MNRL Sub (MNRL) 10-K 25 Feb 21 2020 FY Annual report Financial data

Cover

Cover - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Feb. 19, 2021	Jun. 30, 2020
Document Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2020
Current Fiscal Year End Date	--12-31
Document Transition Report	false
Entity File Number	001-38870
Entity Registrant Name	Brigham Minerals, Inc.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	83-1106283
Entity Address, Address Line One	5914 W. Courtyard Drive,
Entity Address, Address Line Two	Suite 200
Entity Address, City or Town	Austin,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	78730
City Area Code	512
Local Phone Number	220-6350
Title of 12(b) Security	Class A common stock, par value $0.01
Trading Symbol	MNRL
Security Exchange Name	NYSE
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	true
Entity Ex Transition Period	false
ICFR Auditor Attestation Flag	false
Entity Shell Company	false
Entity Public Float			$ 515.5
Documents Incorporated by Reference	Portions of the registrant’s definitive proxy statement for the 2021 Annual Meeting of Stockholders, to be filed no later than 120 days after the end of the fiscal year to which this Annual Report on Form 10-K relates, are incorporated by reference into Part III of this Annual Report on Form 10-K.
Amendment Flag	false
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	FY
Entity Central Index Key	0001745797
Common Class A
Document Information [Line Items]
Entity Common Stock, Shares Outstanding		43,558,494
Class B Common Stock
Document Information [Line Items]
Entity Common Stock, Shares Outstanding		13,167,687

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 9,144	$ 51,133
Accounts receivable	17,632	30,291
Prepaid expenses and other	3,693	1,688
Total current assets	30,469	83,112
Non-current assets:
Unevaluated property	325,091	291,664
Evaluated property	488,301	449,061
Less accumulated depreciation, depletion, and amortization	(189,546)	(61,103)
Total oil and gas properties, net	623,846	679,622
Other property and equipment	5,587	5,095
Less accumulated depreciation	(4,632)	(3,703)
Other property and equipment—net	955	1,392
Deferred tax asset	24,920	18,823
Other assets, net	771	1,213
Total assets	680,961	784,162
Current liabilities:
Accounts payable and accrued liabilities	7,905	11,533
Total current liabilities	7,905	11,533
Long-term debt	20,000	0
Other non-current liabilities	1,126	803
Temporary equity	146,280	454,507
Shareholders' equity:
Preferred stock, $0.01 par value; 50,000,000 authorized; no shares issued and outstanding at December 31, 2020 and December 31, 2019	0	0
Additional paid-in capital	601,129	323,578
Accumulated deficit	(92,392)	(6,599)
Treasury stock, at cost; 436,630 shares at December 31, 2020 and no shares at December 31, 2019	(3,527)	0
Total shareholders' equity attributable to Brigham Minerals, Inc.	505,650	317,319
Total liabilities, temporary equity and shareholders' equity	680,961	784,162
Class A Common Stock
Shareholders' equity:
Common stock	440	340
Class B Common Stock
Shareholders' equity:
Common stock	$ 0	$ 0

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Dec. 31, 2020	Dec. 31, 2019
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Preferred stock, shares issued (in shares)	0	0
Preferred stock, shares outstanding (in shares)	0	0
Treasury stock (in shares)	436,630	0
Class A Common Stock
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	400,000,000	400,000,000
Common stock, shares issued (in shares)	43,995,124	34,040,934
Common stock, shares outstanding (in shares)	43,558,494	34,040,934
Class B Common Stock
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	150,000,000	150,000,000
Common stock, shares issued (in shares)	13,167,687	22,847,045
Common stock, shares outstanding (in shares)	13,167,687	22,847,045

Consolidated and Combined State

Consolidated and Combined Statements of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
REVENUES
Mineral and royalty revenues	$ 86,245	$ 97,886	$ 59,758
Lease bonus and other revenues	5,478	3,629	7,506
Total revenues	91,723	101,515	67,264
OPERATING EXPENSES
Gathering, transportation and marketing	6,985	4,985	3,944
Severance and ad valorem taxes	5,606	6,409	3,536
Depreciation, depletion, and amortization	48,238	30,940	13,915
Impairment of oil and gas properties	79,569	0	0
General and administrative	21,619	21,963	6,638
Total operating expenses	162,017	64,297	28,033
(LOSS) INCOME FROM OPERATIONS	(70,294)	37,218	39,231
(Loss) gain on derivative instruments, net	0	(568)	424
Interest expense, net	(890)	(5,609)	(7,446)
Loss on extinguishment of debt	0	(6,892)	0
Gain on sale and distribution of equity securities	0	0	823
Other income, net	428	169	110
(Loss) income before income tax expense	(70,756)	24,318	33,142
Income tax (benefit) expense	(12,762)	2,679	327
NET (LOSS) INCOME	(57,994)	21,639	32,815
Less: Net income attributable to Predecessor	0	(5,092)	(30,976)
Less: net loss (income) attributable to temporary equity	15,582	(9,646)	0
Net (loss) income attributable to Brigham Minerals, Inc. shareholders	$ (42,412)	$ 6,901	$ 1,839
NET (LOSS) INCOME PER COMMON SHARE
Basic (in dollars per share)	$ (1.11)	$ 0.26	$ 0
Diluted (in dollars per share)	$ (1.11)	$ 0.26	$ 0
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING
Basic (in shares)	38,178	22,870	0
Diluted (in shares)	38,178	22,870	0

Consolidated and Combined Sta_2

Consolidated and Combined Statement of Comprehensive Income (Loss) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Statement of Comprehensive Income [Abstract]
NET (LOSS) INCOME	$ (57,994)	$ 21,639	$ 32,815
Other comprehensive income
Unrealized gains on available for sale equity securities, net	0	0	141
Reclassification of gains on sale and distribution of available for sale equity securities	0	0	(823)
Other comprehensive loss	0	0	(682)
COMPREHENSIVE (LOSS) INCOME	(57,994)	21,639	32,133
Comprehensive income attributable to Predecessor	0	(5,092)	(30,294)
Comprehensive loss (income) attributable to temporary equity	15,582	(9,646)	0
Comprehensive (loss) income attributable to shareholders	$ (42,412)	$ 6,901	$ 1,839

Consolidated and Combined Sta_3

Consolidated and Combined Statement of Changes in Shareholders' and Members' Equity - USD ($) $ in Thousands	Total	Members' Contributed Capital	Additional Paid-In Capital	Accumulated Other Comprehensive Income	Retained Earnings (accumulated deficit)	Treasury Stock	Class A Common Stock	Class A Common StockCommon Stock	Class B Common Stock	Class B Common StockCommon Stock	December Offering	December OfferingAdditional Paid-In Capital	December OfferingClass A Common StockCommon Stock	December OfferingClass B Common StockCommon Stock
Beginning balance at Dec. 31, 2017	$ 302,174	$ 166,030		$ 682	$ 135,462
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Contributions	45,078	45,078
Distributions	(3,313)	(3,313)
Other comprehensive income	(682)			$ (682)
Deferred tax liability arising from corporate reorganization	(3,057)		$ (3,057)
Proceeds from sale of equity securities	933	933
Net income attributable to predecessor	30,976				30,976
Net income attributable to shareholders	1,839				1,839
Ending balance at Dec. 31, 2018	373,948	208,728	(3,057)		168,277
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to predecessor	5,092				5,092
Net income attributable to shareholders	848				848
Ending balance at Apr. 16, 2019	379,888	208,728	(3,057)		174,217
Beginning balance at Dec. 31, 2018	373,948	208,728	(3,057)		168,277
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other comprehensive income	0
Net income attributable to predecessor	5,092
Net income attributable to shareholders	6,901
Ending balance at Dec. 31, 2019	317,319		323,578		(6,599)			$ 340
Ending balance (in shares) at Dec. 31, 2019							34,040,934	34,041,000	22,847,045	22,847,000
Beginning balance at Apr. 16, 2019	379,888	208,728	(3,057)		174,217
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to shareholders	6,053				6,053
Conversion of PE Units for Class A Common Stock and Class B Common Stock	0	$ (208,728)	380,205		(171,530)			$ 53
Conversion of PE Units for Class A Common Stock and Class B Common Stock (in shares)								5,322,000		28,778,000
Issuance of common stock, net of offering cost (in shares)								16,675,000					6,000,000
Issuance of common stock, net of offering cost	273,448		273,281					$ 167			$ 102,680	$ 102,620	$ 60
Deferred tax asset arising from the IPO	13,664		13,664								9,508	9,508
Reclassification of noncontrolling interests to temporary equity	(518,000)		(518,000)
Issuance of common stock upon vesting of RSUs, net of shares withheld for income taxes (in shares)								124,000
Issuance of common stock upon vesting of RSUs, net of shares withheld for income taxes	(1,255)		(1,256)					$ 1
Share-based compensation expense (in shares)								0
Share-based compensation expense	13,888		13,888					$ 0
Restricted stock forfeited (in shares)													(11,000)
Dividends declared	(14,663)				(14,663)
Dividend equivalent rights declared	(676)				(676)
Adjustment of temporary equity to redemption amount	(51,572)		(51,572)
Conversion of Class B shares to Class A shares (in shares)													5,931,000	(5,931,000)
Conversion of shares of Class B Common Stock to Class A Common Stock	104,390		104,331										$ 59
Restricted stock forfeited											$ (34)	$ (34)
Ending balance at Dec. 31, 2019	317,319		323,578		(6,599)			$ 340
Ending balance (in shares) at Dec. 31, 2019							34,040,934	34,041,000	22,847,045	22,847,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other comprehensive income	0
Net income attributable to predecessor	0
Net income attributable to shareholders	(42,412)				(42,412)
Issuance of common stock upon vesting of RSUs, net of shares withheld for income taxes (in shares)								304,000
Issuance of common stock upon vesting of RSUs, net of shares withheld for income taxes	(991)		(993)					$ 2
Shares withheld to satisfy employee tax withholding obligations (in shares)								(19,000)
Shares surrendered for tax withholdings on vested equity awards	(185)		(185)
Conversion of shares of Class B Common Stock to Class A Common Stock (in shares)								9,679,000		(9,679,000)
Conversion of shares of Class B Common Stock to Class A Common Stock	97,491		97,393					$ 98
Reduction in deferred tax asset arising from conversion of shares of Class B Common Stock to Class A Common Stock	(2,640)		(2,640)
Purchase of treasury stock (in shares)						437,000		(437,000)
Purchase of treasury stock	(3,527)					$ (3,527)
Share-based compensation expense (in shares)								0
Share-based compensation expense	13,615		13,615
Restricted stock forfeited (in shares)								(10,000)
Dividends declared	(41,601)				(41,601)
Dividend equivalent rights declared	(1,780)				(1,780)
Adjustment of temporary equity to redemption amount	170,361		170,361
Ending balance at Dec. 31, 2020	$ 505,650		$ 601,129		$ (92,392)	$ (3,527)		$ 440
Ending balance (in shares) at Dec. 31, 2020						437,000	43,558,494	43,558,000	13,167,687	13,168,000

Consolidated and Combined Sta_4

Consolidated and Combined Statement of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
CASH FLOWS FROM OPERATING ACTIVITIES
NET (LOSS) INCOME	$ (57,994)	$ 21,639	$ 32,815
Adjustments to reconcile net earnings to net cash provided by operating activities:
Depreciation and amortization	48,238	30,940	13,915
Impairment of oil and gas properties	79,569	0	0
Share-based compensation expense	7,529	10,049	0
Loss on extinguishment of debt	0	6,892	0
Amortization of debt issue costs	605	433	690
Deferred income tax (benefit)/expense	(9,942)	665	237
Loss (gain) on derivative instruments, net	0	568	(424)
Net cash received (paid) for derivative settlements	0	470	(754)
Gain on sale and distribution of equity securities	0	0	(823)
Bad debt expense	299	669	382
Changes in operating assets and liabilities:
Decrease (increase) in accounts receivables	12,359	(10,246)	(8,022)
(Increase) decrease in other current assets	(2,005)	1,787	(6,116)
Decrease in other deferred charges	45	0	0
(Decrease) increase in accounts payables and accrued liabilities	(3,608)	5,112	(484)
Increase in other long-term liabilities	165	47	28
Net cash provided by operating activities	75,260	69,025	31,444
CASH FLOWS FROM INVESTING ACTIVITIES
Additions to oil and gas properties	(66,498)	(219,481)	(195,603)
Additions to other fixed assets	(492)	(474)	(723)
Proceeds from sale of oil and gas properties, net	1,565	3,123	125
Proceeds from sale of equity securities	0	0	933
Net cash used in investing activities	(65,425)	(216,832)	(195,268)
CASH FLOWS FROM FINANCING ACTIVITIES
Payments of short-term related party loan	0	0	(7,000)
Borrowing of short-term related party loan	0	0	7,000
Payments of short-term debt	0	(4,596)	0
Payments of long-term debt	0	(275,404)	(70,000)
Borrowing of long-term debt	20,000	105,000	218,000
Payment of debt extinguishment fees	0	(2,091)	0
Proceeds from issuance of Class A common stock sold in initial public offering, net of offering costs	0	277,075	0
Proceeds from issuance of Class A common stock, net of offering costs	0	102,680	0
Capital contributions	0	0	46,011
Capital distributions	0	(441)	0
Purchase of treasury stock	(3,527)	0	0
Dividends paid	(42,216)	(14,663)	0
Distributions to holders of temporary equity	(24,670)	(19,731)	0
Debt issuance cost	(208)	(1,348)	(4,614)
Employee tax withholding for settlement of equity compensation awards	(1,203)	0	0
Net cash (used in) provided by financing activities	(51,824)	166,481	189,397
(Decrease) increase in cash and cash equivalents and restricted cash	(41,989)	18,674	25,573
Cash, cash equivalents and restricted cash, beginning of period	51,133	32,459	6,886
Cash, cash equivalents and restricted cash end of period	9,144	51,133	32,459
Supplemental disclosure of non-cash activity:
Equity securities distributed	0	0	3,313
Accrued capital expenditures	146	63	1,426
Capitalized share-based compensation cost	6,086	3,818	0
Temporary equity cumulative adjustment to fair value	(170,361)	51,572	0
Supplemental cash flow information:
Cash (payments) for loan commitment fees and interest	(715)	(6,192)	(6,123)
Cash received/(paid) for taxes	$ 1,211	$ (832)	$ (604)

Business and Basis of Presentat

Business and Basis of Presentation	12 Months Ended
	Dec. 31, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Business and Basis of Presentation	Business and Basis of Presentation Description of the Business Brigham Minerals, Inc. (together with its wholly owned subsidiaries, “Brigham Minerals” or the “Company”) is a Delaware corporation formed in June 2018 to become a holding company. Brigham Minerals acquired an indirect interest in Brigham Resources, LLC (“Brigham Resources”), our predecessor, on July 16, 2018 in a series of restructuring transactions pursuant to which certain entities affiliated with Warburg Pincus LLC (“Warburg Pincus”) contributed all of their respective interests in the entities through which they held interests in Brigham Resources to Brigham Minerals in exchange for all of the outstanding shares of common stock of Brigham Minerals (the “July 2018 restructuring”). As a result of such restructuring transactions, Brigham Minerals became wholly owned by an entity affiliated with Warburg Pincus, and Brigham Minerals indirectly owned a 16.5% membership interest in Brigham Resources. The remaining outstanding membership interests of Brigham Resources remained with certain other entities affiliated with Warburg Pincus, Yorktown Partners LLC and Pine Brook Road Advisors, LP, Brigham Minerals’ management and its other investors (collectively, the “Original Owners”). On November 20, 2018, Brigham Resources underwent a second series of restructuring transactions (the “November 2018 restructuring”). In the November 2018 restructuring, Brigham Resources became a wholly owned subsidiary of Brigham Minerals Holdings, LLC (“Brigham LLC”), which was a wholly owned subsidiary of Brigham Equity Holdings, LLC (“Brigham Equity Holdings”), and Brigham Equity Holdings became wholly owned by the owners of Brigham Resources immediately prior to such restructuring, directly or indirectly, through Brigham Minerals. As a result of the foregoing transactions, there was no change in the control or economic interests of the Original Owners and Brigham Minerals in Brigham Resources, although their ownership became indirect through Brigham Equity Holdings and its wholly owned subsidiary, Brigham LLC. The July 2018 restructuring and the November 2018 restructuring are collectively referred to herein as the “2018 corporate reorganizations.” Brigham Resources wholly owns Brigham Minerals, LLC and Rearden Minerals, LLC (collectively, the “Minerals Subsidiaries”), which acquire and actively manage a portfolio of mineral and royalty interests. The Minerals Subsidiaries are Brigham Resources’ sole material assets. Initial Public Offering In April 2019, Brigham Minerals completed its' initial public offering (the "IPO") of 16,675,000 shares of Class A common stock at a price to the public of $18.00 per share. This resulted in net proceeds of approximately $273.4 million, after deducting underwriting commissions and discounts and offering expenses, which proceeds were used to repay $200.0 million of existing indebtedness and to fund mineral and royalty acquisitions. As a result of the IPO and the corporate restructuring described in "Note 9—Temporary Equity", Brigham Minerals became a holding company whose sole material asset consisted of a 43.3% interest in Brigham LLC, which wholly owns Brigham Resources. Brigham Resources continues to wholly own the Minerals Subsidiaries, which own all of Brigham Resources’ operating assets. In connection with the IPO, Brigham Minerals became the sole managing member of Brigham LLC and is responsible for all operational, management and administrative decisions relating to Brigham LLC’s business and consolidates the financial results of Brigham LLC and its wholly owned subsidiary, Brigham Resources. December 2019 Offering On December 16, 2019, Brigham Minerals completed an offering of 12,650,000 shares of its Class A common stock (the "December 2019 Offering"), including 6,000,000 shares issued and sold by Brigham Minerals and an aggregate of 6,650,000 shares sold by certain shareholders of the Company (the "Selling Shareholders"), of which 5,496,813 represents shares issued upon redemption of an equivalent number of their Brigham LLC units, at a price to the public of $18.10 per share ($17.376 per share net of underwriting discounts and commissions). After deducting underwriting discounts, commissions and offering expenses, Brigham Minerals received net proceeds of approximately $102.7 million which were used to repay $80.0 million of existing indebtedness under our revolving credit agreement and will be used to fund future mineral and royalty acquisitions. Brigham Minerals did not receive any proceeds from the sale of shares of Class A common stock by the Selling Shareholders. June 2020 Secondary Offering On June 12, 2020, Brigham Minerals completed an offering of 6,600,000 shares of its Class A common stock (the "June 2020 Secondary Offering"), all of which were sold by certain shareholders of the Company (the “June 2020 Selling Shareholders”), and 4,872,669 of which represented shares issued upon redemption of an equivalent number of the June 2020 Selling Shareholders’ Brigham LLC Units (together with a corresponding number of shares of Class B common stock in Brigham Minerals), at a price to the public of $13.75 per share. Brigham Minerals did not sell any shares of its common stock in the June 2020 Secondary Offering and did not receive any proceeds pursuant to the June 2020 Secondary Offering. September 2020 Secondary Offering On September 15, 2020, Brigham Minerals completed an offering of 5,021,140 shares of its Class A common stock, including 654,931 shares issued pursuant to the option granted to the underwriter to purchase additional shares to cover over-allotments (the "September 2020 Secondary Offering"), all of which were sold by certain shareholders of the Company (the "September 2020 Selling Shareholders"), and 3,062,011 of which represented shares issued upon redemption of an equivalent number of the September 2020 Selling Shareholders’ Brigham LLC Units (together with a corresponding number of shares of Class B common stock in Brigham Minerals), at a price to the public of $8.20 per share. Brigham Minerals did not sell any shares of its Class A common stock in the September 2020 Secondary Offering and did not receive any proceeds pursuant to the September 2020 Secondary Offering. In addition, in connection with the September 2020 Secondary Offering, Brigham Minerals repurchased 436,630 shares of its Class A common stock from the September 2020 Selling Shareholders in a privately negotiated transaction at a price equal to the price per share at which the underwriter purchased shares from the September 2020 Selling Shareholders in the September 2020 Secondary Offering (and Brigham LLC redeemed a corresponding number of Brigham LLC Units held by Brigham Minerals). The repurchased shares are presented in the Company's consolidated balance sheet as Treasury Stock, at cost. Following the completion of the September 2020 Secondary Offering and as of December 31, 2020, Brigham Minerals owned a 76.8% interest in Brigham LLC and the Original Owners owned 23.2% of the outstanding voting stock of Brigham Minerals. Certain other entities affiliated with Yorktown Partners LLC and Pine Brook Road Advisors, LP, which are a subset of the Company's Original Owners, collectively owned 16.9% of the outstanding voting stock of Brigham Minerals as of December 31, 2020. Basis of Presentation Subsequent to the July 2018 restructuring and prior to the IPO, Brigham Minerals used the equity method of accounting for its investment in Brigham Resources, its predecessor, because its 16.5% ownership in Brigham Resources provided Brigham Minerals with significant influence, but not with a controlling financial interest or the ability to direct the most significant activities of Brigham Resources. Upon the completion of the IPO, Brigham Minerals indirectly owned an approximate 43.3% interest of Brigham Resources and 100% of the voting rights and consolidates the results of operations of Brigham Resources. In order to furnish comparative financial information, the accompanying consolidated and combined financial statements and related notes of Brigham Minerals for periods prior to the IPO have been retrospectively recast to include the combined historical financial information of both Brigham Resources (at historical carrying values) and Brigham Minerals, taking into account state and federal income taxes and liabilities associated with Brigham Minerals. All intercompany transactions between Brigham Minerals and Brigham Resources have been eliminated. Because Brigham Minerals acquired an interest in Brigham Resources as part of the 2018 corporate reorganization, net income is attributable to stockholders of Brigham Minerals in addition to our Predecessor beginning in 2018.

