 31, 2019	Dec. 31, 2018
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		614,754		598,024	682,792
Granted, Number of Units				17,500	[1]		300,517	[2]	173,070	[3]		437,000	[4]
Forfeited, Number of Units				(38,652)			(38,151)		(105,032)			(363,513)	[5]
Vested, Number of Units				(81,723)			(437,834)		0			(158,255)
Outstanding, Number of Units, Ending Balance		394,245	[1]	291,370		291,370	422,556		682,792		291,370	598,024
Merger conversion ratio	[6],[7]	0.933
Converted TSUs		394,245
Outstanding, Weighted-Average Grant Date Fair Value per unit, Beginning balance	[8]	$ 10.87		$ 5.12	[9]	$ 10.87	$ 11.35		$ 13.77		$ 11.35	$ 13.54
Granted, Weighted-Average Grant Date Fair Value per Unit	[8]			6.14			6.80	[2]	12.87	[3]		10.51	[4]
Forfeited, Weighted-Average Grant Date Fair Value per Unit	[8]			5.12			11.13		13.77			13.55	[5]
Vested, Weighted-Average Grant Date Fair Value per Unit	[8]			5.12			8.71		0			13.44
Outstanding, Weighted-Average Grant Date Fair Value per unit, Ending balance	[8]	$ 5.12	[9]	$ 5.18		$ 5.18	$ 10.87		$ 13.54		$ 5.18	$ 11.35
Number of common stock share for each share	[6],[7]	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	[10]	388,500	393,500				393,500	0
Granted, Number of Units				17,500			17,750	[11]				395,500	[12]
Forfeited, Number of Units				(74,078)			(22,750)					(2,000)
Vested, Number of Units				0			0					0
Outstanding, Number of Units, Ending Balance		362,471	[10]	305,893		305,893	388,500		0		305,893	393,500
Merger conversion ratio	[13],[14]	0.933
Converted TSUs		362,471
Outstanding, Weighted-Average Grant Date Fair Value per unit, Beginning balance	[15]	$ 7.98		$ 2.11	[16]	$ 7.98	$ 8.14				$ 8.14	$ 0
Granted, Weighted-Average Grant Date Fair Value per Unit	[15]			2.87			4.06	[11]				8.14	[12]
Forfeited, Weighted-Average Grant Date Fair Value per Unit	[15]			2.11			7.59					7.59
Vested, Weighted-Average Grant Date Fair Value per Unit	[15]			0			0					0
Outstanding, Weighted-Average Grant Date Fair Value per unit, Ending balance	[15]	$ 2.11	[16]	$ 2.15		$ 2.15	$ 7.98		$ 0		$ 2.15	$ 8.14
Number of common stock share for each share	[13],[14]	0.933
[1]	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
[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 aggregate grant date fair value of TSUs issued for the period from May 5, 2017 through December 31, 2017 was $2.2 million based on a grant date market price ranging from $10.00 to $13.77 per share.
[4]	The aggregate grant date fair value of TSUs issued for the year ended December 31, 2018 was $4.6 million based on a grant date market price ranging from $9.30 to $11.00 per share.
[5]	Certain Legacy Amplify departing executives forfeited 298,354 TSUs during the year ended December 31, 2018, in connection with their separation and retirement agreements.
[6]	The merger ratio used to convert Legacy Amplify TSUs into newly issued TSUs.
[7]	This reflects the unvested TSUs converted into newly issued Company’s TSUs at August 6, 2019 at a stock price of $5.12
[8]	Determined by dividing the aggregate grant date fair value of awards by the number of awards issued
[9]	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
[10]	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
[11]	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.
[12]	The aggregate grant date fair value of PSUs issued for the year ended December 31, 2018 was $3.2 million based on a calculated fair value price ranging from $5.88 to $9.87 per share.
[13]	The merger ratio used to convert Legacy Amplify PSUs into newly issued Company PSUs.
[14]	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
[15]	Determined by dividing the aggregate grant date fair value of awards by the number of awards issued.
[16]	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