Significant Accounting Policies

Significant Accounting Policies	12 Months Ended
	Dec. 31, 2020
Accounting Policies [Abstract]
Significant Accounting Policies	Significant Accounting Policies Emerging Growth Company Status As a company with less than $1.07 billion in revenues during its last fiscal year, Brigham Minerals qualifies as an “emerging growth company” as defined in the Jumpstart Our Business Startups Act of 2012 (the “JOBS Act”). An emerging growth company may take advantage of specified reduced reporting and other regulatory requirements. Brigham Minerals will remain an “emerging growth company” until as late as the last day of Brigham Minerals’ 2023 fiscal year, or until the earliest of (i) the last day of the fiscal year in which Brigham Minerals has $1.07 billion or more in annual revenues; (ii) the date on which Brigham Minerals becomes a “large accelerated filer” (the fiscal year-end on which the total market value of Brigham Minerals’ common equity securities held by non-affiliates is $700 million or more as of June 30); (iii) the date on which Brigham Minerals issues more than $1.0 billion of non-convertible debt over a three-year period. As a result of Brigham Minerals’ election to avail itself of certain provisions of the JOBS Act, the information that Brigham Minerals provides may be different than the information provided by other public companies. Use of Estimates The preparation of consolidated and combined financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities in the consolidated and combined financial statements and accompanying notes. Although management believes these estimates are reasonable, actual results could differ from these estimates. Changes in estimates are recorded prospectively. The accompanying consolidated and combined financial statements are based on a number of significant estimates including quantities of oil, natural gas and NGLs reserves that are the basis for the calculations of depreciation, depletion, amortization (“DD&A”) and impairment of oil and natural gas properties. Reservoir engineering is a subjective process of estimating underground accumulations of oil and natural gas and there are numerous uncertainties inherent in estimating quantities of proved oil and natural gas reserves. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. As a result, reserve estimates may differ from the quantities of oil and natural gas that are ultimately recovered. Brigham Minerals’ reserve estimates are audited by Cawley, Gillespie & Associates, Inc. (“CG&A”), an independent petroleum engineering firm. Other items subject to significant estimates and assumptions include the carrying amount of oil and natural gas properties, valuation of derivative instruments, share-based compensation and revenue accruals. Cash and Cash Equivalents Brigham Minerals considers all highly liquid investments with an original maturity of three months or less to be cash equivalents. Receivables Receivables consist of royalty income due from operators for oil and gas sales to purchasers. Those purchasers remit payment for production to the operator of our properties and the operator, in turn, remits payment to us. Receivables from third parties for which we did not receive actual information, either due to timing delays or due to the unavailability of data at the time when revenues are recognized, are estimated. Volume estimates for wells with available historical actual data are based upon (i) the historical actual data for the months the data is available, or (ii) engineering estimates for the months the historical actual data is not available. We do not recognize revenues for wells with no historical actual data because we cannot conclude that it is probable that a significant revenue reversal will not occur in future periods. Pricing estimates are based upon actual prices realized in an area by adjusting the market price for the average basis differential from market on a basin-by-basin basis. Brigham Minerals routinely reviews outstanding balances, assesses the financial strength of its customers and records a reserve for amounts not expected to be fully recovered. We recorded an allowance for doubtful accounts of $0.3 million and $0.6 million for the year ended December 31, 2020 and 2019, respectively, which was included in general and administrative expenses. At December 31, 2020 and 2019, accounts receivable was comprised of the following: December 31, (In thousands) 2020 2019 Oil and gas sales $ 17,413 $ 27,888 Allowance for doubtful accounts (855) (556) Other 1,074 2,959 Total accounts receivables $ 17,632 $ 30,291 Concentration of Credit Risk and Significant Customers Financial instruments that potentially subject Brigham Minerals to concentrations of credit risk consist of cash, accounts receivable, commodity derivative financial instruments and our revolving credit facility. Cash and cash equivalents are held in a few financial institutions in amounts that may, at times, exceed federally insured limits. However, no losses have been incurred and management believes that counterparty risks are minimal based on the reputation and history of the institutions selected. Accounts receivable are concentrated among operators and purchasers engaged in the energy industry within the United States. Management periodically assesses the financial condition of these entities and institutions and considers any possible credit risk to be minimal. Concentrations of oil and gas sales to significant customers (operators) are presented in the table below. For the year ended December 31, 2020 2019 2018 Occidental Petroleum Corp. 12 % 16 % 15 % Royal Dutch Shell 12 % — % — % Exxon Mobil Corp. 11 % 10 % — % Continental Resources, Inc. 10 % 12 % 10 % Management does not believe that the loss of any customer would have a long-term material adverse effect on our financial position or the results of operations. Investments in Equity Securities In January 2019, the Company adopted ASU 2016-01, Financial Instruments-Overall: Recognition and Measurement of Financial Assets and Financial Liabilities. The ASU changes to the current GAAP model primarily affect the accounting for equity investments, financial liabilities under the fair value option and the presentation and disclosure requirements for financial instruments. Under the new standard, all equity investments in unconsolidated entities (other than those accounted for using the equity method of accounting) will generally be measured at fair value through earnings. There will no longer be an available-for-sale classification (changes in fair value reported in other comprehensive income) for equity securities with readily determinable fair values. Prior to January 2019, Brigham Minerals classified its equity securities as available-for-sale, and as such, they were carried at fair value. Changes in fair value of available-for-sale securities were reported as a component of other comprehensive income. Losses were recognized within the consolidated and combined statement of operations when a decline in value is determined to be other-than-temporary. Brigham Minerals used the average cost method to determine the realized gain or loss for each sale or distribution of available-for-sale securities. Financial Instruments Brigham Minerals’ financial instruments consist of cash and cash equivalents, receivables, payables, derivative assets and liabilities, investments in equity securities and long-term debt. The carrying amounts of cash and cash equivalents, receivables and payables approximate fair value due to the highly liquid or short-term nature of these instruments. The fair values of Brigham Minerals’ derivative assets and liabilities are based on a third-party industry-standard pricing model using contract terms and prices and assumptions and inputs that are substantially observable in active markets throughout the full term of the instruments, including forward oil and gas price curves, discount rates, volatility factors and credit risk adjustments. The carrying amount of long-term debt associated with borrowings outstanding under Brigham Minerals’ revolving credit facility approximates fair value as borrowings bear interest at variable market rates. See “Note 5—Derivative Instruments,” “Note 6—Fair Value Measurements” and “Note 7—Long-Term Debt.” Oil and Gas Properties Brigham Minerals uses the full cost method of accounting for its oil and natural gas properties. Under this method, all acquisition costs incurred for the purpose of acquiring mineral and royalty interests and certain related employee costs are capitalized into a full cost pool. Costs associated with general corporate activities are expensed in the period incurred. Capitalized costs are amortized using the units-of-production method. Under this method, the provision for depletion is calculated by multiplying total production for the period by a depletion rate. The depletion rate is determined by dividing the total unamortized cost base by net equivalent proved reserves at the beginning of the period. Costs associated with unevaluated properties are excluded from the amortizable cost base until a determination has been made as to the existence of proved reserves. Unevaluated properties are reviewed periodically to determine whether the costs incurred should be reclassified to the full cost pool and subjected to amortization. The costs associated with unevaluated properties primarily consist of acquisition costs and capitalized general and administrative costs. Unevaluated properties are assessed for impairment on an individual basis or as a group if properties are individually insignificant. The assessment includes consideration of the following factors, among others: expectation of future drilling activity; past drilling results and activity; geological and geophysical evaluations; the assignment of proved reserves; and the economic viability of development if proved reserves are assigned. During any period in which these factors indicate an impairment, the cumulative acquisition costs incurred to date for such property are transferred to the full cost pool and are then subject to amortization. There was no impairment recorded for unevaluated properties in 2020, 2019 and 2018. Sales and abandonments of oil and natural gas properties being amortized are accounted for as adjustments to the full cost pool, with no gain or loss recognized unless the adjustments would significantly alter the relationship between capitalized costs and proved reserves. A significant alteration would not ordinarily be expected to occur upon the sale of reserves involving less than 25% of the reserve quantities of a cost center. Natural gas volumes are converted to barrels of oil equivalent (Boe) at the rate of six thousand cubic feet (Mcf) of natural gas to one barrel (Bbl) of oil. This convention is not an equivalent price basis and there may be a large difference in value between an equivalent volume of oil versus an equivalent volume of natural gas. Under the full cost method of accounting, total capitalized costs of oil and natural gas properties, net of accumulated depletion and related deferred income taxes, may not exceed an amount equal to the present value of future net revenues from proved reserves, discounted at 10% per annum ("PV-10"), plus the cost of unevaluated properties less related income tax effects (the ceiling limitation). A ceiling limitation is calculated at each reporting period. If total capitalized costs, net of accumulated DD&A and related deferred income taxes are greater than the ceiling limitation, a write-down or impairment of the full cost pool is required. A write-down of the carrying value of the full cost pool is a noncash charge that reduces earnings and impacts equity in the period of occurrence and typically results in lower depletion expense in future periods. Once incurred, a write-down cannot be reversed at a later date. The ceiling limitation calculation is prepared using an unweighted arithmetic average of oil prices ("SEC oil price") and natural gas prices ("SEC gas price") as of the first day of each month for the trailing 12-month period ended December 31, 2020, adjusted by area for energy content, transportation fees and regional price differentials, as required under the guidelines established by the SEC. If applicable, these net wellhead prices would be further adjusted to include the effects of any fixed price arrangements for the sale of oil and natural gas. For the year ended December 31, 2020, as a result of its quarterly full cost ceiling analysis, Brigham Minerals recorded impairments of proved oil and gas properties of $79.6 million, due to declines in the 12-month average realized price of crude oil, as well as reclassification of proved undeveloped reserves to probable and possible reserves, as a result of a slowdown in operator activity. See “Note 3—Oil and Gas Properties” for further discussion. Share-Based Compensation Brigham Minerals accounts for its share-based compensation including grants of the Incentive Units (as hereinafter defined), restricted stock awards, time-based restricted stock units and performance-based stock units in the consolidated and combined statements of operations based on their estimated fair values at grant date. Brigham Minerals uses a Monte Carlo simulation to determine the fair value of performance-based stock units. Brigham Minerals recognizes expense on a straight-line basis over the vesting period of the respective grant, which is generally the requisite service period. Brigham Minerals capitalizes a portion of the share-based compensation cost to oil and gas properties on the consolidated balance sheets. Share-based compensation expense is included in general and administrative expenses in Brigham Minerals’ consolidated and combined statements of operations included within this Annual Report. There was approximately $17.0 million of unamortized compensation expense relating to outstanding awards at December 31, 2020, a portion of which will be capitalized. The unrecognized share-based compensation expense will be recognized on a straight-line basis over the remaining vesting periods of the awards. Brigham Minerals accounts for forfeitures as they occur. Earnings Per Share Brigham Minerals uses the “if-converted” method to determine the potential dilutive effect of its Class B common stock and the treasury stock method to determine the potential dilutive effect of outstanding Incentive Units, RSAs, RSUs, and PSUs. Employee Benefit Plan We sponsor a 401(k) tax-deferred savings plan for our employees. We match 100% of each employee’s contributions, up to 6% of the employee’s total compensation. Brigham Resources may also contribute additional amounts at its discretion. Brigham Resources contributed $0.4 million, $0.3 million and $0.2 million, to the 401(k) plan for each of the years ended December 31, 2020, 2019, and 2018. Income Taxes Brigham Minerals accounts for income taxes using the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are calculated by applying existing tax laws and the rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the period that includes the enactment date. Brigham Minerals periodically assesses whether it is more likely than not that it will generate sufficient taxable income to realize its deferred income tax assets, including net operating losses. In making this determination, Brigham Minerals considers all available positive and negative evidence and makes certain assumptions. Brigham Minerals considers, among other things, its deferred tax liabilities, the overall business environment, its historical earnings and losses, current industry trends and its outlook for future years. Temporary Equity Brigham Minerals accounts for the Original Owners’ 23.2% interest in Brigham LLC as of December 31, 2020, as temporary equity as a result of certain redemption rights held by the Original Owners as discussed in “Note 9—Temporary Equity.” As such, the Company adjusts temporary equity to its maximum redemption amount at the balance sheet date, if higher than the carrying amount. The redemption amount is based on the 10-day volume-weighted average closing price (“VWAP”) of Class A shares at the end of the reporting period. Changes in the redemption value are recognized immediately as they occur, as if the end of the reporting period was also the redemption date for the instrument, with an offsetting entry to additional paid-in capital. Temporary equity is reclassified to permanent equity (i) upon Conversion of Class B common stock (and an equivalent number of Brigham LLC Units) to Class A common stock, or (ii) when holders of Class B common stock no longer control a majority of the votes of the board of directors through direct representation on the board of directors, and no longer control the determination of whether to make a cash payment upon a Brigham Unit Holder's exercise of its Redemption Right. Revenue from Contracts with Customers In 2019, the Company adopted Accounting Standards Codification Topic 606, Revenue from Contracts with Customers, ("ASC 606") using the modified retrospective approach, which only applied to contracts that were in effect as of the date of adoption. The adoption did not require an adjustment to opening retained earnings for the cumulative effect adjustment and did not impact the Company’s previously reported results of operations, nor its ongoing consolidated balance sheets, consolidated and combined statements of cash flow or statements of changes in shareholders' and members' equity. Overall, there were no material changes in the timing of the satisfaction of the Company’s performance obligations or the allocation of the transaction price to its performance obligations in applying the guidance in ASC 606 as compared to legacy U.S. GAAP. Oil and natural gas sales Oil, natural gas and NGLs sales revenues are generally recognized when control of the product is transferred to the customer, the performance obligations under the terms of the contracts with customers are satisfied and collectability is reasonably assured. All of the Company’s oil, natural gas and NGL sales are made under contracts with customers (operators). The performance obligations for the Company’s contracts with customers are satisfied at a point in time through the delivery of oil and natural gas to its customers. Accordingly, the Company’s contracts do not give rise to contract assets or liabilities. The Company typically receives payment for oil, natural gas and NGL sales within 60 days of the month of delivery, which can extend up to 9 months after initial production from the well. The Company’s contracts for oil, natural gas and NGL sales are standard industry contracts that include variable consideration based on the monthly index price and adjustments that may include counterparty-specific provisions related to volumes, price differentials, discounts and other adjustments and deductions. As each unit of product represents a separate performance obligation and the consideration is variable as it relates to oil and natural gas prices, Brigham Minerals recognizes revenue from oil and natural gas sales using the allocation exception for variable consideration in ASC 606. Lease bonus and other income Brigham Minerals also earns revenue from lease bonuses, delay rentals, and right-of-way payments. We generate lease bonus revenue by leasing our mineral interests to exploration and production companies. A lease agreement represents our contract with a customer and generally transfers the rights to any oil or natural gas discovered, grants us a right to a specified royalty interest, and requires that drilling and completion operations commence within a specified time period. The Company recognizes lease bonus revenues when the lease agreement has been executed, payment has been received, and the Company has no further obligation to refund the payment. At the time Brigham Minerals executes the lease agreement, Brigham Minerals expects to receive the lease bonus payment within a reasonable time, though in no case more than one year, such that Brigham Minerals has not adjusted the expected amount of consideration for the effects of any significant financing component per the practical expedient in ASC 606. Brigham Minerals also recognizes revenue from delay rentals to the extent drilling has not started within the specified period, payment has been received, and we have no further obligation to refund the payment. Right-of-way payments are recorded by the Company when the agreement has been executed, payment is determined to be collectable, and the Company has no further obligation to refund the payment. Allocation of transaction price to remaining performance obligations Oil and natural gas sales Brigham Minerals’ right to royalty income does not originate until production occurs and, therefore, is not considered to exist beyond each day’s production. Therefore, there are no remaining performance obligation under any of our royalty income contracts. Lease bonus and other income Given that Brigham Minerals does not recognize lease bonus or other income until a lease agreement has been executed, at which point its performance obligation has been satisfied, and payment is received, Brigham Minerals does not record revenue for unsatisfied or partially unsatisfied performance obligations as of the end of the reporting period. Prior-period performance obligations Brigham Minerals records revenue in the month production is delivered to the purchaser. As a non-operator, Brigham Minerals has limited visibility into the timing of when new wells start producing and production statements may not be received for 30 to 90 days or more after the date production is delivered. As a result, Brigham Minerals is required to estimate the amount of production delivered to the purchaser and the price that will be received for the sale of the product. The expected sales volumes and prices for these properties are estimated and recorded within the accounts receivable line item in the accompanying consolidated balance sheets. The difference between the Company’s estimates and the actual amounts received for oil and natural gas sales is recorded in the month that payment is received from the third party. For the years ended December 31, 2020, 2019 and 2018, revenue recognized in the reporting periods related to performance obligations satisfied in prior reporting periods was immaterial. Debt Issuance Cost Other assets include capitalized debt issuance costs of $0.8 million, net of accumulated amortization of $0.8 million as of December 31, 2020. As of December 31, 2019, capitalized debt issuance costs of $1.2 million, net of accumulated amortization of $0.2 million, was included in long-term debt on the consolidated balance sheets. Debt issuance costs were incurred in connection with establishing and amending credit facilities for Brigham Resources and are amortized over the term of the credit facilities using the straight-line method, which approximates the effective interest rate method. Amortization expense for debt issue costs was $0.6 million, $0.4 million and $0.7 million for the years ended December 31, 2020, 2019, and 2018. During the year ended December 31, 2020, we wrote off debt issuance cost of $0.3 million as a result of the reduction of the borrowing base on our revolving credit facility that occurred in May 2020. On July 27, 2018, the prior revolving credit facility was terminated and replaced with the Owl Rock credit facility. On May 16, 2019, the Owl Rock credit facility was terminated and replaced with a new revolving credit facility. See further discussion in "Note 7—Long-Term Debt" in our consolidated and combined financial statements. Recently Issued Accounting Standards Not Yet Adopted Brigham Minerals’ status as an emerging growth company ("EGC") under Section 107 of the JOBS Act permits it to delay the adoption of certain accounting standards until those standards would otherwise apply to private companies. Brigham Minerals is choosing to take advantage of this extended transition period and, as a result, it will comply with new or revised accounting standards on the relevant dates on which adoption of such standards is required for private companies. If Brigham loses its status as an EGC before the adoption dates for private companies, Brigham Minerals will be required to accelerate the adoption of new or revised accounting standards. In February 2016, the FASB issued ASU 2016-02, Leases, which requires all leasing arrangements to be presented in the balance sheet as liabilities along with a corresponding asset. ASU 2016-02 does not apply to leases of mineral rights to explore for or use crude oil and natural gas. The ASU will replace most existing lease guidance in GAAP when it becomes effective. In January 2018, the FASB issued ASU 2018-01, Land Easement Practical Expedient for Transition to Topic 842, to provide an optional practical expedient to not evaluate existing or expired land easements that were not previously accounted for as leases under Topic 840. In July 2018, the FASB issued ASU 2018-11 Leases (Topic 842): Targeted Improvements, which provides for another transition method, in addition to the existing transition method, by allowing entities to initially apply the new leases standard at the adoption date and recognize a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption (i.e. comparative periods presented in the financial statements will continue to be in accordance with current GAAP (Topic 840, Leases)). The new standard becomes effective for us during the fiscal year ending December 31, 2022 and interim periods within the fiscal year ending December 31, 2023 and early adoption is permitted. We are currently evaluating the impact that the adoption of this update will have on our consolidated and combined financial statements and related disclosures. In June 2016, the FASB issued ASU 2016-13, Financial Instruments—Credit Losses. In May 2019, ASU 2016-13 was subsequently amended by ASU 2019-04, Codification Improvements to Topic 326, Financial Instruments—Credit Losses and ASU 2019-05, Financial Instruments—Credit Losses (Topic 326): Targeted Transition Relief. ASU 2016-13, as amended, affects trade receivables, financial assets and certain other instruments that are not measured at fair value through net income. This ASU will replace the currently required incurred loss approach with an expected loss model for instruments measured at amortized cost and is effective for financial statements issued for fiscal years beginning after December 15, 2022, including interim periods within those fiscal years. ASU 2016-13 will be applied using a modified retrospective approach through a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. We are currently evaluating the impact that the adoption of this update will have on our condensed consolidated and combined financial statements and related disclosures.