Equity-based Awards - Summary_2

Equity-based Awards - Summary of Information Regarding Restricted Stock Unit Awards (Parenthetical) (Detail) - USD ($) $ / shares in Units, $ in Millions		5 Months Ended	7 Months Ended	8 Months Ended	12 Months Ended
		Dec. 31, 2019	Aug. 05, 2019	Dec. 31, 2017	Dec. 31, 2018	Aug. 06, 2019		May 04, 2017
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	$ 2	$ 2.2	$ 4.6
Grant Date Market Price		$ 6.14
Unvested awards converted into newly issued TSUs						$ 5.12
TSUs [Member] | Departing Executives [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Forfeited, Number of Units					298,354
TSUs [Member] | Minimum [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Grant Date Market Price			$ 4.48	$ 10	$ 9.30
TSUs [Member] | Maximum [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Grant Date Market Price			8.70	$ 13.77	$ 11
PSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate grant date fair value of restricted stock units issued					$ 3.2
PSUs [Member] | Minimum [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Calculated fair value price		$ 2.38	$ 1.64		$ 5.88	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		$ 3.40	$ 6.76		$ 9.87	2.63
Restricted Stock Units (RSUs) | 2017 Non-Employee Directors Compensation Plan [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate grant date fair value of restricted stock units issued			$ 0.3	$ 0.2	$ 0.3
Grant Date Market Price			$ 6.95	$ 13.77	$ 10.45
Forfeited, Number of Units		0	0	0	0
Unvested awards converted into newly issued TSUs	[1]	$ 5.12	$ 8.35	$ 13.77	$ 11.36	$ 5.12	[2]	$ 0
[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_3

Equity-based Awards - Summary of Fair Value Assumptions (Detail) - PSUs [Member] - $ / shares	Oct. 01, 2019	Jul. 01, 2019	Apr. 01, 2019	Jan. 01, 2019	Nov. 01, 2018	Oct. 01, 2018	Aug. 01, 2018	Jul. 01, 2018	May 14, 2018	Dec. 31, 2019	Dec. 31, 2018
Share Price Target 12.50 [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Share price targets										$ 12.50
Risk-free interest rate	1.50%	1.73%	2.28%	2.44%	2.89%	2.88%	2.76%	2.61%	2.68%
Dividend yield										0.00%	0.00%
Expected volatility	65.00%	57.00%	50.00%	54.00%	54.00%	53.00%	55.00%	50.00%	50.00%
Calculated fair value per PSU	$ 3.40	$ 2.63	$ 4.22	$ 6.76	$ 7.65	$ 8.54	$ 9.79	$ 9.87	$ 9.71
Share Price Target 15.00 [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Share price targets										$ 15
Risk-free interest rate	1.50%	1.73%	2.28%	2.44%	2.89%	2.88%	2.76%	2.61%	2.68%
Dividend yield										0.00%	0.00%
Expected volatility	65.00%	57.00%	50.00%	54.00%	54.00%	53.00%	55.00%	50.00%	50.00%
Calculated fair value per PSU	$ 2.83	$ 2.05	$ 3.43	$ 5.86	$ 6.72	$ 7.57	$ 8.66	$ 8.72	$ 8.52
Share Price Target 17.50 [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Share price targets										$ 17.50
Risk-free interest rate	1.50%	1.73%	2.28%	2.44%	2.89%	2.88%	2.76%	2.61%	2.68%
Dividend yield										0.00%	0.00%
Expected volatility	65.00%	57.00%	50.00%	54.00%	54.00%	53.00%	55.00%	50.00%	50.00%
Calculated fair value per PSU	$ 2.38	$ 1.64	$ 2.80	$ 5.11	$ 5.88	$ 6.66	$ 7.65	$ 7.68	$ 7.48

Equity-based Awards - Summary_4

Equity-based Awards - Summary of Modified-Date Grant Fair Value Estimated Using Black-Scholes Option Pricing Model (Detail) - Restricted Stock Options [Member] - $ / shares	Apr. 27, 2018	Dec. 31, 2018	Dec. 31, 2017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Risk-free interest rate		2.49%	2.06%
Dividend yield		0.00%	0.00%
Expected life (in years)	2 years	2 years	6 years
Expected volatility		50.00%	50.00%
Strike Price		$ 21.58	$ 21.58
Calculated fair value per stock option		$ 0.85	$ 5.01

Equity-based Awards - Summary_5

Equity-based Awards - Summary of Restricted Stock Option Awards (Detail) - Restricted Stock Options [Member] - $ / shares		8 Months Ended	12 Months Ended
		Dec. 31, 2017	Dec. 31, 2018
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Number of Options, Beginning Balance		614,754	517,398
Granted, Number of Options		1,876	0
Forfeited, Number of Options		(99,232)	(161,243)	[1]
Vested, Number of Options		0	(356,155)
Outstanding, Number of Options, Ending Balance		517,398	0
Outstanding, Weighted Average Grant Date Fair Value per Option, Beginning balance	[2]	$ 5.01	$ 5.01
Granted, Weighted-Average Grant Date Fair Value per Option	[2]	5.01	0
Forfeited, Weighted-Average Grant Date Fair Value per Option	[2]	5.01	5.01
Vested, Weighted-Average Grant Date Fair Value per Option	[2]	0	5.01
Outstanding, Weighted Average Grant Date Fair Value per Option, Ending balance	[2]	$ 5.01	$ 0
[1]	In connection with certain grants awarded in 2018 pursuant to the Legacy Amplify MIP, all remaining unvested restricted stock options were forfeited.
[2]	Determined by dividing the aggregate grant date fair value of awards by the number of awards issued.