Oil and Gas Properties

Oil and Gas Properties	12 Months Ended
	Dec. 31, 2020
Extractive Industries [Abstract]
Oil and Gas Properties	Oil and Gas Properties Brigham Minerals uses the full cost method of accounting for its oil and natural gas properties. Under this method, all acquisition costs incurred for the purpose of acquiring mineral and royalty interests, including certain internal costs, are capitalized into a full cost pool. Costs associated with general corporate activities are expensed in the period incurred. Oil and gas properties consisted of the following: December 31, (In thousands) 2020 2019 Oil and gas properties, at cost, using the full cost method of accounting: Not subject to depletion $ 325,091 $ 291,664 Subject to depletion 488,301 449,061 Total oil and gas properties, at cost 813,392 740,725 Less accumulated depreciation, depletion, and amortization (189,546) (61,103) Total oil and gas properties, net $ 623,846 $ 679,622 Costs not subject to depletion are as follows, by the year in which such costs were incurred: By Year: (In thousands) Total 2020 2019 2018 2017 2016 Prior Property Acquisition costs $ 325,091 $ 34,032 $ 80,799 $ 72,884 $ 65,925 $ 10,624 $ 60,827 Capitalized costs are depleted on a unit of production basis based on proved oil and natural gas reserves. Depletion expense was $47.3 million, $30.4 million and $13.3 million for the year ended December 31, 2020, 2019 and 2018, respectively. Average depletion of proved properties was $13.63, $11.22 and $9.38 per Boe for the year ended December 31, 2020, 2019 and 2018, respectively. The costs associated with unevaluated properties primarily consist of acquisition costs and capitalized general and administrative costs. Brigham Minerals capitalizes certain overhead expenses and other internal costs attributable to the acquisition of mineral and royalty interests as part of its investment in oil and gas properties over the periods benefitted by these activities. Capitalized costs do not include any costs related to general corporate overhead or similar activities. Capitalized costs were $10.2 million, $7.4 million and $2.7 million for the years ended December 31, 2020, 2019 and 2018, respectively. As of December 31, 2020, 2019 and 2018, the SEC oil price and SEC gas price used in the calculation of the ceiling test, adjusted by area for energy content, transportation fees and regional price differentials, were $39.57, $55.65, and $65.66 per barrel of oil and $2.00, $2.60, and $3.12 per MMbtu of natural gas, respectively. During the year ended December 31, 2020, Brigham Minerals recorded ceiling test impairment charges of $79.6 million to oil and gas properties, net, as a result of its quarterly ceiling test analysis. The impairment charges were due to declining SEC oil prices and SEC gas prices, as well as certain reclassification of proved undeveloped reserves to probable and possible reserves, as a result of a slowdown in operator activity. There was no impairment charge during the year ended December 31, 2019 and 2018. Further decline in the SEC oil price or the SEC gas price could lead to additional impairment charges in the future and such impairment charges could be material. In addition to the impact of lower prices, any future changes to assumptions of drilling and completion activity, development timing, acquisitions or divestitures of oil and gas properties, proved undeveloped locations, and production and other estimates may require revisions to estimates of total proved reserves which would impact the amount of any impairment charge. During the year ended December 31, 2020, Brigham Minerals reduced its proved undeveloped reserves by 8,209 MBoe primarily due to a reclassification of 7,036 MBoe from proved undeveloped reserves to probable and possible reserves, as a result of decreased rig activity, a 29% reduction in SEC oil prices over the twelve months, and conversion from proved undeveloped to proved developed reserves. The reduction in rig activity led to changes in the development timing and a reduction of the number of proved undeveloped locations that Brigham Minerals expects will be developed within five years after the date of booking.

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2020
Business Combinations [Abstract]
Acquisitions and Divestitures	Acquisitions and Divestitures In 2019, Brigham Minerals adopted ASU 2017-01, Clarifying the Definition of a Business, using a prospective approach. This guidance assists in determining whether a transaction should be accounted for as an acquisition of assets or as a business. This ASU provides a screen that when substantially all of the fair value of the gross assets acquired, or disposed of, are concentrated in a single identifiable asset, or a group of similar identifiable assets, the set will not be considered a business. If the screen is not met, a set must include an input and a substantive process that together significantly contribute to the ability to create an output to be considered a business. The adoption of the new standard did not have a material impact on the consolidated and combined financial statements. During the years ended December 31, 2020 and 2019, Brigham Minerals entered into a number of individually insignificant acquisitions of mineral and royalty interests from various sellers in Texas, Oklahoma, Colorado, New Mexico, and North Dakota, as reflected in the table below. The change in the oil and natural gas property balance is comprised of payments for acquisitions of minerals, land brokerage costs and capitalized general and administrative expenses that were funded with borrowings under its Owl Rock credit facility, our revolving credit facility and proceeds from the IPO. Assets Acquired Cash Consideration Paid (In thousands) Evaluated Unevaluated Year ended December 31, 2020 $ 30,856 $ 35,725 $ 66,581 Year ended December 31, 2019 $ 140,025 $ 78,093 $ 218,118 Oil and Natural Gas Reserves Proved reserves represent quantities of oil, natural gas and NGLs which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be recoverable in the future from known reservoirs under existing economic conditions, operating methods and government regulations. Proved developed reserves are proved reserves which can be expected to be recovered through existing wells with existing equipment, infrastructure and operating methods. Proved reserves were estimated in accordance with guidelines established by the SEC, which require that reserve estimates be prepared under existing economic and operating conditions based upon the 12-month unweighted average of the first-day-of-the-month prices. The reserves at December 31, 2020, 2019, and 2018 presented below were audited by CG&A. Estimates of proved reserves are inherently imprecise and are continually subject to revision based on production history, results of additional exploration and development, price changes and other factors. The reserves are located in various fields in Texas, New Mexico, Oklahoma, Colorado, Wyoming, North Dakota, and Montana. All of the proved reserves are located in the continental United States. Crude Oil Natural Gas NGL Total Proved reserve quantities, December 31, 2017 8,724 38,401 3,980 19,104 Sales of minerals-in-place — — — — Extensions and discoveries 1,765 5,285 562 3,208 Acquisitions 3,669 13,862 1,374 7,354 Revisions of previous estimates (390) (3,245) (577) (1,508) Production (777) (2,507) (222) (1,417) Proved reserve quantities, December 31, 2018 12,991 51,796 5,117 26,741 Sales of minerals-in-place (182) (697) (110) (409) Extensions and discoveries 1,997 7,780 817 4,110 Acquisitions 4,256 13,053 1,218 7,651 Revisions of previous estimates (586) (5,495) (797) (2,299) Production (1,515) (4,707) (407) (2,706) Proved reserve quantities, December 31, 2019 16,961 61,730 5,838 33,088 Sales of minerals-in-place — (286) (1) (48) Extensions and discoveries 876 2,545 291 1,591 Acquisitions 1,235 3,652 331 2,174 Revisions of previous estimates (4,049) (18,188) (1,189) (8,271) Production (1,823) (5,809) (680) (3,471) Proved reserve quantities, December 31, 2020 13,200 43,644 4,590 25,063 Proved reserve quantities at December 31, 2020 attributable to temporary equity 3,064 10,131 1,065 5,818 Proved developed reserve quantities: December 31, 2018 6,067 21,735 1,898 11,588 December 31, 2019 9,924 33,232 2,494 17,957 December 31, 2020 9,403 31,873 3,426 18,141 Proved developed reserves at December 31, 2020 attributable to temporary equity 2,183 7,399 795 4,211 Proved undeveloped reserve quantities: December 31, 2018 6,924 30,061 3,219 15,153 December 31, 2019 7,037 28,498 3,344 15,131 December 31, 2020 3,797 11,771 1,164 6,922 Proved undeveloped reserves at December 31, 2020 attributable to temporary equity 881 2,732 270 1,607 Changes in proved reserves that occurred during 2020 were primarily due to: • the acquisition of additional mineral interests located in the Permian, Anadarko, DJ and Williston Basins in multiple transactions. The acquired proved reserves of 2,174 MBoe throughout the year were offset by the divestiture of 48 MBoe of proved reserves; • well additions, extensions and discoveries of approximately 1,591 MBoe, as approximately 342 gross horizontal well locations were converted from probable, possible and contingent resources to proved, due to continuous activity and delineation of additional zones on our mineral and royalty interests; • negative revisions of 2,645 MBoe attributable to reduction in SEC pricing; • as a result of decreased operator activity throughout 2020, a reclass of 7,036 MBoe to non-proved due to future locations falling outside the SEC five-year rule for PUDs; and • positive revision of 1,410 MBoe attributable to estimate ultimate recovery ("EUR") adjustments, refined gas and NGL processing assumptions, and unit configuration. Changes in proved reserves that occurred during 2019 were primarily due to: • the acquisition of additional mineral interests located in the Permian, Anadarko, DJ and Williston Basins in multiple transactions, which included 7,242 MBoe of additional proved reserves which is comprised of 7,651 MBoe of acquired proved reserves and divestiture of 409 MBoe of proved reserves within the year; • well additions extensions and discoveries of approximately 4,110 MBoe, as approximately 900 gross horizontal well locations were converted from probable, possible and contingent resources to proved, due to continuous activity and delineation of additional zones on our mineral and royalty interests; and • net volume revisions of approximately 2,299 MBoe. These revisions were comprised of 902 MBoe of negative revisions attributable to pricing as well as approximately 1,397 MBoe attributable to operator development timing, unit configuration and EUR adjustments to existing proved locations. Changes in proved reserves that occurred during 2018 were primarily due to: • the acquisition of additional mineral and royalty interests located in the Permian, DJ, Anadarko and Williston Basins in multiple transactions, which included 7,354 MBoe of additional proved reserves; • well additions, extensions and discoveries of approximately 3,208 MBoe, as 555 gross horizontal well locations were converted from probable, possible and contingent resources to proved, due to continuous activity and delineation of additional zones on our mineral and royalty interests; and • net negative volume revisions of approximately 1,508 MBoe. These revisions were comprised of 536 MBoe of positive revisions attributable to pricing and were offset by negative revisions of 1,100 MBoe attributable to operator development timing as well as 944 MBoe of revisions associated with unit configuration and EUR adjustments to existing proved locations. Standardized Measure of Discounted Future Net Cash Flows Guidelines prescribed in FASB’s Accounting Standards Codification (“ASC”) Topic 932 Extractive Industries—Oil and Gas, have been followed for computing a standardized measure of future net cash flows and changes therein relating to estimated proved reserves. Future cash inflows are determined by applying prices and costs, including transportation, quality, and basis differentials, to the year-end estimated quantities of oil, natural gas and NGLs to be produced in the future. The resulting future net cash flows are reduced to present value amounts by applying a ten percent annual discount factor. The assumptions used to compute the standardized measure are those prescribed by the FASB and the SEC. These assumptions do not necessarily reflect Brigham Resources’ expectations of actual revenues to be derived from those reserves, nor their present value. The limitations inherent in the reserve quantity estimation process, as discussed previously, are equally applicable to the standardized measure computations since these reserve quantity estimates are the basis for the valuation process. Reserve estimates are inherently imprecise and estimates of new discoveries and undeveloped locations are more imprecise than estimates of established proved producing oil and gas properties. Accordingly, these estimates are expected to change as future information becomes available. The following summary sets forth the future net cash flows relating to proved oil and gas reserves based on the standardized measure prescribed in ASC Topic 932: For the Year Ended December 31, (In thousands) 2020 2019 2018 Future crude oil, natural gas, and NGL sales $ 562,545 $ 1,042,118 $ 1,049,141 Future severance tax and ad valorem taxes (39,318) (73,627) (70,248) Future income tax expense (46,908) (143,599) (144,421) Future net cash flows 476,319 824,892 834,472 10% annual discount (205,551) (359,258) (391,013) Standardized measure of discounted future net cash flows $ 270,768 $ 465,634 $ 443,459 Standardized measure of discounted future net cash flows attributable to temporary equity $ 62,853 $ 186,999 $ — The following prices were used in the determination of standardized measure: For the Year Ended December 31, 2020 2019 2018 Oil (per Bbl) $ 36.35 $ 51.01 $ 61.31 Natural gas (per Mcf) 1.03 1.51 2.51 NGLs (per Bbl) 8.19 14.39 23.98 These prices were based on the 12-month arithmetic average first-of-month West Texas Intermediate (“WTI”) price of oil and Henry Hub price of natural gas. The NGL pricing varied by basin at 10% to 25% of WTI. All prices have been adjusted for transportation, quality, basis differentials and post-production costs. The principal sources of change in the standardized measure of discounted future net cash flows are: For the Year Ended December 31, (In thousands) 2020 2019 2018 Standardized measure of discounted future net cash flows, beginning of the year $ 465,634 $ 443,459 $ 316,468 Changes in the year resulting from: Sales, less production costs (73,654) (86,492) (52,278) Revisions of previous quantity estimates (135,926) (41,539) (22,942) Extensions, discoveries, and other additions 21,011 69,057 71,668 Net change in prices and production costs (131,886) (99,660) 71,770 Accretion of discount 54,741 51,949 31,713 Purchase of reserves in place 27,241 137,819 148,580 Divestitures of reserves in place (250) (5,783) — Net change in taxes 53,786 (5,739) (75,369) Timing differences and other (9,929) 2,563 (46,151) Standardized measure of discounted future net cash flows, end of the year $ 270,768 $ 465,634 $ 443,459 Capitalized oil and natural gas costs The aggregate amounts of costs capitalized for oil and natural gas producing activities and related aggregate amounts of accumulated depletion follow: For the Year Ended December 31, (In thousands) 2020 2019 2018 Oil and gas properties, at cost, using full cost method of accounting: Not subject to depletion $ 325,091 $ 291,664 $ 228,151 Subject to depletion 488,301 449,061 289,851 Total oil and gas properties, at cost 813,392 740,725 518,002 Less accumulated depreciation, depletion, and amortization (189,546) (61,103) (27,628) Total oil and gas properties, net $ 623,846 $ 679,622 $ 490,374 Costs incurred in oil and natural gas activities The following costs were incurred in oil and natural gas producing activities: For the Year Ended December 31, (In thousands) 2020 2019 2018 Acquisition of oil and gas properties Unevaluated $ 35,725 $ 78,093 $ 59,460 Evaluated 30,856 140,025 137,496 Total $ 66,581 $ 218,118 $ 196,956

Derivative Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	Derivative Instruments Brigham Minerals periodically uses commodity derivative instruments to reduce its exposure to commodity price volatility for a portion of its forecasted crude oil and natural gas sales and thereby achieve a more predictable level of cash flows. None of the derivative instruments are designated as hedges. Brigham Minerals does not enter into derivative instruments for speculative or trading purposes. Because the counterparties to Brigham Minerals derivative instruments have investment grade credit ratings, Brigham Minerals believes it does not have significant credit risk and does not anticipate nonperformance from its counterparties. Brigham Minerals continually monitors the credit ratings of its counterparties. Concurrent with the termination of its prior revolving credit facility in July 2018, Brigham Resources posted cash collateral of $1.4 million for its existing WTI fixed price swap contracts. The cash collateral was $1.6 million in May 2019 prior to the termination of the Owl Rock credit facility and was returned to Brigham Resources upon entering into our revolving credit facility. Brigham Minerals had no derivative contracts in place as of December 31, 2020 and 2019. Prior to December 31, 2019, we had certain oil swap contracts based on the New York Mercantile Exchange ("NYMEX") futures index. The following table summarizes Brigham Minerals' (loss) gain on derivative instruments, net on its consolidated and combined statement of operations for the year ended December 31, 2020, 2019 and 2018: Years Ended December 31, (In thousands) 2020 2019 2018 Realized gain (loss) $ — $ 470 $ (754) Unrealized (loss) gain — (1,038) 1,178 (Loss) gain on derivative instruments, net $ — $ (568) $ 424

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2020
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements We classify financial assets and liabilities that are measured and reported at fair value on a recurring basis using a hierarchy based on the inputs used in measuring fair value. GAAP defines fair value 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 the measurement date (exit price). We classify the inputs used to measure fair value into the following hierarchy: • Level 1: Inputs based on quoted market prices in active markets for identical assets or liabilities at the measurement date. • Level 2: Inputs based on quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets and liabilities in markets that are not active or other inputs that are observable and can be corroborated by observable market data. • Level 3: Inputs that reflect management’s best estimates and assumptions of what market participants would use in pricing the asset or liability at the measurement date. The inputs are unobservable in the market and significant to the valuation of the instruments. Changes in economic conditions or model-based valuation techniques may require the transfer of financial instruments from one fair value level to another. In such instances, the transfer would be reported at the beginning of the period in which the change occurs. Assets and Liabilities Measured at Fair Value on a Recurring Basis Brigham Minerals had no financial assets or liabilities that were accounted for at fair value on a recurring basis at December 31, 2020 and 2019. Brigham Minerals had no derivative contracts in place as of December 31, 2020 and 2019 as disclosed in "Note 5—Derivative Instruments." Commodity derivative instruments are valued using a third-party industry-standard pricing model using contract terms and prices and assumptions and inputs that are substantially observable in active markets throughout the full term of the instruments, including forward oil and gas price curves, discount rates and volatility factors. The fair values are also compared to the values provided by the counterparties for reasonableness and are adjusted for the counterparties’ credit quality for derivative assets and our credit quality for derivative liabilities. As such, these derivative contracts are classified within Level 2. Brigham Minerals had no transfers into or out of Level 1 and no transfers into or out of Level 2 for the years ended December 31, 2020 and 2019. Assets and Liabilities Measured at Fair Value on a Non-Recurring Basis Certain nonfinancial assets and liabilities, such as assets and liabilities acquired in a business combination, are measured at fair value on a nonrecurring basis on the acquisition date and are subject to fair value adjustments under certain circumstances. The inputs used to determine such fair value are primarily based upon internally developed cash flow models and include factors such as estimates of economic reserves, future operating and development costs, future commodity prices and a risk-adjusted discount rates, and are classified within Level 3. Fair Value of Other Financial Instruments The carrying value of cash, trade and other receivables and trade payables are considered to be representative of their respective fair values due to the short-term nature of these instruments. The carrying amount of debt outstanding pursuant to our term loan and our revolving credit facility approximates fair value as interest rates on these instruments approximate current market rates. We categorized our long-term debt within Level 2 of the fair value hierarchy.

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2020
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Prior Revolving Credit Facility Prior to its termination on July 27, 2018, the Minerals Subsidiaries maintained a secured revolving credit facility with a syndicate of financial institutions (the “prior revolving credit facility”), which had been amended periodically. The prior revolving credit facility had a commitment of $150 million, and a borrowing base and outstanding borrowings of $70 million each as of July 27, 2018. Brigham Minerals terminated the prior revolving credit facility on July 27, 2018 with proceeds from the Owl Rock credit facility (as defined below). Additionally, during the third quarter of 2018, Brigham Resources wrote off approximately $0.3 million of unamortized debt issuance costs that were related to the prior revolving credit facility. Owl Rock Credit Facility On July 27, 2018, the prior revolving credit facility was terminated in conjunction with the entry into a new credit facility (the “Owl Rock credit facility”) with Owl Rock Capital Corporation as administrative agent and collateral agent. Brigham Resources used the proceeds from the Owl Rock credit facility to repay the outstanding $70 million of principal under the prior revolving credit facility and to fund mineral and royalty acquisitions. The Owl Rock credit facility was subject to customary fees, guarantees of subsidiaries, restrictions and covenants, including certain restricted payments, and was collateralized by certain oil and natural gas properties of Brigham Resources. The Owl Rock credit facility provided for a $125 million initial term loan, a $75 million delayed draw term loan (“DDTL”) and a $10 million revolving credit facility, bore interest at a rate per annum equal to, at Brigham Resources’ option, (a) the base rate plus 4.50%, or (b) the adjusted LIBOR rate for such interest period (subject to a 1.00% floor) plus 5.50%, matured on July 27, 2024 and required Brigham Resources to maintain compliance with certain financial and collateral coverage ratios. On May 7, 2019, the Owl Rock credit facility was terminated and paid off using a portion of the net proceeds generated from the IPO. As a result of the debt repayment, Brigham Minerals recognized a loss on extinguishment of debt of $6.9 million, which consisted of a $4.0 million write-off of capitalized debt issuance costs, a $2.1 million prepayment fee and legal fees of $0.8 million. Revolving Credit Facility On May 16, 2019 (the “closing date”) Brigham Resources entered into a credit agreement with Wells Fargo Bank, N.A., as administrative agent for the various lenders from time to time party thereto, providing for a new revolving credit facility (our "revolving credit facility”). Our revolving credit facility is guaranteed by Brigham Resources’ domestic subsidiaries and is collateralized by a lien on substantially all of Brigham Resources and its domestic subsidiaries’ assets, including substantially all of their respective royalty and mineral properties. Availability under our revolving credit facility is governed by a borrowing base, which is subject to redetermination in May and November of each year. In addition, lenders holding two-thirds of the aggregate commitments may request one additional redetermination each year. Brigham Resources can also request one additional redetermination each year, and such other redeterminations as appropriate when significant acquisition opportunities arise. The borrowing base is subject to further adjustments for asset dispositions, material title deficiencies, certain terminations of hedge agreements and issuances of permitted additional indebtedness. Increases to the borrowing base require unanimous approval of the lenders, while decreases only require approval of lenders holding two-thirds of the aggregate commitments at such time. As of December 31, 2020, the borrowing base on our revolving credit facility was $135.0 million, with outstanding borrowings of $20.0 million, resulting in $115.0 million availability for future borrowings. Our revolving credit facility bears interest at a rate per annum equal to, at our option, the adjusted base rate or the adjusted LIBOR rate plus an applicable margin. The applicable margin is based on utilization of our revolving credit facility and ranges from (a) in the case of adjusted base rate loans, 0.750% to 1.750% and (b) in the case of adjusted LIBOR rate loans, 1.750% to 2.750%. Brigham Resources may elect an interest period of one two three six twelve Our revolving credit facility matures on May 16, 2024. Loans drawn under our revolving credit facility may be prepaid at any time without premium or penalty (other than customary LIBOR breakage) and must be prepaid in the event that exposure exceeds the lesser of the borrowing base and the elected availability at such time. The principal amount of loans that are prepaid are required to be accompanied by accrued and unpaid interest and fees on such amounts. Loans that are prepaid may be reborrowed. In addition, Brigham Resources may permanently reduce or terminate in full the commitments under our revolving credit facility prior to maturity. Any excess exposure resulting from such permanent reduction or termination must be prepaid. Upon the occurrence of an event of default under our revolving credit facility, the administrative agent acting at the direction of the lenders holding a majority of the aggregate commitments at such time may accelerate outstanding loans and terminate all commitments under our revolving credit facility, provided that such acceleration and termination occurs automatically upon the occurrence of a bankruptcy or insolvency event of default.

Shareholders' and Members' Equi

Shareholders' and Members' Equity	12 Months Ended
	Dec. 31, 2020
Equity [Abstract]
Shareholders' and Members' Equity	Shareholders' and Members' Equity Shareholders' Equity Class A Common Stock Brigham Minerals has approximately 43.6 million shares of its Class A common stock outstanding as of December 31, 2020. Holders of Class A common stock are entitled to one vote per share on all matters to be voted upon by the stockholders and are entitled to ratably receive dividends when and if declared by the Company’s board of directors. Upon liquidation, dissolution, distribution of assets or other winding up, the holders of Class A common stock are entitled to receive ratably the assets available for distribution to the stockholders after payment of liabilities. Class B Common Stock Brigham Minerals has approximately 13.2 million shares of its Class B common stock outstanding as of December 31, 2020. Holders of the Class B common stock are entitled to one vote per share on all matters to be voted upon by the stockholders. Holders of Class A common stock and Class B common stock generally vote together as a single class on all matters presented to Brigham Minerals’ stockholders for their vote or approval. Holders of Class B common stock generally do not have any right to receive dividends or distributions upon a liquidation or winding up of Brigham Minerals. Treasury Stock Brigham Minerals repurchased 436,630 shares of its Class A common stock from the September 2020 Selling Shareholders at a price of $8.08 per share (and Brigham LLC redeemed a corresponding number of Brigham LLC Units held by Brigham Minerals). See "Note 1—Business and Basis of Presentation." As of December 31, 2020, there were 436,630 shares of Class A common stock held in treasury. Earnings per Share Basic earnings per share (“EPS”) measures the performance of an entity over the reporting period. Diluted earnings per share measures the performance of an entity over the reporting period while giving effect to all potentially dilutive common shares that were outstanding during the period. Brigham Minerals uses the “if-converted” method to determine the potential dilutive effect of exchanges of outstanding shares of Class B common stock (and corresponding Brigham LLC Units), and the treasury stock method to determine the potential dilutive effect of vesting of its outstanding RSAs, RSUs, PSUs and unvested Incentive Units. Brigham Minerals does not use the two-class method because the Class B common stock and the unvested share-based awards are nonparticipating securities. For the year ended December 31, 2020, the Class B common stock, the Incentive Units, RSAs and RSUs were not recognized in dilutive EPS calculations as the effect would have been antidilutive. For the year ended December 31, 2019, Brigham Minerals’ EPS calculation includes only its share of net income for the period subsequent to the IPO, and omits income or loss prior to the IPO. In addition, the basic weighted average shares outstanding calculation is based on the actual days in which the shares were outstanding from the IPO through December 31, 2019. There were no shares of Class A or Class B common stock outstanding for the year ended December 31, 2018, therefore no earnings per share information has been presented for the indicated period. The following table reflects the allocation of net income (loss) to common shareholders and EPS computations for the period indicated based on a weighted average number of common stock outstanding for the period: Years Ended December 31, (In thousands, except per share data) 2020 2019 2018 Basic EPS Numerator: Basic net (loss) income attributable to Brigham Minerals, Inc. shareholders $ (42,412) $ 6,901 $ — Less net income attributable to shareholders pre-IPO — (848) — Basic net (loss) income attributable to Brigham Minerals, Inc. shareholders post-IPO (1) (42,412) 6,053 — Denominator: Basic weighted average shares outstanding (1) 38,178 22,870 — Net (loss) income per common share $ (1.11) $ 0.26 $ — Diluted EPS Numerator: Basic net (loss) income attributable to Brigham Minerals, Inc. shareholders post-IPO (1) (42,412) 6,053 — Diluted net (loss) income attributable to Brigham Minerals, Inc. shareholders (42,412) 6,053 — Denominator: Basic weighted average shares outstanding (1) 38,178 22,870 — Effect of dilutive securities: — — — Diluted weighted average shares outstanding 38,178 22,870 — Net (loss) income per common share $ (1.11) $ 0.26 $ — (1) - Represents earnings per share of Class A common stock and weighted average shares of Class A common stock for the period following the IPO.

Temporary Equity

Temporary Equity	12 Months Ended
	Dec. 31, 2020
Temporary Equity Disclosure [Abstract]
Temporary Equity	Temporary Equity Temporary equity represents the Original Owners’ 23.2% ownership of Brigham LLC, as of December 31, 2020. In addition, the Original Owners own all of our Class B common stock. Each share of Class B common stock does not have any economic rights but entitles its holder to one vote on all matters to be voted on by our stockholders, generally and a redemption right into Class A shares. As discussed below, following the IPO: • Each holder of Brigham LLC Units following the restructuring, other than Brigham Minerals and its subsidiaries, received a number of shares of Class B common stock equal to the number of Brigham LLC Units held by such Brigham Unit Holder following the IPO; • Brigham Minerals contributed, directly or indirectly, the net proceeds of the IPO to Brigham LLC in exchange for an additional number of Brigham LLC Units such that Brigham Minerals holds, directly or indirectly, a total number of Brigham LLC Units equal to the number of shares of Class A common stock outstanding following the IPO; and • Under the Amended and Restated Limited Liability Company Agreement of Brigham LLC (the “Brigham LLC Agreement”), each Brigham Unit Holder, subject to certain limitations, has a right (the “Redemption Right”) to cause Brigham LLC to acquire all or a portion of its Brigham LLC Units for, at Brigham LLC’s election, (i) shares of our Class A common stock at a redemption ratio of one share of Class A common stock for each Brigham LLC Unit redeemed, subject to conversion rate adjustments for stock splits, stock dividends and reclassification and other similar transactions or (ii) an equivalent amount of cash. We will determine whether to issue shares of Class A common stock or cash based on facts in existence at the time of the decision, which we expect would include the relative value of the Class A common stock (including trading prices for the Class A common stock at the time), the cash purchase price, the availability of other sources of liquidity (such as an issuance of preferred stock) to acquire the Brigham LLC Units and alternative uses for such cash. Alternatively, upon the exercise of the Redemption Right, Brigham Minerals (instead of Brigham LLC) will have a call right to, for administrative convenience, acquire each tendered Brigham LLC Unit directly from the redeeming Brigham Unit Holder for, at its election, (x) one share of Class A common stock or (y) an equivalent amount of cash (the “Call Right”). The decision to make a cash payment upon a Brigham Unit Holder’s exercise of its Redemption Right is required to be made by the Company’s directors who are independent under Section 10A-3 of the Securities Act and do not hold any Brigham LLC Units subject to such redemption. In connection with any redemption of Brigham LLC Units pursuant to the Redemption Right or acquisition pursuant to our Call Right, the corresponding number of shares of Class B common stock will be cancelled. Class B common stock is classified as temporary equity in the consolidated balance sheet as, pursuant to the Brigham LLC Agreement, the Redemption Rights of each Brigham Unit Holder for either shares of Class A common stock or an equivalent amount of cash is not solely within Brigham Minerals’ control. This is due to the fact that the holders of Class B common stock control a majority of the votes of the board of directors through direct representation on the board of directors, which allows the holders of Class B common stock to control the determination of whether to make a cash payment upon a Brigham Unit Holder's exercise of its Redemption Right. Temporary equity is recorded at the greater of the carrying value or redemption amount with a corresponding adjustment to additional paid-in capital. From the date of the IPO through December 31, 2020, the Company recorded adjustments to the value of temporary equity as presented in the table below: (In thousands) Temporary equity adjustments Balance - April 17, 2019 (1) $ 518,000 Conversion of Class B shares to Class A shares (104,390) Net income attribution to temporary equity 9,646 Distribution to holders of temporary equity (20,321) Adjustment of temporary equity to redemption amount (2) 51,572 Balance - December 31, 2019 $ 454,507 Conversion of Class B shares to Class A shares (97,491) Net loss attribution to temporary equity (15,582) Distribution to holders of temporary equity (24,793) Adjustment of temporary equity to redemption amount (3) (170,361) Balance - December 31, 2020 $ 146,280 (1) Based on 28,777,802 shares of Class B common stock outstanding and Class A share price of $18.00. In connection with the IPO, the balance transferred from additional paid-in capital to temporary equity was the greater of redemption value or carrying value of the shares of Class B common stock at IPO and included an initial upward adjustment to redemption amount totaling $194.5 million. (2) Based on 22,847,045 shares of Class B common stock outstanding and Class A share 10-day VWAP of $19.89 at December 31, 2019. (3) Based on 13,167,687 shares of Class B common stock outstanding and Class A share 10-day VWAP of $11.11 at December 31, 2020.