Equity-based Awards - Summary_6

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, 2017		Dec. 31, 2019	Dec. 31, 2018
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		0		39,604	16,341
Granted, Number of Units				0			42,933	[2]	16,341	[3]		28,708	[4]
Forfeited, Number of Units				0			0		0			0
Vested, Number of Units				(14,459)			(49,723)		0			(5,445)
Outstanding, Number of Units, Ending Balance		30,616	[1]	16,157		16,157	32,814		16,341		16,157	39,604
Number of common stock share for each share		0.933
Converted Board RSUs	[5]	30,616
Outstanding, Weighted-Average Grant Date Fair Value per unit, Beginning balance	[6]	$ 8.35		$ 5.12	[1]	$ 8.35	$ 11.36		$ 0		$ 11.36	$ 13.77
Granted, Weighted-Average Grant Date Fair Value per Unit	[6]			0			6.95	[2]	13.77	[3]		10.45	[4]
Forfeited, Weighted-Average Grant Date Fair Value per Unit	[6]			0			0		0			0
Vested, Weighted-Average Grant Date Fair Value per Unit	[6]			5.12			9.54		0			13.77
Outstanding, Weighted-Average Grant Date Fair Value per unit, Ending balance	[6]	$ 5.12	[1]	$ 5.12		$ 5.12	$ 8.35		$ 13.77		$ 5.12	$ 11.36
[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. The merger ratio used to convert Legacy Amplify Board RSUs into newly issued Company Board RSUs. 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 in 2017 was $0.2 million based on grant date market price of $13.77 per share.
[4]	The aggregate grant date fair value of Board RSUs issued in 2018 was $0.3 million based on a grant date market price of $10.45 per share.
[5]	The merger ratio used to convert Legacy Amplify Board RSUs into newly issued Company Board RSUs.
[6]	Determined by dividing the aggregate grant date fair value of awards by the number of awards issued.

Equity-based Awards - Summary_7

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	Aug. 05, 2019	Dec. 31, 2018	Dec. 31, 2017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate grant date fair value of restricted stock units issued	$ 0.3	$ 0.3	$ 0.2
Grant Date Market Price	$ 6.95	$ 10.45	$ 13.77

Equity-based Awards - Summary_8

Equity-based Awards - Summary of Information Regarding Restricted Common Unit Awards (Detail) - Restricted Common Units [Member] - Predecessor [Member] - $ / shares		4 Months Ended	12 Months Ended
		May 04, 2017	Dec. 31, 2016
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Number of Units, Beginning Balance			432,160
Granted, Number of Units			0
Forfeited, Number of Units			(12,952)
Vested, Number of Units			(43,045)
Cancelled, Number of Units		(376,163)
Outstanding, Number of Units, Ending Balance		0
Outstanding, Weighted-Average Grant Date Fair Value per unit, Beginning balance	[1]		$ 15
Granted, Weighted-Average Grant Date Fair Value per Unit	[1]		0
Forfeited, Weighted-Average Grant Date Fair Value per Unit	[1]		9.51
Vested, Weighted-Average Grant Date Fair Value per Unit	[1]		10.40
Cancelled, Weighted-Average Grant Date Fair Value per Unit	[1]	$ 15.72	$ 0
Outstanding, Weighted-Average Grant Date Fair Value per unit, Ending balance	[1]	$ 0
[1]	Determined by dividing the aggregate grant date fair value of awards by the number of awards issued.

Equity-based Awards - Summary_9

Equity-based Awards - Summary of Information Regarding Predecessor's Phantom Unit Awards (Detail) - Phantom Units [Member] - shares	4 Months Ended	8 Months Ended
	May 04, 2017	Dec. 31, 2017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Number of Units, Beginning Balance
Outstanding, Number of Units, Ending Balance		0
Predecessor [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Number of Units, Beginning Balance	5,980,693	5,692,745
Granted, Number of Units	0
Forfeited, Number of Units	(132,347)
Vested, Number of Units	(155,601)
Cancellation of Predecessor common units		(5,692,745)
Outstanding, Number of Units, Ending Balance	5,692,745

Equity-based Awards - Summar_10

Equity-based Awards - Summary of Amount of Compensation Expense Recognized (Detail) - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)		$ 2,516	$ 3,042	$ 2,777
Predecessor [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)	$ 3,667
TSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)		1,906	1,797	1,445
TSUs [Member] | Predecessor [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)	0
PSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)		0	981	1,404
PSUs [Member] | Predecessor [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)	0
Restricted Stock Options [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)		569	0	(214)
Restricted Stock Options [Member] | Predecessor [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)	0
Board RSUs [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)		41	264	142
Board RSUs [Member] | Predecessor [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)	0
Restricted Common Units [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)		0	0	0
Restricted Common Units [Member] | Predecessor [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)	3,713
Phantom Units [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)		$ 0	$ 0	$ 0
Phantom Units [Member] | Predecessor [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity based compensation expense (benefit)	$ (46)