Share-Based Compensation

Share-Based Compensation	12 Months Ended
	Dec. 31, 2020
Share-based Payment Arrangement [Abstract]
Share-Based Compensation	Share-Based Compensation LLC Incentive Units As part of the Second Amended and Restated Limited Liability Company Agreement of Brigham Resources, LLC dated May 8, 2015, Brigham Resources authorized 120,000 restricted incentive units for issuance to management, independent directors, employees, and consultants (such incentive units, as converted as described below, the “Incentive Units”). Brigham Resources granted Incentive Units in April 2013 and September 2015 and 2018. In connection with the 2018 corporate reorganizations and the corporate reorganization consummated in connection with Brigham Minerals’ IPO (collectively with the 2018 corporate reorganizations, the “corporate reorganization”), these Incentive Units were converted into units in Brigham Equity Holdings, LLC (“Brigham Equity Holdings”) with equivalent rights, responsibilities, and preferences. The Incentive Units are subject to vesting as follows: 20% of the Incentive Units were vested on the date of grant and 20% of the Incentive Units vest on each anniversary of the date of grant if the holder remains continuously employed by Brigham Resources or its affiliates through the applicable vesting date. Upon vesting of the Incentive Units, holders of the Incentive Units receive one share of Brigham Minerals’ Class B common stock and one Brigham LLC Unit for each vested Incentive Unit. In connection with the completion of the IPO, Brigham LLC and Brigham Equity Holdings discontinued granting new Incentive Units; however Brigham Equity Holdings will continue to administer the existing awards that remain outstanding. As discussed in “Note 9—Temporary Equity,” participants may receive one share of Brigham Minerals’ Class A common stock in exchange for one share of Class B common stock and one Brigham LLC Unit, or cash at the option of Brigham Minerals. Brigham Minerals accounts for the Incentive Units as compensation cost measured at the fair value of the award on the date of grant. No compensation expense was recognized prior to the IPO because the IPO was not considered probable. A summary of the Incentive Unit activity for the year ended December 31, 2020 is as follows: Incentive Units Number of Incentive Units Grant-date Fair Value Outstanding—January 1, 2020 212,733 $ 10.04 Vested (70,913) $ 10.04 Outstanding—December 31, 2020 141,820 $ 10.04 Long Term Incentive Plan In connection with the IPO, Brigham Minerals adopted the Brigham Minerals, Inc. 2019 Long Term Incentive Plan (“LTIP”) for employees, consultants and directors who perform services for Brigham Minerals. The LTIP provides for issuance of awards based on shares of Class A common stock. Brigham Minerals has issued restricted stock awards ("RSAs"), restricted stock units ("RSUs") and performance-based vesting units ("PSUs") under the LTIP. The shares to be delivered under the LTIP shall be made available from (i) authorized but unissued shares, (ii) shares held as treasury stock or (iii) previously issued shares reacquired by Brigham Minerals including shares purchased on the open market. A total of 5,999,600 shares of Class A common stock have been authorized for issuance under the LTIP. At December 31, 2020, 3,548,923 shares of Class A common stock remained available for future grants. Currently, all outstanding RSAs, RSUs and PSUs granted under the LTIP are entitled to receive dividends (in the case of RSAs) or have dividend equivalent rights (“DERs”), which entitle holders of RSUs and PSUs to the same dividend value per share as holders of the Company’s Class A common stock. Such dividends and DERs are subject to the same vesting and other terms and conditions as the corresponding unvested RSAs, RSUs, and PSUs. Dividends and DERs are accumulated and paid when the underlying shares vest. The fair value of the RSA awards granted with the right to receive dividends and RSU awards granted with the right to receive DERs are generally based on the trading price of the Company’s Class A common stock as of the date of grant. Brigham Minerals accounts for the awards granted under the LTIP as compensation cost measured at the fair value of the award on the date of grant. Brigham Minerals accounts for forfeitures for each of the RSAs, RSUs, and PSUs as they occur. RSAs are grants of shares of Class A common stock subject to a risk of forfeiture and restrictions on transferability. The share-based compensation expense of such RSAs was determined using the closing price of Class A common stock on April 23, 2019, the date of grant, of $21.25. On April 23, 2019, 312,189 RSAs were granted and 152,742 RSAs vested immediately. The RSAs generally vest in one-third increments on each of April 23, 2020, 2021 and 2022 and are subject to restrictions on transfer and are generally subject to a risk of forfeiture if the award recipient ceases providing services to Brigham Minerals prior to the lapse of such restrictions. A summary of the RSA activity for the year ended December 31, 2020 is as follows: Restricted Stock Awards Number of RSAs Grant Date Fair Value Unvested at January 1, 2020 148,456 $ 21.25 Vested (69,594) $ 21.25 Forfeited (10,569) $ 21.25 Unvested at December 31, 2020 68,293 $ 21.25 RSUs represent the right to receive shares of Class A common stock at the end of the vesting period in an amount equal to the number of RSUs that vest. The RSUs that have been granted generally vest in one-third increments on each of the first three anniversaries of the grant date and are subject to restrictions on transfer and are generally subject to a risk of forfeiture if the award recipient ceases providing services to Brigham Minerals prior to the date the award vests. The share-based compensation expense of the RSUs is determined using the closing share price on the date of grant applied to the total number of RSUs granted. Brigham Minerals accounts for forfeitures as they occur. Brigham Minerals withheld 88,476 RSUs to satisfy employee tax withholding obligations totaling $1.0 million, related to the RSUs that vested in 2020. A summary of the RSU activity for the year ended December 31, 2020 is as follows: Restricted Stock Units Number of RSUs Grant Date Fair Value Unvested at January 1, 2020 415,815 $ 21.25 Granted 555,534 $ 16.41 Vested (392,528) $ 19.36 Forfeited (15,950) $ 20.57 Unvested at December 31, 2020 562,871 $ 17.81 PSUs represent the right to receive shares of Class A common stock at the end of a specified performance period. 753,546 PSUs (based on target) were granted on April 23, 2019, with a performance period that ends on December 31, 2021. During the year ended December 31, 2020, 434,265 PSUs (based on target) were granted with a performance period that ends on December 31, 2022. The terms and conditions of the PSUs allow for vesting of the awards ranging between 0% (or forfeiture) and 200% of target. The vesting level is calculated based on the actual total stockholder return achieved during the performance period including projected dividends. The fair value of such PSUs was determined using a Monte Carlo simulation and will be recognized over the applicable performance period. The Monte Carlo simulation model utilizes multiple input variables that determine the probability of satisfying the market condition stipulated in the award to calculate the fair value of the award. Expected volatilities in the model were estimated using a historical period consistent with the performance period of approximately three years. The risk-free interest rate was based on the United States Treasury rate for a term commensurate with the expected life of the grant. Using the assumptions in the table below, Brigham Minerals estimated the fair value of PSUs to be $15.98 and $20.36, respectively, for PSUs granted in 2020 and 2019, respectively. Years Ended December 31, 2020 2019 Expected dividend yield 11.5 % 8.1 % Risk-free interest rate 1.4 % 2.3 % Volatility 35 % 30 % A summary of the PSU activity for the year ended December 31, 2020 is as follows: Performance-Based Restricted Stock Units Target PSUs Estimated Earned PSUs Grant Date Fair Value Unvested at January 1, 2020 753,546 450,836 $ 20.36 Granted 434,265 174,106 $ 15.98 Unvested at December 31, 2020 1,187,811 624,942 $ 19.14 Share-Based Compensation Expense Share-based compensation expense is included in general and administrative expense in the Company’s consolidated and combined statement of operations. Share-based compensation cost recorded for each type of share-based compensation award, was as follows for the periods indicated: Years Ended December 31, (In thousands) 2020 2019 2018 Incentive Units (1) (3) $ 712 $ 2,904 $ — RSAs (2) (3) 1,254 3,972 — RSUs (3) 7,390 4,630 — PSUs (4) 4,259 2,361 — Capitalized share-based compensation (5) (6) (6,086) (3,818) — Total share-based compensation expense $ 7,529 $ 10,049 $ — (1) Includes a cumulative effect adjustment to share-based compensation cost of $2.0 million pertaining to the period from the grant date through the IPO date. No compensation expense was recorded prior to the IPO because the IPO was not considered probable. (2) Includes $3.2 million recorded at grant date of April 23, 2019, associated with 152,742 RSAs, which vested immediately during the year ended December 31, 2019. (3) Share-based compensation expense relating to Incentive Units, RSAs, and RSUs with ratable vesting is recognized on a straight-line basis over the requisite service period for the entire award. (4) Share-based compensation expense relating to PSUs with cliff-vesting is recognized on a straight-line basis over the performance period for the entire award. (5) During the year ended December 31, 2020, Brigham Minerals capitalized $3.0 million of the share-based compensation to unevaluated property and $3.0 million to evaluated property on its consolidated balance sheet. (6) Brigham Minerals capitalizes a portion of the share-based compensation cost incurred after the IPO . In addition to the time-based vesting conditions described above, the Incentive Units could be earned upon the completion of an initial public offering or another liquidity event, considered a performance condition, which was not deemed probable and therefore no compensation expense was recognized prior to December 31, 2018. Future Share-Based Compensation Expense The following table reflects the future share-based compensation expense to be recorded for the share-based compensation awards that were outstanding at December 31, 2020, a portion of which will be capitalized: (In thousands) Incentive Units RSAs RSUs PSUs Total Year 2021 712 726 6,851 4,374 12,663 2022 534 225 2,653 966 4,378 Total $ 1,246 $ 951 $ 9,504 $ 5,340 $ 17,041

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2020
Income Tax Disclosure [Abstract]
Income Taxes	Income TaxesThe Company accounts for income taxes using the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are calculated by applying existing tax laws and the rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the period that includes the enactment date. Brigham Minerals periodically assesses whether it is more likely than not that it will generate sufficient taxable income to realize its deferred income tax assets, including net operating losses. In making this determination, Brigham Minerals considers all available positive and negative evidence and makes certain assumptions. Brigham Minerals considers, among other things, its deferred tax liabilities, the overall business environment, its historical earnings and losses, current industry trends and its outlook for future years. Brigham Minerals' management believes that it is more likely than not that the results of future operations will generate sufficient taxable income to realize the deferred tax assets and as a result, Brigham Minerals did not record a valuation allowance at December 31, 2020 and 2019. Brigham Minerals has evaluated all tax positions for which the statute of limitations remains open and believes that the material positions taken would more likely than not be sustained by examination. Therefore, at December 31, 2020 and 2019, Brigham Minerals had not established any reserves for, nor recorded any unrecognized benefits related to, uncertain tax positions. Brigham Resources, the Company’s predecessor, is a limited liability company that is not subject to U.S. federal income tax, but is subject to the Texas Margin Tax and state income taxes in Oklahoma, North Dakota, and Colorado. As part of the corporate reorganization, certain entities affiliated with Warburg Pincus contributed all of their respective interests in certain wholly owned “blocker” entities through which they held interests in Brigham Resources to Brigham Minerals in exchange for all of the outstanding shares of common stock of Brigham Minerals. On the date of the corporate reorganization, a corresponding “first day” tax charge of approximately $3.1 million was recorded to establish a net deferred tax liability for differences between the tax and book basis of the investment in Brigham Resources. The offset of the deferred tax liability was recorded to additional paid-in-capital. Brigham Minerals is a corporation and is subject to U.S. federal income tax. In April 2019, Brigham Minerals completed the IPO of 16,675,000 shares of Class A common stock at a price to the public of $18.00 per share. The tax implications of the July 2018 restructuring, IPO and the tax impact of the Company’s status as a taxable corporation subject to U.S. federal income tax have been reflected in the accompanying consolidated and combined financial statements. On IPO date, a corresponding tax benefit of approximately $13.7 million was recorded associated with the differences between the tax and book basis of the investment in Brigham Resources. The offset of the deferred tax asset was recorded to additional paid-in capital. After the December 2019 Offering, as discussed in "Note 1—Business and Basis of Presentation", a corresponding tax benefit of approximately $9.5 million was recorded associated with the differences between the tax and book basis of the investment in Brigham Resources. After the June 2020 Secondary Offering and September 2020 Secondary Offering, and corresponding redemptions, as discussed in "Note 1—Business and Basis of Presentation", a corresponding reduction to the tax benefit of approximately $0.8 million and $2.8 million, respectively, was recorded associated with the differences between the tax and book basis of the investment in Brigham Resources. The offset of the deferred tax asset was recorded to additional paid-in capital. The effective combined U.S. federal and state income tax rate for the year ended December 31, 2020 was 18%. During the year ended December 31, 2020, the Company recognized income tax benefit of $12.8 million. During the years ended December 31, 2019 and 2018, the Company recognized income tax expense of $2.7 million and $0.3 million, respectively. Total income tax expense for the years ended December 31, 2020, 2019 and 2018 differed from amounts computed by applying the U.S. federal statutory tax rate of 21% due to the impact of the temporary equity, net income attributable to Predecessor, state taxes (net of the anticipated federal benefit), and percentage depletion in excess of basis. Years Ended December 31, (In thousands) 2020 2019 2018 State Income Tax Current expense/(benefit) $ 122 $ 692 $ (23) Deferred (benefit)/expense (1,876) 63 (138) Federal Income Tax Current (benefit)/expense (2,942) 1,322 114 Deferred (benefit)/expense (8,066) 602 374 Totals: $ (12,762) $ 2,679 $ 327 Total current income tax (benefit)/expense $ (2,820) $ 2,014 $ 91 Total deferred income tax (benefit)/expense (9,942) 665 236 Totals: $ (12,762) $ 2,679 $ 327 The following table reconciles the income tax provision with income tax expense at the federal statutory rate for the periods indicated: Years Ended December 31, (In thousands) 2020 2019 2018 (Loss) income before income taxes $ (70,756) $ 24,318 $ 33,142 Less: income before income taxes attributable to predecessor — (5,118) (30,805) Less: loss (income) before income taxes attributable to temporary equity 15,270 (9,858) — (Loss) income before income taxes attributable to shareholders $ (55,486) $ 9,342 $ 2,337 Income tax at the federal statutory rate $ (11,652) $ 1,962 $ 491 State income taxes, net of federal benefit (1,223) 717 (150) Other federal tax effects 113 — — Percentage depletion in excess of basis — — (14) Total income tax provision $ (12,762) $ 2,679 $ 327 Brigham Minerals had $24.9 million and $18.8 million recorded as deferred tax asset as of December 31, 2020 and 2019. The tax effects of temporary differences that give rise to significant portions of the deferred tax assets were are follows: Years Ended December 31, (In thousands) 2020 2019 Deferred tax assets: Loss carryforwards $ 627 $ — Investment in subsidiary 24,405 19,021 Total deferred tax assets: $ 25,032 $ 19,021 Deferred tax liabilities: Oil and gas properties $ (112) $ (198) Investment in subsidiary — — Total deferred tax liabilities $ (112) $ (198)

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Commitments Brigham Minerals leases office space under operating leases. Rent expense for the year ended December 31, 2020, 2019, and 2018 was $1.1 million, $0.6 million, and $0.3 million, respectively. Future minimum lease commitments under noncancelable operating leases at December 31, 2020 are presented below (in thousands): Year Commitment 2021 $ 1,272 2022 1,310 2023 1,347 2024 1,383 2025 1,419 2026 and Thereafter $ 2,251 Total $ 8,982 Contingencies Brigham Minerals may, from time to time, be a party to certain lawsuits and claims arising in the ordinary course of business. The outcome of such lawsuits and claims cannot be estimated with certainty and management may not be able to estimate the range of possible losses. Brigham Minerals records reserves for contingencies when information available indicates that a loss is probable and the amount of the loss can be reasonably estimated. Brigham Minerals had no reserves for contingencies at December 31, 2020 and December 31, 2019.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2020
Related Party Transactions [Abstract]
Related Party Transactions	Related-Party Transactions Brigham Land Management (“BLM”) occasionally provides us with land brokerage services. The services are provided at market prices and are periodically verified by third-party quotes. BLM is owned by Vince Brigham, an advisor to us and brother of Ben M. Brigham, founder and Executive Chairman of the Board. For the year ended December 31, 2020, the amounts paid to BLM for land brokerage services were immaterial. For the years ended December 31, 2019 and 2018, the amounts paid to BLM for land brokerage services were $0.1 million and $0.1 million, respectively. At December 31, 2020 and 2019, the liabilities recorded for services performed by BLM during the respective periods were immaterial. Brigham Exploration Company, partially owned by Ben M. Brigham, on occasion leases some of our acreage at market rates. Brigham Minerals did not lease any acreage to Brigham Exploration Company during the years ended December 31, 2020 and 2018. We received $0.4 million for the year ended December 31, 2019 in connection with such leases. The Company is party to a services agreement with RS Energy Group, which provides the Company with certain software and services that assist in evaluating the acquisition of mineral interests. Warburg Pincus owned a controlling stake in RS Energy Group until February 2020. The service fees incurred under this agreement were $0.1 million and $0.2 million for the years ended December 31, 2020 and 2019. During the year ended December 31, 2018, Brigham Resources borrowed $7.0 million from Brigham Operating, at an interest rate of 7.00% and repaid the loan prior to December 31, 2018.

COVID-19 Pandemic and Impact on

COVID-19 Pandemic and Impact on Global Demand for Oil and Natural Gas	12 Months Ended
	Dec. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
COVID-19 Pandemic and Impact on Global Demand for Oil and Natural Gas	COVID-19 Pandemic and Impact on Global Demand for Oil and Natural Gas The ongoing global spread of a novel strain of coronavirus (SARS-Cov-2), which causes COVID-19, has caused a continuing disruption to the oil and natural gas industry and to our business by, among other things, contributing to a significant decrease in global crude oil demand and the price for oil beginning in the first quarter of 2020 and continuing through the fourth quarter of 2020. The declining commodity prices have adversely affected the revenues the Company receives for its royalty interests and could affect its ability to access the capital markets on terms favorable to the Company. Additionally, in response to the decline in commodity prices, many operators on the Company's properties have announced reductions in their estimated capital expenditures for 2021 and beyond, which has and will adversely affect the near-term development of the Company's properties during the second half of the year and into 2021. While these lower commodity prices initially resulted in some of the Company's operators shutting in or curtailing production from wells on its properties during the second quarter of 2020, we saw a majority of the Company’s operators resume production for previously curtailed and shut in wells in connection with the improvement of commodity prices in the second half of 2020. In response to the COVID-19 pandemic, the potential risk to Brigham Minerals' workforce and in compliance with stay at home orders, the Company successfully implemented policies and the technological infrastructure for all of its employees to work from home in the first quarter of 2020 and ceased all business travel. In compliance with the requirements for the re-

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2020
Subsequent Events [Abstract]
Subsequent Events	Subsequent EventsOn February 19, 2021, Brigham Minerals declared a dividend of $0.26 per Class A common stock payable on March 26, 2021, to stockholders of record at the close of business on March 19, 2021.

Quarterly Financial Information

Quarterly Financial Information-Unaudited	12 Months Ended
	Dec. 31, 2020
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Information-Unaudited	Quarterly Financial Information-Unaudited Summarized quarterly financial data for the years ended December 31, 2020 and 2019 are presented in the following tables. During the periods presented below, earnings per share information is not available due to no shares being recognized for accounting purposes for periods prior to the IPO. Quarter (In thousands, except per share amount) First Second Third Fourth Year ended December 31, 2020: Total revenues $ 32,280 $ 12,605 $ 23,078 $ 23,760 Income (loss) from operations - (3) 10,413 (7,144) (15,885) (57,678) Net income (loss) 8,801 (6,816) (13,017) (46,962) Net income (loss) attributable to Brigham Minerals, Inc. 4,706 (4,050) (9,465) (33,603) Basic EPS attributable to Brigham Minerals, Inc. shareholders $ 0.14 $ (0.11) $ (0.24) $ (0.78) Diluted EPS attributable to Brigham Minerals, Inc. shareholders $ 0.14 $ (0.11) $ (0.24) $ (0.78) Year ended December 31, 2019: Total revenues $ 18,265 $ 24,529 $ 25,107 $ 33,614 Income from operations 8,707 5,034 9,115 14,362 Net income (loss) 4,036 (3,207) 8,464 12,346 Net income (loss) attributable to Brigham Minerals, Inc. - (2) 534 (1,856) 3,146 5,077 Basic EPS attributable to Brigham Minerals, Inc. shareholders - (1) $ — $ (0.12) $ 0.14 $ 0.20 Diluted EPS attributable to Brigham Minerals, Inc. shareholders - (1) $ — $ (0.12) $ 0.14 $ 0.20 (1) Represents earnings per share of Class A common stock and weighted average shares of Class A common stock for the period from April 17, 2019 through December 31, 2019, the period following the IPO. See "Note 8— Shareholders' and Members' Equity" for additional information. (2) Represents net income attributable to Brigham Minerals for the period starting with the completion of the July 2018 restructuring. See "Note 1—Business and Basis of Presentation" for additional information.

Reserve and Related Financial D

Reserve and Related Financial Data (SMOG) - Unaudited	12 Months Ended
	Dec. 31, 2020
Extractive Industries [Abstract]
Reserve and Related Financial Data (SMOG) - Unaudited	Acquisitions and Divestitures In 2019, Brigham Minerals adopted ASU 2017-01, Clarifying the Definition of a Business, using a prospective approach. This guidance assists in determining whether a transaction should be accounted for as an acquisition of assets or as a business. This ASU provides a screen that when substantially all of the fair value of the gross assets acquired, or disposed of, are concentrated in a single identifiable asset, or a group of similar identifiable assets, the set will not be considered a business. If the screen is not met, a set must include an input and a substantive process that together significantly contribute to the ability to create an output to be considered a business. The adoption of the new standard did not have a material impact on the consolidated and combined financial statements. During the years ended December 31, 2020 and 2019, Brigham Minerals entered into a number of individually insignificant acquisitions of mineral and royalty interests from various sellers in Texas, Oklahoma, Colorado, New Mexico, and North Dakota, as reflected in the table below. The change in the oil and natural gas property balance is comprised of payments for acquisitions of minerals, land brokerage costs and capitalized general and administrative expenses that were funded with borrowings under its Owl Rock credit facility, our revolving credit facility and proceeds from the IPO. Assets Acquired Cash Consideration Paid (In thousands) Evaluated Unevaluated Year ended December 31, 2020 $ 30,856 $ 35,725 $ 66,581 Year ended December 31, 2019 $ 140,025 $ 78,093 $ 218,118 Oil and Natural Gas Reserves Proved reserves represent quantities of oil, natural gas and NGLs which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be recoverable in the future from known reservoirs under existing economic conditions, operating methods and government regulations. Proved developed reserves are proved reserves which can be expected to be recovered through existing wells with existing equipment, infrastructure and operating methods. Proved reserves were estimated in accordance with guidelines established by the SEC, which require that reserve estimates be prepared under existing economic and operating conditions based upon the 12-month unweighted average of the first-day-of-the-month prices. The reserves at December 31, 2020, 2019, and 2018 presented below were audited by CG&A. Estimates of proved reserves are inherently imprecise and are continually subject to revision based on production history, results of additional exploration and development, price changes and other factors. The reserves are located in various fields in Texas, New Mexico, Oklahoma, Colorado, Wyoming, North Dakota, and Montana. All of the proved reserves are located in the continental United States. Crude Oil Natural Gas NGL Total Proved reserve quantities, December 31, 2017 8,724 38,401 3,980 19,104 Sales of minerals-in-place — — — — Extensions and discoveries 1,765 5,285 562 3,208 Acquisitions 3,669 13,862 1,374 7,354 Revisions of previous estimates (390) (3,245) (577) (1,508) Production (777) (2,507) (222) (1,417) Proved reserve quantities, December 31, 2018 12,991 51,796 5,117 26,741 Sales of minerals-in-place (182) (697) (110) (409) Extensions and discoveries 1,997 7,780 817 4,110 Acquisitions 4,256 13,053 1,218 7,651 Revisions of previous estimates (586) (5,495) (797) (2,299) Production (1,515) (4,707) (407) (2,706) Proved reserve quantities, December 31, 2019 16,961 61,730 5,838 33,088 Sales of minerals-in-place — (286) (1) (48) Extensions and discoveries 876 2,545 291 1,591 Acquisitions 1,235 3,652 331 2,174 Revisions of previous estimates (4,049) (18,188) (1,189) (8,271) Production (1,823) (5,809) (680) (3,471) Proved reserve quantities, December 31, 2020 13,200 43,644 4,590 25,063 Proved reserve quantities at December 31, 2020 attributable to temporary equity 3,064 10,131 1,065 5,818 Proved developed reserve quantities: December 31, 2018 6,067 21,735 1,898 11,588 December 31, 2019 9,924 33,232 2,494 17,957 December 31, 2020 9,403 31,873 3,426 18,141 Proved developed reserves at December 31, 2020 attributable to temporary equity 2,183 7,399 795 4,211 Proved undeveloped reserve quantities: December 31, 2018 6,924 30,061 3,219 15,153 December 31, 2019 7,037 28,498 3,344 15,131 December 31, 2020 3,797 11,771 1,164 6,922 Proved undeveloped reserves at December 31, 2020 attributable to temporary equity 881 2,732 270 1,607 Changes in proved reserves that occurred during 2020 were primarily due to: • the acquisition of additional mineral interests located in the Permian, Anadarko, DJ and Williston Basins in multiple transactions. The acquired proved reserves of 2,174 MBoe throughout the year were offset by the divestiture of 48 MBoe of proved reserves; • well additions, extensions and discoveries of approximately 1,591 MBoe, as approximately 342 gross horizontal well locations were converted from probable, possible and contingent resources to proved, due to continuous activity and delineation of additional zones on our mineral and royalty interests; • negative revisions of 2,645 MBoe attributable to reduction in SEC pricing; • as a result of decreased operator activity throughout 2020, a reclass of 7,036 MBoe to non-proved due to future locations falling outside the SEC five-year rule for PUDs; and • positive revision of 1,410 MBoe attributable to estimate ultimate recovery ("EUR") adjustments, refined gas and NGL processing assumptions, and unit configuration. Changes in proved reserves that occurred during 2019 were primarily due to: • the acquisition of additional mineral interests located in the Permian, Anadarko, DJ and Williston Basins in multiple transactions, which included 7,242 MBoe of additional proved reserves which is comprised of 7,651 MBoe of acquired proved reserves and divestiture of 409 MBoe of proved reserves within the year; • well additions extensions and discoveries of approximately 4,110 MBoe, as approximately 900 gross horizontal well locations were converted from probable, possible and contingent resources to proved, due to continuous activity and delineation of additional zones on our mineral and royalty interests; and • net volume revisions of approximately 2,299 MBoe. These revisions were comprised of 902 MBoe of negative revisions attributable to pricing as well as approximately 1,397 MBoe attributable to operator development timing, unit configuration and EUR adjustments to existing proved locations. Changes in proved reserves that occurred during 2018 were primarily due to: • the acquisition of additional mineral and royalty interests located in the Permian, DJ, Anadarko and Williston Basins in multiple transactions, which included 7,354 MBoe of additional proved reserves; • well additions, extensions and discoveries of approximately 3,208 MBoe, as 555 gross horizontal well locations were converted from probable, possible and contingent resources to proved, due to continuous activity and delineation of additional zones on our mineral and royalty interests; and • net negative volume revisions of approximately 1,508 MBoe. These revisions were comprised of 536 MBoe of positive revisions attributable to pricing and were offset by negative revisions of 1,100 MBoe attributable to operator development timing as well as 944 MBoe of revisions associated with unit configuration and EUR adjustments to existing proved locations. Standardized Measure of Discounted Future Net Cash Flows Guidelines prescribed in FASB’s Accounting Standards Codification (“ASC”) Topic 932 Extractive Industries—Oil and Gas, have been followed for computing a standardized measure of future net cash flows and changes therein relating to estimated proved reserves. Future cash inflows are determined by applying prices and costs, including transportation, quality, and basis differentials, to the year-end estimated quantities of oil, natural gas and NGLs to be produced in the future. The resulting future net cash flows are reduced to present value amounts by applying a ten percent annual discount factor. The assumptions used to compute the standardized measure are those prescribed by the FASB and the SEC. These assumptions do not necessarily reflect Brigham Resources’ expectations of actual revenues to be derived from those reserves, nor their present value. The limitations inherent in the reserve quantity estimation process, as discussed previously, are equally applicable to the standardized measure computations since these reserve quantity estimates are the basis for the valuation process. Reserve estimates are inherently imprecise and estimates of new discoveries and undeveloped locations are more imprecise than estimates of established proved producing oil and gas properties. Accordingly, these estimates are expected to change as future information becomes available. The following summary sets forth the future net cash flows relating to proved oil and gas reserves based on the standardized measure prescribed in ASC Topic 932: For the Year Ended December 31, (In thousands) 2020 2019 2018 Future crude oil, natural gas, and NGL sales $ 562,545 $ 1,042,118 $ 1,049,141 Future severance tax and ad valorem taxes (39,318) (73,627) (70,248) Future income tax expense (46,908) (143,599) (144,421) Future net cash flows 476,319 824,892 834,472 10% annual discount (205,551) (359,258) (391,013) Standardized measure of discounted future net cash flows $ 270,768 $ 465,634 $ 443,459 Standardized measure of discounted future net cash flows attributable to temporary equity $ 62,853 $ 186,999 $ — The following prices were used in the determination of standardized measure: For the Year Ended December 31, 2020 2019 2018 Oil (per Bbl) $ 36.35 $ 51.01 $ 61.31 Natural gas (per Mcf) 1.03 1.51 2.51 NGLs (per Bbl) 8.19 14.39 23.98 These prices were based on the 12-month arithmetic average first-of-month West Texas Intermediate (“WTI”) price of oil and Henry Hub price of natural gas. The NGL pricing varied by basin at 10% to 25% of WTI. All prices have been adjusted for transportation, quality, basis differentials and post-production costs. The principal sources of change in the standardized measure of discounted future net cash flows are: For the Year Ended December 31, (In thousands) 2020 2019 2018 Standardized measure of discounted future net cash flows, beginning of the year $ 465,634 $ 443,459 $ 316,468 Changes in the year resulting from: Sales, less production costs (73,654) (86,492) (52,278) Revisions of previous quantity estimates (135,926) (41,539) (22,942) Extensions, discoveries, and other additions 21,011 69,057 71,668 Net change in prices and production costs (131,886) (99,660) 71,770 Accretion of discount 54,741 51,949 31,713 Purchase of reserves in place 27,241 137,819 148,580 Divestitures of reserves in place (250) (5,783) — Net change in taxes 53,786 (5,739) (75,369) Timing differences and other (9,929) 2,563 (46,151) Standardized measure of discounted future net cash flows, end of the year $ 270,768 $ 465,634 $ 443,459 Capitalized oil and natural gas costs The aggregate amounts of costs capitalized for oil and natural gas producing activities and related aggregate amounts of accumulated depletion follow: For the Year Ended December 31, (In thousands) 2020 2019 2018 Oil and gas properties, at cost, using full cost method of accounting: Not subject to depletion $ 325,091 $ 291,664 $ 228,151 Subject to depletion 488,301 449,061 289,851 Total oil and gas properties, at cost 813,392 740,725 518,002 Less accumulated depreciation, depletion, and amortization (189,546) (61,103) (27,628) Total oil and gas properties, net $ 623,846 $ 679,622 $ 490,374 Costs incurred in oil and natural gas activities The following costs were incurred in oil and natural gas producing activities: For the Year Ended December 31, (In thousands) 2020 2019 2018 Acquisition of oil and gas properties Unevaluated $ 35,725 $ 78,093 $ 59,460 Evaluated 30,856 140,025 137,496 Total $ 66,581 $ 218,118 $ 196,956