Leases - Additional Information

Leases - Additional Information (Detail) - USD ($) $ in Thousands	8 Months Ended	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018	Jan. 01, 2019
Lessee Lease Description [Line Items]
Operating lease - long term right-of-use asset		$ 4,406	$ 0
Operating Liabilities		$ 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
Loss on lease	$ 0	$ 4,247	$ 0
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, 2019	Dec. 31, 2018
Leases [Abstract]
Right-of-use asset	$ 4,406	$ 0
Current lease liability	1,712	0
Long-term lease liability	2,720	$ 0
Total lease liability	$ 4,432

Leases - Schedule of Maturity A

Leases - Schedule of Maturity Analysis of Minimum Lease Payment Obligation Under Non-cancellable Operating Leases (Detail) $ in Thousands	Dec. 31, 2019USD ($)
Lessee Lease Description [Line Items]
2020	$ 2,291
2021	2,167
2022	199
2023 and thereafter	0
Total lease payments	4,657
Less: interest	225
Present value of lease liabilities	4,432
Office Leases [Member]
Lessee Lease Description [Line Items]
2020	1,603
2021	1,631
2022	140
2023 and thereafter	0
Total lease payments	3,374
Less: interest	177
Present value of lease liabilities	3,197
Leased Vehicles and Office Equipment [Member]
Lessee Lease Description [Line Items]
2020	688
2021	536
2022	59
2023 and thereafter	0
Total lease payments	1,283
Less: interest	48
Present value of lease liabilities	$ 1,235

Leases - Schedule of Future Con

Leases - Schedule of Future Contractual Payment for Operating Leases (Detail) $ in Thousands	Dec. 31, 2018USD ($)
Leases [Abstract]
Future contractual payment for operating leases, Total	$ 11,846
Future contractual payment for operating leases, 2019	5,893
Future contractual payment for operating leases, 2020	2,072
Future contractual payment for operating leases, 2021	2,109
Future contractual payment for operating leases, 2022	337
Future contractual payment for operating leases, 2023	205
Future contractual payment for operating leases, After 2023	$ 1,230

Leases - Schedule of Weighted A

Leases - Schedule of Weighted Average Remaining Lease Terms and Discount Rate of Operating Leases (Detail)	Dec. 31, 2019
Office Leases [Member]
Lessee Lease Description [Line Items]
Weighted average remaining lease term	1 year 6 months
Weighted average discount rate	3.63%
Vehicles [Member]
Lessee Lease Description [Line Items]
Weighted average remaining lease term	5 months 8 days
Weighted average discount rate	0.84%
Office Equipment [Member]
Lessee Lease Description [Line Items]
Weighted average remaining lease term	29 days
Weighted average discount rate	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, 2019	Dec. 31, 2018	Dec. 31, 2017	May 04, 2017
Accrued Liabilities Current [Abstract]
Accrued lease operating expense	$ 11,794	$ 10,469
Accrued capital expenditures	5,515	4,349
Accrued general and administrative expense	3,126	4,393
Operating lease liability	1,712	0
Asset retirement obligations	623	477	$ 713
Accrued ad valorem tax	520	729
Accrued interest payable	36	2,476
Other	32	262
Accrued liabilities	$ 23,358	$ 23,155		$ 38,180

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, 2019	Dec. 31, 2018	Dec. 31, 2017	May 04, 2017
Cash And Cash Equivalents [Abstract]
Cash and cash equivalents	$ 0	$ 49,704	$ 6,392	$ 20,140
Restricted cash	325	325
Total cash, cash equivalents and restricted cash	$ 325	$ 50,029	$ 6,392	$ 27,701