Significant Accounting Polici_2

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2020
Accounting Policies [Abstract]
Use of Estimates	Use of Estimates The preparation of consolidated and combined financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities in the consolidated and combined financial statements and accompanying notes. Although management believes these estimates are reasonable, actual results could differ from these estimates. Changes in estimates are recorded prospectively. The accompanying consolidated and combined financial statements are based on a number of significant estimates including quantities of oil, natural gas and NGLs reserves that are the basis for the calculations of depreciation, depletion, amortization (“DD&A”) and impairment of oil and natural gas properties. Reservoir engineering is a subjective process of estimating underground accumulations of oil and natural gas and there are numerous uncertainties inherent in estimating quantities of proved oil and natural gas reserves. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. As a result, reserve estimates may differ from the quantities of oil and natural gas that are ultimately recovered. Brigham Minerals’ reserve estimates are audited by Cawley, Gillespie & Associates, Inc. (“CG&A”), an independent petroleum engineering firm. Other items subject to significant estimates and assumptions include the carrying amount of oil and natural gas properties, valuation of derivative instruments, share-based compensation and revenue accruals.
Cash and Cash Equivalents	Cash and Cash Equivalents Brigham Minerals considers all highly liquid investments with an original maturity of three months or less to be cash equivalents.
Accounts Receivables	ReceivablesReceivables consist of royalty income due from operators for oil and gas sales to purchasers. Those purchasers remit payment for production to the operator of our properties and the operator, in turn, remits payment to us. Receivables from third parties for which we did not receive actual information, either due to timing delays or due to the unavailability of data at the time when revenues are recognized, are estimated. Volume estimates for wells with available historical actual data are based upon (i) the historical actual data for the months the data is available, or (ii) engineering estimates for the months the historical actual data is not available. We do not recognize revenues for wells with no historical actual data because we cannot conclude that it is probable that a significant revenue reversal will not occur in future periods. Pricing estimates are based upon actual prices realized in an area by adjusting the market price for the average basis differential from market on a basin-by-basin basis.Brigham Minerals routinely reviews outstanding balances, assesses the financial strength of its customers and records a reserve for amounts not expected to be fully recovered.
Concentration of Credit Risk and Significant Customers	Concentration of Credit Risk and Significant CustomersFinancial instruments that potentially subject Brigham Minerals to concentrations of credit risk consist of cash, accounts receivable, commodity derivative financial instruments and our revolving credit facility. Cash and cash equivalents are held in a few financial institutions in amounts that may, at times, exceed federally insured limits. However, no losses have been incurred and management believes that counterparty risks are minimal based on the reputation and history of the institutions selected. Accounts receivable are concentrated among operators and purchasers engaged in the energy industry within the United States. Management periodically assesses the financial condition of these entities and institutions and considers any possible credit risk to be minimal.
Investments in Equity Securities	Investments in Equity Securities In January 2019, the Company adopted ASU 2016-01, Financial Instruments-Overall: Recognition and Measurement of Financial Assets and Financial Liabilities. The ASU changes to the current GAAP model primarily affect the accounting for equity investments, financial liabilities under the fair value option and the presentation and disclosure requirements for financial instruments. Under the new standard, all equity investments in unconsolidated entities (other than those accounted for using the equity method of accounting) will generally be measured at fair value through earnings. There will no longer be an available-for-sale classification (changes in fair value reported in other comprehensive income) for equity securities with readily determinable fair values. Prior to January 2019, Brigham Minerals classified its equity securities as available-for-sale, and as such, they were carried at fair value. Changes in fair value of available-for-sale securities were reported as a component of other comprehensive income. Losses were recognized within the consolidated and combined statement of operations when a decline in value is determined to be other-than-temporary. Brigham Minerals used the average cost method to determine the realized gain or loss for each sale or distribution of available-for-sale securities.
Financial Instruments	Financial Instruments Brigham Minerals’ financial instruments consist of cash and cash equivalents, receivables, payables, derivative assets and liabilities, investments in equity securities and long-term debt. The carrying amounts of cash and cash equivalents, receivables and payables approximate fair value due to the highly liquid or short-term nature of these instruments. The fair values of Brigham Minerals’ derivative assets and liabilities are based on a third-party industry-standard pricing model using contract terms and prices and assumptions and inputs that are substantially observable in active markets throughout the full term of the instruments, including forward oil and gas price curves, discount rates, volatility factors and credit risk adjustments.
Oil and Gas Properties	Oil and Gas Properties Brigham Minerals uses the full cost method of accounting for its oil and natural gas properties. Under this method, all acquisition costs incurred for the purpose of acquiring mineral and royalty interests and certain related employee costs are capitalized into a full cost pool. Costs associated with general corporate activities are expensed in the period incurred. Capitalized costs are amortized using the units-of-production method. Under this method, the provision for depletion is calculated by multiplying total production for the period by a depletion rate. The depletion rate is determined by dividing the total unamortized cost base by net equivalent proved reserves at the beginning of the period. Costs associated with unevaluated properties are excluded from the amortizable cost base until a determination has been made as to the existence of proved reserves. Unevaluated properties are reviewed periodically to determine whether the costs incurred should be reclassified to the full cost pool and subjected to amortization. The costs associated with unevaluated properties primarily consist of acquisition costs and capitalized general and administrative costs. Unevaluated properties are assessed for impairment on an individual basis or as a group if properties are individually insignificant. The assessment includes consideration of the following factors, among others: expectation of future drilling activity; past drilling results and activity; geological and geophysical evaluations; the assignment of proved reserves; and the economic viability of development if proved reserves are assigned. During any period in which these factors indicate an impairment, the cumulative acquisition costs incurred to date for such property are transferred to the full cost pool and are then subject to amortization. There was no impairment recorded for unevaluated properties in 2020, 2019 and 2018. Sales and abandonments of oil and natural gas properties being amortized are accounted for as adjustments to the full cost pool, with no gain or loss recognized unless the adjustments would significantly alter the relationship between capitalized costs and proved reserves. A significant alteration would not ordinarily be expected to occur upon the sale of reserves involving less than 25% of the reserve quantities of a cost center. Natural gas volumes are converted to barrels of oil equivalent (Boe) at the rate of six thousand cubic feet (Mcf) of natural gas to one barrel (Bbl) of oil. This convention is not an equivalent price basis and there may be a large difference in value between an equivalent volume of oil versus an equivalent volume of natural gas. Under the full cost method of accounting, total capitalized costs of oil and natural gas properties, net of accumulated depletion and related deferred income taxes, may not exceed an amount equal to the present value of future net revenues from proved reserves, discounted at 10% per annum ("PV-10"), plus the cost of unevaluated properties less related income tax effects (the ceiling limitation). A ceiling limitation is calculated at each reporting period. If total capitalized costs, net of accumulated DD&A and related deferred income taxes are greater than the ceiling limitation, a write-down or impairment of the full cost pool is required. A write-down of the carrying value of the full cost pool is a noncash charge that reduces earnings and impacts equity in the period of occurrence and typically results in lower depletion expense in future periods. Once incurred, a write-down cannot be reversed at a later date. The ceiling limitation calculation is prepared using an unweighted arithmetic average of oil prices ("SEC oil price") and natural gas prices ("SEC gas price") as of the first day of each month for the trailing 12-month period ended December 31, 2020, adjusted by area for energy content, transportation fees and regional price differentials, as required under the guidelines established by the SEC. If applicable, these net wellhead prices would be further adjusted to include the effects of any fixed price arrangements for the sale of oil and natural gas. For the year ended December 31, 2020, as a result of its quarterly full cost ceiling analysis, Brigham Minerals recorded impairments of proved oil and gas properties of $79.6 million, due to declines in the 12-month average realized price of crude oil, as well as reclassification of proved undeveloped reserves to probable and possible reserves, as a result of a slowdown in operator activity. See “Note 3—Oil and Gas Properties” for further discussion.
Share-Based Compensation	Share-Based Compensation Brigham Minerals accounts for its share-based compensation including grants of the Incentive Units (as hereinafter defined), restricted stock awards, time-based restricted stock units and performance-based stock units in the consolidated and combined statements of operations based on their estimated fair values at grant date. Brigham Minerals uses a Monte Carlo simulation to determine the fair value of performance-based stock units. Brigham Minerals recognizes expense on a straight-line basis over the vesting period of the respective grant, which is generally the requisite service period. Brigham Minerals capitalizes a portion of the share-based compensation cost to oil and gas properties on the consolidated balance sheets. Share-based compensation expense is included in general and administrative expenses in Brigham Minerals’ consolidated and combined statements of operations included within this Annual Report. There was approximately $17.0 million of unamortized compensation expense relating to outstanding awards at December 31, 2020, a portion of which will be capitalized. The
Earnings Per Share	Earnings Per Share
Employee Benefit Plan	Employee Benefit PlanWe sponsor a 401(k) tax-deferred savings plan for our employees. We match 100% of each employee’s contributions, up to 6% of the employee’s total compensation. Brigham Resources may also contribute additional amounts at its discretion.
Income Taxes	Income Taxes Brigham Minerals accounts for income taxes using the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are calculated by applying existing tax laws and the rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the period that includes the enactment date. Brigham Minerals periodically assesses whether it is more likely than not that it will generate sufficient taxable income to realize its deferred income tax assets, including net operating losses. In making this determination, Brigham Minerals considers all available positive and negative evidence and makes certain assumptions. Brigham Minerals considers, among other things, its deferred tax liabilities, the overall business environment, its historical earnings and losses, current industry trends and its outlook for future years.
Temporary Equity	Temporary Equity Brigham Minerals accounts for the Original Owners’ 23.2% interest in Brigham LLC as of December 31, 2020, as temporary equity as a result of certain redemption rights held by the Original Owners as discussed in “Note 9—Temporary Equity.” As such, the Company adjusts temporary equity to its maximum redemption amount at the balance sheet date, if higher than the carrying amount. The redemption amount is based on the 10-day volume-weighted average closing price (“VWAP”) of Class A shares at the end of the reporting period. Changes in the redemption value are recognized immediately as they occur, as if the end of the reporting period was also the redemption date for the instrument, with an offsetting entry to additional paid-in capital. Temporary equity is reclassified to permanent equity (i) upon Conversion of Class B common stock (and an equivalent number of Brigham LLC Units) to Class A common stock, or (ii) when holders of Class B common stock no longer control a majority of the votes of the board of directors through direct representation on the board of directors, and no longer control the determination of whether to make a cash payment upon a Brigham Unit Holder's exercise of its Redemption Right.
Revenue from Contracts with Customers	Revenue from Contracts with Customers In 2019, the Company adopted Accounting Standards Codification Topic 606, Revenue from Contracts with Customers, ("ASC 606") using the modified retrospective approach, which only applied to contracts that were in effect as of the date of adoption. The adoption did not require an adjustment to opening retained earnings for the cumulative effect adjustment and did not impact the Company’s previously reported results of operations, nor its ongoing consolidated balance sheets, consolidated and combined statements of cash flow or statements of changes in shareholders' and members' equity. Overall, there were no material changes in the timing of the satisfaction of the Company’s performance obligations or the allocation of the transaction price to its performance obligations in applying the guidance in ASC 606 as compared to legacy U.S. GAAP. Oil and natural gas sales Oil, natural gas and NGLs sales revenues are generally recognized when control of the product is transferred to the customer, the performance obligations under the terms of the contracts with customers are satisfied and collectability is reasonably assured. All of the Company’s oil, natural gas and NGL sales are made under contracts with customers (operators). The performance obligations for the Company’s contracts with customers are satisfied at a point in time through the delivery of oil and natural gas to its customers. Accordingly, the Company’s contracts do not give rise to contract assets or liabilities. The Company typically receives payment for oil, natural gas and NGL sales within 60 days of the month of delivery, which can extend up to 9 months after initial production from the well. The Company’s contracts for oil, natural gas and NGL sales are standard industry contracts that include variable consideration based on the monthly index price and adjustments that may include counterparty-specific provisions related to volumes, price differentials, discounts and other adjustments and deductions. As each unit of product represents a separate performance obligation and the consideration is variable as it relates to oil and natural gas prices, Brigham Minerals recognizes revenue from oil and natural gas sales using the allocation exception for variable consideration in ASC 606. Lease bonus and other income Brigham Minerals also earns revenue from lease bonuses, delay rentals, and right-of-way payments. We generate lease bonus revenue by leasing our mineral interests to exploration and production companies. A lease agreement represents our contract with a customer and generally transfers the rights to any oil or natural gas discovered, grants us a right to a specified royalty interest, and requires that drilling and completion operations commence within a specified time period. The Company recognizes lease bonus revenues when the lease agreement has been executed, payment has been received, and the Company has no further obligation to refund the payment. At the time Brigham Minerals executes the lease agreement, Brigham Minerals expects to receive the lease bonus payment within a reasonable time, though in no case more than one year, such that Brigham Minerals has not adjusted the expected amount of consideration for the effects of any significant financing component per the practical expedient in ASC 606. Brigham Minerals also recognizes revenue from delay rentals to the extent drilling has not started within the specified period, payment has been received, and we have no further obligation to refund the payment. Right-of-way payments are recorded by the Company when the agreement has been executed, payment is determined to be collectable, and the Company has no further obligation to refund the payment. Allocation of transaction price to remaining performance obligations Oil and natural gas sales Brigham Minerals’ right to royalty income does not originate until production occurs and, therefore, is not considered to exist beyond each day’s production. Therefore, there are no remaining performance obligation under any of our royalty income contracts. Lease bonus and other income Given that Brigham Minerals does not recognize lease bonus or other income until a lease agreement has been executed, at which point its performance obligation has been satisfied, and payment is received, Brigham Minerals does not record revenue for unsatisfied or partially unsatisfied performance obligations as of the end of the reporting period. Prior-period performance obligations
Debt Issuance Cost	Debt issuance costs were incurred in connection with establishing and amending credit facilities for Brigham Resources and are amortized over the term of the credit facilities using the straight-line method, which approximates the effective interest rate method.
Recently Issued Accounting Standards Not Yet Adopted	Recently Issued Accounting Standards Not Yet Adopted Brigham Minerals’ status as an emerging growth company ("EGC") under Section 107 of the JOBS Act permits it to delay the adoption of certain accounting standards until those standards would otherwise apply to private companies. Brigham Minerals is choosing to take advantage of this extended transition period and, as a result, it will comply with new or revised accounting standards on the relevant dates on which adoption of such standards is required for private companies. If Brigham loses its status as an EGC before the adoption dates for private companies, Brigham Minerals will be required to accelerate the adoption of new or revised accounting standards. In February 2016, the FASB issued ASU 2016-02, Leases, which requires all leasing arrangements to be presented in the balance sheet as liabilities along with a corresponding asset. ASU 2016-02 does not apply to leases of mineral rights to explore for or use crude oil and natural gas. The ASU will replace most existing lease guidance in GAAP when it becomes effective. In January 2018, the FASB issued ASU 2018-01, Land Easement Practical Expedient for Transition to Topic 842, to provide an optional practical expedient to not evaluate existing or expired land easements that were not previously accounted for as leases under Topic 840. In July 2018, the FASB issued ASU 2018-11 Leases (Topic 842): Targeted Improvements, which provides for another transition method, in addition to the existing transition method, by allowing entities to initially apply the new leases standard at the adoption date and recognize a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption (i.e. comparative periods presented in the financial statements will continue to be in accordance with current GAAP (Topic 840, Leases)). The new standard becomes effective for us during the fiscal year ending December 31, 2022 and interim periods within the fiscal year ending December 31, 2023 and early adoption is permitted. We are currently evaluating the impact that the adoption of this update will have on our consolidated and combined financial statements and related disclosures. In June 2016, the FASB issued ASU 2016-13, Financial Instruments—Credit Losses. In May 2019, ASU 2016-13 was subsequently amended by ASU 2019-04, Codification Improvements to Topic 326, Financial Instruments—Credit Losses and ASU 2019-05, Financial Instruments—Credit Losses (Topic 326): Targeted Transition Relief. ASU 2016-13, as amended, affects trade receivables, financial assets and certain other instruments that are not measured at fair value through net income. This ASU will replace the currently required incurred loss approach with an expected loss model for instruments measured at amortized cost and is effective for financial statements issued for fiscal years beginning after December 15, 2022, including interim periods within those fiscal years. ASU 2016-13 will be applied using a modified retrospective approach through a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is effective. We are currently evaluating the impact that the adoption of this update will have on our condensed consolidated and combined financial statements and related disclosures.
Fair Value Measurement	We classify financial assets and liabilities that are measured and reported at fair value on a recurring basis using a hierarchy based on the inputs used in measuring fair value. GAAP defines fair value 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 the measurement date (exit price). We classify the inputs used to measure fair value into the following hierarchy: • Level 1: Inputs based on quoted market prices in active markets for identical assets or liabilities at the measurement date. • Level 2: Inputs based on quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets and liabilities in markets that are not active or other inputs that are observable and can be corroborated by observable market data. • Level 3: Inputs that reflect management’s best estimates and assumptions of what market participants would use in pricing the asset or liability at the measurement date. The inputs are unobservable in the market and significant to the valuation of the instruments. Changes in economic conditions or model-based valuation techniques may require the transfer of financial instruments from one fair value level to another. In such instances, the transfer would be reported at the beginning of the period in which the change occurs.

Significant Accounting Polici_3

Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2020
Accounting Policies [Abstract]
Schedule of Accounts Receivable	At December 31, 2020 and 2019, accounts receivable was comprised of the following: December 31, (In thousands) 2020 2019 Oil and gas sales $ 17,413 $ 27,888 Allowance for doubtful accounts (855) (556) Other 1,074 2,959 Total accounts receivables $ 17,632 $ 30,291
Schedules of Concentration of Risk, by Risk Factor	Concentrations of oil and gas sales to significant customers (operators) are presented in the table below. For the year ended December 31, 2020 2019 2018 Occidental Petroleum Corp. 12 % 16 % 15 % Royal Dutch Shell 12 % — % — % Exxon Mobil Corp. 11 % 10 % — % Continental Resources, Inc. 10 % 12 % 10 %

Oil and Gas Properties (Tables)

Oil and Gas Properties (Tables)	12 Months Ended
	Dec. 31, 2020
Extractive Industries [Abstract]
Schedule of Oil and Gas Properties	Costs associated with general corporate activities are expensed in the period incurred. Oil and gas properties consisted of the following: December 31, (In thousands) 2020 2019 Oil and gas properties, at cost, using the full cost method of accounting: Not subject to depletion $ 325,091 $ 291,664 Subject to depletion 488,301 449,061 Total oil and gas properties, at cost 813,392 740,725 Less accumulated depreciation, depletion, and amortization (189,546) (61,103) Total oil and gas properties, net $ 623,846 $ 679,622 Costs not subject to depletion are as follows, by the year in which such costs were incurred: By Year: (In thousands) Total 2020 2019 2018 2017 2016 Prior Property Acquisition costs $ 325,091 $ 34,032 $ 80,799 $ 72,884 $ 65,925 $ 10,624 $ 60,827 For the Year Ended December 31, (In thousands) 2020 2019 2018 Oil and gas properties, at cost, using full cost method of accounting: Not subject to depletion $ 325,091 $ 291,664 $ 228,151 Subject to depletion 488,301 449,061 289,851 Total oil and gas properties, at cost 813,392 740,725 518,002 Less accumulated depreciation, depletion, and amortization (189,546) (61,103) (27,628) Total oil and gas properties, net $ 623,846 $ 679,622 $ 490,374

Acquisitions and Divestitures (

Acquisitions and Divestitures (Tables)	12 Months Ended
	Dec. 31, 2020
Business Combinations [Abstract]
Schedule of Asset Acquisitions	During the years ended December 31, 2020 and 2019, Brigham Minerals entered into a number of individually insignificant acquisitions of mineral and royalty interests from various sellers in Texas, Oklahoma, Colorado, New Mexico, and North Dakota, as reflected in the table below. The change in the oil and natural gas property balance is comprised of payments for acquisitions of minerals, land brokerage costs and capitalized general and administrative expenses that were funded with borrowings under its Owl Rock credit facility, our revolving credit facility and proceeds from the IPO. Assets Acquired Cash Consideration Paid (In thousands) Evaluated Unevaluated Year ended December 31, 2020 $ 30,856 $ 35,725 $ 66,581 Year ended December 31, 2019 $ 140,025 $ 78,093 $ 218,118 The following costs were incurred in oil and natural gas producing activities: For the Year Ended December 31, (In thousands) 2020 2019 2018 Acquisition of oil and gas properties Unevaluated $ 35,725 $ 78,093 $ 59,460 Evaluated 30,856 140,025 137,496 Total $ 66,581 $ 218,118 $ 196,956

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Gain (Loss) On Derivative Instruments	The following table summarizes Brigham Minerals' (loss) gain on derivative instruments, net on its consolidated and combined statement of operations for the year ended December 31, 2020, 2019 and 2018: Years Ended December 31, (In thousands) 2020 2019 2018 Realized gain (loss) $ — $ 470 $ (754) Unrealized (loss) gain — (1,038) 1,178 (Loss) gain on derivative instruments, net $ — $ (568) $ 424

Shareholders' and Members' Eq_2

Shareholders' and Members' Equity (Tables)	12 Months Ended
	Dec. 31, 2020
Equity [Abstract]
Schedule of Earnings Per Share, Basic and Diluted	The following table reflects the allocation of net income (loss) to common shareholders and EPS computations for the period indicated based on a weighted average number of common stock outstanding for the period: Years Ended December 31, (In thousands, except per share data) 2020 2019 2018 Basic EPS Numerator: Basic net (loss) income attributable to Brigham Minerals, Inc. shareholders $ (42,412) $ 6,901 $ — Less net income attributable to shareholders pre-IPO — (848) — Basic net (loss) income attributable to Brigham Minerals, Inc. shareholders post-IPO (1) (42,412) 6,053 — Denominator: Basic weighted average shares outstanding (1) 38,178 22,870 — Net (loss) income per common share $ (1.11) $ 0.26 $ — Diluted EPS Numerator: Basic net (loss) income attributable to Brigham Minerals, Inc. shareholders post-IPO (1) (42,412) 6,053 — Diluted net (loss) income attributable to Brigham Minerals, Inc. shareholders (42,412) 6,053 — Denominator: Basic weighted average shares outstanding (1) 38,178 22,870 — Effect of dilutive securities: — — — Diluted weighted average shares outstanding 38,178 22,870 — Net (loss) income per common share $ (1.11) $ 0.26 $ —

Temporary Equity (Tables)

Temporary Equity (Tables)	12 Months Ended
	Dec. 31, 2020
Temporary Equity Disclosure [Abstract]
Temporary Equity	From the date of the IPO through December 31, 2020, the Company recorded adjustments to the value of temporary equity as presented in the table below: (In thousands) Temporary equity adjustments Balance - April 17, 2019 (1) $ 518,000 Conversion of Class B shares to Class A shares (104,390) Net income attribution to temporary equity 9,646 Distribution to holders of temporary equity (20,321) Adjustment of temporary equity to redemption amount (2) 51,572 Balance - December 31, 2019 $ 454,507 Conversion of Class B shares to Class A shares (97,491) Net loss attribution to temporary equity (15,582) Distribution to holders of temporary equity (24,793) Adjustment of temporary equity to redemption amount (3) (170,361) Balance - December 31, 2020 $ 146,280 (1) Based on 28,777,802 shares of Class B common stock outstanding and Class A share price of $18.00. In connection with the IPO, the balance transferred from additional paid-in capital to temporary equity was the greater of redemption value or carrying value of the shares of Class B common stock at IPO and included an initial upward adjustment to redemption amount totaling $194.5 million. (2) Based on 22,847,045 shares of Class B common stock outstanding and Class A share 10-day VWAP of $19.89 at December 31, 2019. (3) Based on 13,167,687 shares of Class B common stock outstanding and Class A share 10-day VWAP of $11.11 at December 31, 2020.