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	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Supplemental cash flows:
Cash paid for interest, net of amounts capitalized		$ 12,109	$ 15,937	$ 17,083
Cash paid for reorganization items, net		7,943	1,057	2,399
Noncash investing and financing activities:
Increase (decrease) in capital expenditures in payables and accrued liabilities		(1,080)	2,143	(156)
Asset retirement obligation removal related to divestitures		0	0	(15,702)
Assumption of asset retirement obligations related to Merger		0	9,440	0
Assets acquired & liabilities assumed in the Merger:
Accounts receivable		0	14,633	0
Prepaids and other current assets		0	3,229	0
Other non-current assets		0	9,075	0
Oil and natural gas properties		0	149,421	0
Other property and equipment		0	1,694	0
Accounts payable and other current liabilities		0	(24,135)	0
Other non-current liabilities		0	(5,067)	0
Long-term debt		0	(76,559)	0
Issuance of common stock in connection with the Merger		$ 0	$ 91,541	$ 0
Predecessor [Member]
Supplemental cash flows:
Cash paid for interest, net of amounts capitalized	$ 6,598
Cash paid for reorganization items, net	11,999
Noncash investing and financing activities:
Increase (decrease) in capital expenditures in payables and accrued liabilities	3,173
Asset retirement obligation removal related to divestitures	0
Assumption of asset retirement obligations related to Merger	0
Assets acquired & liabilities assumed in the Merger:
Accounts receivable	0
Prepaids and other current assets	0
Other non-current assets	0
Oil and natural gas properties	0
Other property and equipment	0
Accounts payable and other current liabilities	0
Other non-current liabilities	0
Long-term debt	0
Issuance of common stock in connection with the Merger	$ 0

Related Party Transactions - Ad

Related Party Transactions - Additional Information (Detail)	May 04, 2017USD ($)
Maximum [Member]
Related Party Transaction [Line Items]
Amount of related party transaction	$ 120,000

Commitments and Contingencies -

Commitments and Contingencies - Additional Information (Detail)	Jun. 24, 2019USD ($)	Nov. 20, 2018USD ($)	Oct. 05, 2018USD ($)	Oct. 31, 2017USD ($)	May 04, 2017USD ($)	Dec. 31, 2019USD ($)$ / bbl	Dec. 31, 2017USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)$ / bbl	Dec. 31, 2018USD ($)
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			0.25
Sinking fund account maximum value upon which obligation ceases						$ 4,300,000			$ 4,300,000
Proceeds from Beta Decommissioning Trust account	$ 90,000,000	$ 1,000,000	$ 61,500,000
Beta's decommissioning obligations, previously supported by surety bonds						71,300,000			71,300,000
Beta's decommissioning obligations, cash						90,200,000			90,200,000
Beta's decommissioning obligations, full supported by surety bonds						161,300,000			161,300,000
Beta's decommissioning remaining obligations, cash						300,000			300,000
Rent expense							$ 6,300,000		7,500,000	$ 8,600,000
Commitment fee/expense						700,000
Predecessor [Member]
Commitments and Contingencies Additional Textual [Abstract]
Rent expense					$ 3,100,000
Scenario Forecast [Member]
Commitments and Contingencies Additional Textual [Abstract]
Average estimated fee expected per month								$ 100,000
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			$ 4,600,000
Third-Party Midstream Transaction [Member]
Commitments and Contingencies Additional Textual [Abstract]
Proceeds from divestitures				$ 17,000,000

Commitments and Contingencies_2

Commitments and Contingencies - Purchase Commitments Under the Contracts (Detail) $ in Thousands	Dec. 31, 2019USD ($)
CO2 Minimum Purchase Commitment [Member]
Recorded Unconditional Purchase Obligation [Line Items]
Total	$ 4,365
2020	4,365
2021	0
2022	0
2023	0
2024	0
Thereafter	0
Midstream services [Member]
Recorded Unconditional Purchase Obligation [Line Items]
Total	11,781
2020	3,967
2021	3,788
2022	3,746
2023	280
2024	0
Thereafter	$ 0

Income Taxes - Additional Infor

Income Taxes - Additional Information (Details) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Disclosure [Line Items]
Statutory tax rate	21.00%	21.00%	35.00%
Operating loss carryforwards, limitations on use	limitations on net operating losses (NOLs) generated after December 31, 2017, to 80% of taxable income
Tax cuts and jobs act of 2017, limitations on NOLs percentage of taxable income	80.00%		80.00%
Valuation Allowance	$ 189,941,000	$ 23,934,000
Increase to valuation allowance	166,000,000
Unrecognized Tax Benefits	0
United States [Member]
Income Tax Disclosure [Line Items]
Operating Loss carryforwards not subject to expiration	$ 590,600,000
Operating loss carryforwards expiration year	2037
State [Member]
Income Tax Disclosure [Line Items]
Operating Loss carryforwards not subject to expiration	$ 203,900,000
Operating loss carryforwards expiration year	2037
Maximum [Member] | United States [Member]
Income Tax Disclosure [Line Items]
Net operating loss carryforwards	$ 618,000,000
Maximum [Member] | State [Member]
Income Tax Disclosure [Line Items]
Net operating loss carryforwards	$ 238,500,000

Income Taxes - Components of In

Income Taxes - Components of Income Tax Expense (Benefit) (Detail) - USD ($) $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Current taxes:
Federal		$ 4	$ 0	$ 0
State		(34)	50	0
Total current income tax benefit (expense)		(30)	50	0
Deferred taxes:
Federal		1,933	0	0
State		273	0	0
Total deferred income tax benefit (expense)		2,206	0	0
Total income tax benefit (expense)		$ 2,176	$ 50	$ 0
Predecessor [Member]
Current taxes:
Federal	$ 0
State	17
Total current income tax benefit (expense)	17
Deferred taxes:
Federal	71
State	3
Total deferred income tax benefit (expense)	74
Total income tax benefit (expense)	$ 91

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Income Tax Benefit (Provision) (Detail) - USD ($) $ in Thousands		4 Months Ended	8 Months Ended	12 Months Ended
		May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Income Tax Contingency [Line Items]
Expected tax benefit (expense) at federal statutory rate			$ 310	$ 7,402	$ 11,468
State income tax benefit (expense), net of federal benefit			240	946	1,108
Non-deductible expenses			(187)	(3,659)	1,328
Changes in valuation allowances			24,767	(4,332)	(14,194)
Remeasurement of federal deferred tax assets due rate change			(22,958)	0	0
Pass-through entities	[1]		0	0	0
Non-cash compensation			0	(367)	0
Other			4	60	290
Total income tax benefit (expense)			$ 2,176	$ 50	$ 0
Predecessor [Member]
Income Tax Contingency [Line Items]
Expected tax benefit (expense) at federal statutory rate		$ 5,764
State income tax benefit (expense), net of federal benefit		30
Non-deductible expenses		0
Changes in valuation allowances		0
Remeasurement of federal deferred tax assets due rate change		0
Pass-through entities	[1]	(5,686)
Non-cash compensation		0
Other		(17)
Total income tax benefit (expense)		$ 91
[1]	MEMP, a publicly traded partnership with qualifying income, was a pass-through entity for federal income tax purposes.

Income Taxes - Components of Ne

Income Taxes - Components of Net Deferred Income Tax Liabilities (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018	May 04, 2017
Deferred income tax assets:
Property, Plant & Equipment	$ 37,075	$ 2,208
Net operating loss carryforward	141,534	19,085
Disallowed interest expense	10,627	5,748
Accrued liabilities	1,431	1,387
Other	4,234	307
Total deferred income tax assets:	194,901	28,735
Valuation allowance	(189,941)	(23,934)
Net deferred income tax assets	4,960	4,801
Deferred income tax liabilities:
Derivatives	2,767	4,801
Other	2,193	0
Total deferred income tax liabilities	4,960	4,801
Net deferred income tax liabilities	$ 0	$ 0	$ 2,206

Quarterly Financial Informati_3

Quarterly Financial Information (Unaudited) - Quarterly Financial Data (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								8 Months Ended	12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Quarterly Financial Information Disclosure [Abstract]
Revenues	$ 77,929	$ 72,959	$ 59,532	$ 65,155	$ 75,702	$ 85,522	$ 90,988	$ 87,932	$ 205,479	$ 275,575	$ 340,144
Operating income (loss)	(23,054)	14,807	23,527	(27,251)	87,014	3,206	(18,226)	9,529	(816)	(11,971)	81,523
Net income (loss)	(27,518)	5,157	18,641	(31,477)	79,247	(2,598)	(25,279)	3,239	1,286	(35,197)	54,609
Net income (loss) attributable to Successor	(27,518)	5,157	18,641	(31,477)	79,247	(2,598)	(25,279)	3,239	1,286	(35,197)	54,609
Net income (loss) available to common stockholders	$ (27,518)	$ 5,029	$ 17,913	$ (31,477)	$ 75,727	$ (2,598)	$ (25,279)	$ 3,156	$ 1,251	$ (35,197)	$ 52,183
Basic and diluted earnings per share	$ (0.71)	$ 0.15	$ 0.80	$ (1.42)	$ 3.06	$ (0.10)	$ (1.01)	$ 0.13	$ 0.05	$ (1.20)	$ 2.09

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, 2019	Dec. 31, 2018
Extractive Industries [Abstract]
Evaluated oil and natural gas properties	$ 797,005	$ 598,331
Support equipment and facilities	140,023	108,760
Accumulated depletion, depreciation, and amortization	(136,747)	(82,389)
Total	$ 800,281	$ 624,702

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	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Costs Incurred Oil And Gas Property Acquisition Exploration And Development Activities [Line Items]
Property acquisition costs, proved		$ 0	$ 150,871	$ 0
Property acquisition costs, unproved		0	7,674	0
Exploration		0	0	0
Development		51,925	71,460	42,878
Total		$ 51,925	$ 230,005	$ 42,878
Predecessor [Member]
Costs Incurred Oil And Gas Property Acquisition Exploration And Development Activities [Line Items]
Property acquisition costs, proved	$ 0
Property acquisition costs, unproved	0
Exploration	0
Development	9,573
Total	$ 9,573

Supplemental Oil and Gas Info_5

Supplemental Oil and Gas Information (Unaudited) - Additional Information (Detail) - MMBoe	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Supplemental Oil And Gas Reserve Information [Line Items]
Percent of discount factor to proved reserves			10.00%
Increase (reduction) in reserves		(16.5)	(22.8)	(24.7)
Downward price revisions in proved reserve			25.9
Downward revisions due to updated well performance data			12.1
Acquisition of oil and gas properties			69.7
Upward price revisions in proved reserve		2.2		4.6
Downward revisions due to updated well performance data and increase in anticipated development and maintenance cost		12.8		10.6
Extensions and discoveries		1.2		1.9
Divestiture of oil and gas properties				11
Predecessor [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Increase (reduction) in reserves	28.7
Downward revisions due to updated well performance data	1.5
Upward price revisions in proved reserve	34.1

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, 2019$ / MMBTU$ / bbl	Dec. 31, 2018$ / MMBTU$ / bbl	Dec. 31, 2017$ / MMBTU$ / bbl
Oil [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Product prices for reserves	55.69	65.56	51.34
NGL [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Product prices for reserves	55.69	65.56	51.34
Natural Gas [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Product prices for reserves | $ / MMBTU	2.58	3.10	2.98

Supplemental Oil and Gas Info_7

Supplemental Oil and Gas Information (Unaudited) - Schedule of Net Reserves (Detail)	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017MBoebblMMcf	Dec. 31, 2017MBoeMMBoebblMMcf	Dec. 31, 2019MBoebblMMcf	Dec. 31, 2018MBoeMMBoebblMMcf
Supplemental Oil And Gas Reserve Information [Line Items]
Extensions and discoveries | MMBoe		1.2		1.9
Proved Reserves, Total
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, Beginning of year | MBoe		181,444	140,189	164,953
Extensions and discoveries | MBoe		1,199	441	1,923
Purchase of minerals in place | MBoe			69,697
Production | MBoe		(7,142)	(9,256)	(9,694)
Sale of minerals in place | MBoe				(11,016)
Revision of previous estimates | MBoe		(10,548)	(38,069)	(5,977)
Proved developed and undeveloped reserves, End of year | MBoe	181,444	164,953	163,002	140,189
Proved developed reserves, Beginning of year | MBoe		129,283	110,156	117,910
Proved developed reserves, End of year | MBoe	129,283	117,910	130,577	110,156
Proved undeveloped reserves, Beginning of year | MBoe		52,161	30,033	47,043
Proved undeveloped reserves, End of year | MBoe	52,161	47,043	32,425	30,033
Proved Reserves, Total | Predecessor [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, Beginning of year | MBoe	152,761	181,444
Extensions and discoveries | MBoe	69
Production | MBoe	(3,890)
Revision of previous estimates | MBoe	32,504
Proved developed and undeveloped reserves, End of year | MBoe	181,444
Proved developed reserves, Beginning of year | MBoe	111,132	129,283
Proved developed reserves, End of year | MBoe	129,283
Proved undeveloped reserves, Beginning of year | MBoe	41,630	52,161
Proved undeveloped reserves, End of year | MBoe	52,161
Oil [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, Beginning of year		80,960	69,624	72,004
Extensions and discoveries		121	301	1,207
Purchase of minerals in place			17,429
Production		(2,380)	(3,498)	(3,335)
Revision of previous estimates		(6,697)	(13,084)	(93)
Proved developed and undeveloped reserves, End of year	80,960	72,004	70,772	69,624
Proved developed reserves, Beginning of year		57,803	54,147	50,014
Proved developed reserves, End of year	57,803	50,014	53,476	54,147
Proved undeveloped reserves, Beginning of year		23,157	15,477	21,990
Proved undeveloped reserves, End of year	23,157	21,990	17,296	15,477
Sale of minerals in place				(159)
Oil [Member] | Predecessor [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, Beginning of year	65,741	80,960
Extensions and discoveries	53
Production	(1,204)
Revision of previous estimates	16,370
Proved developed and undeveloped reserves, End of year	80,960
Proved developed reserves, Beginning of year	45,536	57,803
Proved developed reserves, End of year	57,803
Proved undeveloped reserves, Beginning of year	20,205	23,157
Proved undeveloped reserves, End of year	23,157
Natural Gas [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, Beginning of year | MMcf		419,472	293,959	406,558
Extensions and discoveries | MMcf		4,900	576	2,910
Purchase of minerals in place | MMcf			202,409
Production | MMcf		(21,885)	(26,489)	(29,176)
Revision of previous estimates | MMcf		4,071	(92,586)	(30,005)
Proved developed and undeveloped reserves, End of year | MMcf	419,472	406,558	377,869	293,959
Proved developed reserves, Beginning of year | MMcf		297,101	232,110	299,481
Proved developed reserves, End of year | MMcf	297,101	299,481	320,731	232,110
Proved undeveloped reserves, Beginning of year | MMcf		122,371	61,849	107,077
Proved undeveloped reserves, End of year | MMcf	122,371	107,077	57,138	61,849
Sale of minerals in place | MMcf				(56,328)
Natural Gas [Member] | Predecessor [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, Beginning of year | MMcf	371,016	419,472
Extensions and discoveries | MMcf	45
Production | MMcf	(12,411)
Revision of previous estimates | MMcf	60,822
Proved developed and undeveloped reserves, End of year | MMcf	419,472
Proved developed reserves, Beginning of year | MMcf	280,035	297,101
Proved developed reserves, End of year | MMcf	297,101
Proved undeveloped reserves, Beginning of year | MMcf	90,981	122,371
Proved undeveloped reserves, End of year | MMcf	122,371
NGLs [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, Beginning of year		30,572	21,572	25,189
Extensions and discoveries		261	44	231
Purchase of minerals in place			18,533
Production		(1,114)	(1,343)	(1,496)
Revision of previous estimates		(4,530)	(9,554)	(883)
Proved developed and undeveloped reserves, End of year	30,572	25,189	29,252	21,572
Proved developed reserves, Beginning of year		21,963	17,324	17,982
Proved developed reserves, End of year	21,963	17,982	23,646	17,324
Proved undeveloped reserves, Beginning of year		8,609	4,248	7,207
Proved undeveloped reserves, End of year	8,609	7,207	5,606	4,248
Sale of minerals in place				(1,469)
NGLs [Member] | Predecessor [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, Beginning of year	25,184	30,572
Extensions and discoveries	8
Production	(616)
Revision of previous estimates	5,996
Proved developed and undeveloped reserves, End of year	30,572
Proved developed reserves, Beginning of year	18,923	21,963
Proved developed reserves, End of year	21,963
Proved undeveloped reserves, Beginning of year	6,261	8,609
Proved undeveloped reserves, End of year	8,609

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, 2019	Dec. 31, 2018	Dec. 31, 2017	May 04, 2017	Dec. 31, 2016
Supplemental Oil And Gas Reserve Information [Line Items]
Future cash inflows	$ 5,146,288	$ 6,000,268	$ 5,149,623
Future production costs	(2,917,262)	(3,280,778)	(2,982,035)
Future development costs	(567,423)	(474,413)	(530,133)
Future income tax expense	0	0	0
Future net cash flows for estimated timing of cash flows	1,661,603	2,245,077	1,637,455
10% annual discount for estimated timing of cash flows	(745,042)	(1,132,048)	(869,784)
Standardized measure of discounted future net cash flows	$ 916,561	$ 1,113,029	$ 767,671	$ 691,089
Predecessor [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Future cash inflows				5,246,487
Future production costs				(3,275,952)
Future development costs				(492,610)
Future income tax expense				0
Future net cash flows for estimated timing of cash flows				1,477,925
10% annual discount for estimated timing of cash flows				(786,836)
Standardized measure of discounted future net cash flows				$ 691,089	$ 395,841

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	4 Months Ended	8 Months Ended	12 Months Ended
	May 04, 2017	Dec. 31, 2017	Dec. 31, 2019	Dec. 31, 2018
Supplemental Oil And Gas Reserve Information [Line Items]
Beginning of year		$ 691,089	$ 1,113,029	$ 767,671
Sale of oil and natural gas produced, net of production costs		(100,946)	(113,545)	(181,841)
Purchase of minerals in place		0	408,370	0
Sale of minerals in place		0	0	(29,036)
Extensions and discoveries		7,187	5,334	27,157
Changes in prices and costs		161,106	(623,592)	507,888
Previously estimated development costs incurred		61,851	84,341	73,761
Net changes in future development costs		(31,438)	110,892	24,396
Revisions of previous quantities		(27,060)	(183,300)	(86,812)
Accretion of discount		46,072	92,998	51,769
Change in production rates and other		(40,190)	22,034	(41,924)
End of year	$ 691,089	767,671	$ 916,561	$ 1,113,029
Predecessor [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Beginning of year	395,841	$ 691,089
Sale of oil and natural gas produced, net of production costs	(57,420)
Purchase of minerals in place	0
Sale of minerals in place	0
Extensions and discoveries	1,320
Changes in prices and costs	306,375
Previously estimated development costs incurred	9,227
Net changes in future development costs	(55,333)
Revisions of previous quantities	99,591
Accretion of discount	13,195
Change in production rates and other	(21,707)
End of year	$ 691,089