Share-Based Compensation (Table

Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2020
Share-based Payment Arrangement [Abstract]
Schedule of Restricted Incentive Unit Activity	A summary of the Incentive Unit activity for the year ended December 31, 2020 is as follows: Incentive Units Number of Incentive Units Grant-date Fair Value Outstanding—January 1, 2020 212,733 $ 10.04 Vested (70,913) $ 10.04 Outstanding—December 31, 2020 141,820 $ 10.04 A summary of the RSU activity for the year ended December 31, 2020 is as follows: Restricted Stock Units Number of RSUs Grant Date Fair Value Unvested at January 1, 2020 415,815 $ 21.25 Granted 555,534 $ 16.41 Vested (392,528) $ 19.36 Forfeited (15,950) $ 20.57 Unvested at December 31, 2020 562,871 $ 17.81
Nonvested Restricted Stock Shares Activity	A summary of the RSA activity for the year ended December 31, 2020 is as follows: Restricted Stock Awards Number of RSAs Grant Date Fair Value Unvested at January 1, 2020 148,456 $ 21.25 Vested (69,594) $ 21.25 Forfeited (10,569) $ 21.25 Unvested at December 31, 2020 68,293 $ 21.25
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions	Years Ended December 31, 2020 2019 Expected dividend yield 11.5 % 8.1 % Risk-free interest rate 1.4 % 2.3 % Volatility 35 % 30 %
Schedule of Nonvested Performance-based Units Activity	A summary of the PSU activity for the year ended December 31, 2020 is as follows: Performance-Based Restricted Stock Units Target PSUs Estimated Earned PSUs Grant Date Fair Value Unvested at January 1, 2020 753,546 450,836 $ 20.36 Granted 434,265 174,106 $ 15.98 Unvested at December 31, 2020 1,187,811 624,942 $ 19.14
Schedule of Share-Based Compensation Expense	Share-based compensation cost recorded for each type of share-based compensation award, was as follows for the periods indicated: Years Ended December 31, (In thousands) 2020 2019 2018 Incentive Units (1) (3) $ 712 $ 2,904 $ — RSAs (2) (3) 1,254 3,972 — RSUs (3) 7,390 4,630 — PSUs (4) 4,259 2,361 — Capitalized share-based compensation (5) (6) (6,086) (3,818) — Total share-based compensation expense $ 7,529 $ 10,049 $ — (1) Includes a cumulative effect adjustment to share-based compensation cost of $2.0 million pertaining to the period from the grant date through the IPO date. No compensation expense was recorded prior to the IPO because the IPO was not considered probable. (2) Includes $3.2 million recorded at grant date of April 23, 2019, associated with 152,742 RSAs, which vested immediately during the year ended December 31, 2019. (3) Share-based compensation expense relating to Incentive Units, RSAs, and RSUs with ratable vesting is recognized on a straight-line basis over the requisite service period for the entire award. (4) Share-based compensation expense relating to PSUs with cliff-vesting is recognized on a straight-line basis over the performance period for the entire award. (5) During the year ended December 31, 2020, Brigham Minerals capitalized $3.0 million of the share-based compensation to unevaluated property and $3.0 million to evaluated property on its consolidated balance sheet. (6) Brigham Minerals capitalizes a portion of the share-based compensation cost incurred after the IPO . In addition to the time-based vesting conditions described above, the Incentive Units could be earned upon the completion of an initial public offering or another liquidity event, considered a performance condition, which was not deemed probable and therefore no compensation expense was recognized prior to December 31, 2018. Future Share-Based Compensation Expense The following table reflects the future share-based compensation expense to be recorded for the share-based compensation awards that were outstanding at December 31, 2020, a portion of which will be capitalized: (In thousands) Incentive Units RSAs RSUs PSUs Total Year 2021 712 726 6,851 4,374 12,663 2022 534 225 2,653 966 4,378 Total $ 1,246 $ 951 $ 9,504 $ 5,340 $ 17,041

Income Taxes Income Taxes (Tabl

Income Taxes Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2020
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit)	Years Ended December 31, (In thousands) 2020 2019 2018 State Income Tax Current expense/(benefit) $ 122 $ 692 $ (23) Deferred (benefit)/expense (1,876) 63 (138) Federal Income Tax Current (benefit)/expense (2,942) 1,322 114 Deferred (benefit)/expense (8,066) 602 374 Totals: $ (12,762) $ 2,679 $ 327 Total current income tax (benefit)/expense $ (2,820) $ 2,014 $ 91 Total deferred income tax (benefit)/expense (9,942) 665 236 Totals: $ (12,762) $ 2,679 $ 327
Schedule of Income before Income Tax, Domestic and Foreign	The following table reconciles the income tax provision with income tax expense at the federal statutory rate for the periods indicated: Years Ended December 31, (In thousands) 2020 2019 2018 (Loss) income before income taxes $ (70,756) $ 24,318 $ 33,142 Less: income before income taxes attributable to predecessor — (5,118) (30,805) Less: loss (income) before income taxes attributable to temporary equity 15,270 (9,858) — (Loss) income before income taxes attributable to shareholders $ (55,486) $ 9,342 $ 2,337 Income tax at the federal statutory rate $ (11,652) $ 1,962 $ 491 State income taxes, net of federal benefit (1,223) 717 (150) Other federal tax effects 113 — — Percentage depletion in excess of basis — — (14) Total income tax provision $ (12,762) $ 2,679 $ 327
Schedule of Deferred Tax Assets and Liabilities	The tax effects of temporary differences that give rise to significant portions of the deferred tax assets were are follows: Years Ended December 31, (In thousands) 2020 2019 Deferred tax assets: Loss carryforwards $ 627 $ — Investment in subsidiary 24,405 19,021 Total deferred tax assets: $ 25,032 $ 19,021 Deferred tax liabilities: Oil and gas properties $ (112) $ (198) Investment in subsidiary — — Total deferred tax liabilities $ (112) $ (198)

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
Schedule of Future Minimum Lease Commitments	Future minimum lease commitments under noncancelable operating leases at December 31, 2020 are presented below (in thousands): Year Commitment 2021 $ 1,272 2022 1,310 2023 1,347 2024 1,383 2025 1,419 2026 and Thereafter $ 2,251 Total $ 8,982

Quarterly Financial Informati_2

Quarterly Financial Information-Unaudited (Tables)	12 Months Ended
	Dec. 31, 2020
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Information	Summarized quarterly financial data for the years ended December 31, 2020 and 2019 are presented in the following tables. During the periods presented below, earnings per share information is not available due to no shares being recognized for accounting purposes for periods prior to the IPO. Quarter (In thousands, except per share amount) First Second Third Fourth Year ended December 31, 2020: Total revenues $ 32,280 $ 12,605 $ 23,078 $ 23,760 Income (loss) from operations - (3) 10,413 (7,144) (15,885) (57,678) Net income (loss) 8,801 (6,816) (13,017) (46,962) Net income (loss) attributable to Brigham Minerals, Inc. 4,706 (4,050) (9,465) (33,603) Basic EPS attributable to Brigham Minerals, Inc. shareholders $ 0.14 $ (0.11) $ (0.24) $ (0.78) Diluted EPS attributable to Brigham Minerals, Inc. shareholders $ 0.14 $ (0.11) $ (0.24) $ (0.78) Year ended December 31, 2019: Total revenues $ 18,265 $ 24,529 $ 25,107 $ 33,614 Income from operations 8,707 5,034 9,115 14,362 Net income (loss) 4,036 (3,207) 8,464 12,346 Net income (loss) attributable to Brigham Minerals, Inc. - (2) 534 (1,856) 3,146 5,077 Basic EPS attributable to Brigham Minerals, Inc. shareholders - (1) $ — $ (0.12) $ 0.14 $ 0.20 Diluted EPS attributable to Brigham Minerals, Inc. shareholders - (1) $ — $ (0.12) $ 0.14 $ 0.20 (1) Represents earnings per share of Class A common stock and weighted average shares of Class A common stock for the period from April 17, 2019 through December 31, 2019, the period following the IPO. See "Note 8— Shareholders' and Members' Equity" for additional information. (2) Represents net income attributable to Brigham Minerals for the period starting with the completion of the July 2018 restructuring. See "Note 1—Business and Basis of Presentation" for additional information.

Reserve and Related Financial_2

Reserve and Related Financial Data (SMOG) - Unaudited (Tables)	12 Months Ended
	Dec. 31, 2020
Extractive Industries [Abstract]
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities	The reserves at December 31, 2020, 2019, and 2018 presented below were audited by CG&A. Estimates of proved reserves are inherently imprecise and are continually subject to revision based on production history, results of additional exploration and development, price changes and other factors. The reserves are located in various fields in Texas, New Mexico, Oklahoma, Colorado, Wyoming, North Dakota, and Montana. All of the proved reserves are located in the continental United States. Crude Oil Natural Gas NGL Total Proved reserve quantities, December 31, 2017 8,724 38,401 3,980 19,104 Sales of minerals-in-place — — — — Extensions and discoveries 1,765 5,285 562 3,208 Acquisitions 3,669 13,862 1,374 7,354 Revisions of previous estimates (390) (3,245) (577) (1,508) Production (777) (2,507) (222) (1,417) Proved reserve quantities, December 31, 2018 12,991 51,796 5,117 26,741 Sales of minerals-in-place (182) (697) (110) (409) Extensions and discoveries 1,997 7,780 817 4,110 Acquisitions 4,256 13,053 1,218 7,651 Revisions of previous estimates (586) (5,495) (797) (2,299) Production (1,515) (4,707) (407) (2,706) Proved reserve quantities, December 31, 2019 16,961 61,730 5,838 33,088 Sales of minerals-in-place — (286) (1) (48) Extensions and discoveries 876 2,545 291 1,591 Acquisitions 1,235 3,652 331 2,174 Revisions of previous estimates (4,049) (18,188) (1,189) (8,271) Production (1,823) (5,809) (680) (3,471) Proved reserve quantities, December 31, 2020 13,200 43,644 4,590 25,063 Proved reserve quantities at December 31, 2020 attributable to temporary equity 3,064 10,131 1,065 5,818 Proved developed reserve quantities: December 31, 2018 6,067 21,735 1,898 11,588 December 31, 2019 9,924 33,232 2,494 17,957 December 31, 2020 9,403 31,873 3,426 18,141 Proved developed reserves at December 31, 2020 attributable to temporary equity 2,183 7,399 795 4,211 Proved undeveloped reserve quantities: December 31, 2018 6,924 30,061 3,219 15,153 December 31, 2019 7,037 28,498 3,344 15,131 December 31, 2020 3,797 11,771 1,164 6,922 Proved undeveloped reserves at December 31, 2020 attributable to temporary equity 881 2,732 270 1,607
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure	The following summary sets forth the future net cash flows relating to proved oil and gas reserves based on the standardized measure prescribed in ASC Topic 932: For the Year Ended December 31, (In thousands) 2020 2019 2018 Future crude oil, natural gas, and NGL sales $ 562,545 $ 1,042,118 $ 1,049,141 Future severance tax and ad valorem taxes (39,318) (73,627) (70,248) Future income tax expense (46,908) (143,599) (144,421) Future net cash flows 476,319 824,892 834,472 10% annual discount (205,551) (359,258) (391,013) Standardized measure of discounted future net cash flows $ 270,768 $ 465,634 $ 443,459 Standardized measure of discounted future net cash flows attributable to temporary equity $ 62,853 $ 186,999 $ —
Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure	The following prices were used in the determination of standardized measure: For the Year Ended December 31, 2020 2019 2018 Oil (per Bbl) $ 36.35 $ 51.01 $ 61.31 Natural gas (per Mcf) 1.03 1.51 2.51 NGLs (per Bbl) 8.19 14.39 23.98
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows	The principal sources of change in the standardized measure of discounted future net cash flows are: For the Year Ended December 31, (In thousands) 2020 2019 2018 Standardized measure of discounted future net cash flows, beginning of the year $ 465,634 $ 443,459 $ 316,468 Changes in the year resulting from: Sales, less production costs (73,654) (86,492) (52,278) Revisions of previous quantity estimates (135,926) (41,539) (22,942) Extensions, discoveries, and other additions 21,011 69,057 71,668 Net change in prices and production costs (131,886) (99,660) 71,770 Accretion of discount 54,741 51,949 31,713 Purchase of reserves in place 27,241 137,819 148,580 Divestitures of reserves in place (250) (5,783) — Net change in taxes 53,786 (5,739) (75,369) Timing differences and other (9,929) 2,563 (46,151) Standardized measure of discounted future net cash flows, end of the year $ 270,768 $ 465,634 $ 443,459
Schedule of Capitalized Oil and Natural Gas Costs	Costs associated with general corporate activities are expensed in the period incurred. Oil and gas properties consisted of the following: December 31, (In thousands) 2020 2019 Oil and gas properties, at cost, using the full cost method of accounting: Not subject to depletion $ 325,091 $ 291,664 Subject to depletion 488,301 449,061 Total oil and gas properties, at cost 813,392 740,725 Less accumulated depreciation, depletion, and amortization (189,546) (61,103) Total oil and gas properties, net $ 623,846 $ 679,622 Costs not subject to depletion are as follows, by the year in which such costs were incurred: By Year: (In thousands) Total 2020 2019 2018 2017 2016 Prior Property Acquisition costs $ 325,091 $ 34,032 $ 80,799 $ 72,884 $ 65,925 $ 10,624 $ 60,827 For the Year Ended December 31, (In thousands) 2020 2019 2018 Oil and gas properties, at cost, using full cost method of accounting: Not subject to depletion $ 325,091 $ 291,664 $ 228,151 Subject to depletion 488,301 449,061 289,851 Total oil and gas properties, at cost 813,392 740,725 518,002 Less accumulated depreciation, depletion, and amortization (189,546) (61,103) (27,628) Total oil and gas properties, net $ 623,846 $ 679,622 $ 490,374
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure	During the years ended December 31, 2020 and 2019, Brigham Minerals entered into a number of individually insignificant acquisitions of mineral and royalty interests from various sellers in Texas, Oklahoma, Colorado, New Mexico, and North Dakota, as reflected in the table below. The change in the oil and natural gas property balance is comprised of payments for acquisitions of minerals, land brokerage costs and capitalized general and administrative expenses that were funded with borrowings under its Owl Rock credit facility, our revolving credit facility and proceeds from the IPO. Assets Acquired Cash Consideration Paid (In thousands) Evaluated Unevaluated Year ended December 31, 2020 $ 30,856 $ 35,725 $ 66,581 Year ended December 31, 2019 $ 140,025 $ 78,093 $ 218,118 The following costs were incurred in oil and natural gas producing activities: For the Year Ended December 31, (In thousands) 2020 2019 2018 Acquisition of oil and gas properties Unevaluated $ 35,725 $ 78,093 $ 59,460 Evaluated 30,856 140,025 137,496 Total $ 66,581 $ 218,118 $ 196,956

Business and Basis of Present_2

Business and Basis of Presentation (Details)	Sep. 15, 2020USD ($)$ / sharesshares	Jun. 12, 2020USD ($)$ / sharesshares	Dec. 16, 2019USD ($)$ / sharesshares	May 07, 2019USD ($)	Apr. 17, 2019USD ($)$ / sharesshares	Apr. 30, 2019	Dec. 31, 2020USD ($)segment	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Jul. 16, 2018
Schedule of Equity Method Investments [Line Items]
Proceeds from issuance of common stock | $							$ 0	$ 102,680,000	$ 0
Number of operating segments | segment							1
Brigham LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage by subsidiary					43.30%	43.30%
Percentage of voting rights owned					100.00%
Brigham Resources
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage										16.50%
Initial Public Offering
Schedule of Equity Method Investments [Line Items]
Consideration received | $					$ 273,400,000
Initial Public Offering | Class A Common Stock
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)					16,675,000
Share price (in dollars per share) | $ / shares					$ 18
December Offering | Class A Common Stock
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)			12,650,000
December Offering, Company
Schedule of Equity Method Investments [Line Items]
Consideration received | $			$ 102,700,000
December Offering, Company | Class A Common Stock
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)			6,000,000
December Offering, Selling Shareholders | Class A Common Stock
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)			6,650,000
Share price (in dollars per share) | $ / shares			$ 18.10
Share price, net (in dollars per share) | $ / shares			$ 17.376
December Offering, Equivalent Units Issued | Class A Common Stock
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)			5,496,813
June Offering | Class A Common Stock
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)		6,600,000
Share price (in dollars per share) | $ / shares		$ 13.75
Proceeds from issuance of common stock | $		$ 0
June Offering, Equivalent Units Issued By Selling Shareholders | Class A Common Stock
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)		4,872,669
September Offering | Brigham LLC
Schedule of Equity Method Investments [Line Items]
Sale of stock, ownership percentage							76.80%
September Offering | Existing Owners of Brigham Minerals | Brigham LLC
Schedule of Equity Method Investments [Line Items]
Sale of stock, ownership percentage							23.20%
September Offering | Other Entities Affiliated With Yorktown Partners L L C And Pine Brook Road Advisors L P Collectively The Sponsors | Brigham Minerals
Schedule of Equity Method Investments [Line Items]
Sale of stock, ownership percentage							16.90%
September Offering | Class A Common Stock
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)	5,021,140
Share price (in dollars per share) | $ / shares	$ 8.20
Proceeds from issuance of common stock | $	$ 0
Purchase of treasury stock (in shares)	436,630
September Offering, Over-Allotment Option | Class A Common Stock
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)	654,931
September Offering, Equivalent Units Issued By Selling Shareholders | Class A Common Stock
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)	3,062,011
New Revolving Credit Facility
Schedule of Equity Method Investments [Line Items]
Repayments of lines of credit | $			$ 80,000,000	$ 200,000,000

Significant Accounting Polici_4

Significant Accounting Policies - Narrative (Details) - USD ($) $ in Thousands	May 07, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Increase in investing cash flow		$ (65,425)	$ (216,832)	$ (195,268)
Accounts Receivable, Allowance For Doubtful Accounts		300	600
Share based compensation expense		$ 17,041
Employer matching contribution, percent of match		100.00%
Employer matching contribution, percent of employees' total compensation		6.00%
Contributions		$ 400	300	200
Timing of satisfaction of performance obligation and payment		The Company typically receives payment for oil, natural gas and NGL sales within 60 days of the month of delivery, which can extend up to 9 months after initial production from the well.
Debt issuance costs		$ 800	1,200
Accumulated amortization of debt issuance costs		800	200
Amortization of debt issuance costs		605	$ 433	$ 690
Unamortized debt issuance costs written off	$ 4,000	$ 300

Significant Accounting Polici_5

Significant Accounting Policies - Schedule of Accounts Receivable (Details) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019
Accounting Policies [Abstract]
Oil and gas sales	$ 17,413	$ 27,888
Allowance for doubtful accounts	(855)	(556)
Other	1,074	2,959
Total accounts receivables	$ 17,632	$ 30,291

Significant Accounting Polici_6

Significant Accounting Policies - Schedule of Concentration Risk (Details) - Sales Revenue, Product Line - Customer Concentration Risk	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Occidental Petroleum Corp.
Concentration Risk [Line Items]
Concentration risk (as a percentage)	12.00%	16.00%	15.00%
Royal Dutch Shell
Concentration Risk [Line Items]
Concentration risk (as a percentage)	12.00%	0.00%	0.00%
Exxon Mobil Corp.
Concentration Risk [Line Items]
Concentration risk (as a percentage)	11.00%	10.00%	0.00%
Continental Resources, Inc.
Concentration Risk [Line Items]
Concentration risk (as a percentage)	10.00%	12.00%	10.00%

Oil and Gas Properties - Schedu

Oil and Gas Properties - Schedule of Oil and Gas Properties (Details) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Oil and gas properties, at cost, using the full cost method of accounting:
Not subject to depletion	$ 325,091	$ 291,664
Subject to depletion	488,301	449,061
Total oil and gas properties, at cost	813,392	740,725
Less accumulated depreciation, depletion, and amortization	(189,546)	(61,103)
Total oil and gas properties, net	623,846	679,622
Costs not subject to depletion, cost per year	$ 34,032	$ 80,799	$ 72,884	$ 65,925	$ 10,624	$ 60,827

Oil and Gas Properties - Narrat

Oil and Gas Properties - Narrative (Details) $ in Thousands	3 Months Ended		12 Months Ended
	Dec. 31, 2020USD ($)	Sep. 30, 2020USD ($)	Dec. 31, 2020USD ($)MMBoeMBoe$ / Boe	Dec. 31, 2019USD ($)$ / Boe	Dec. 31, 2018USD ($)$ / Boe
Extractive Industries [Abstract]
Depletion expense			$ 47,300	$ 30,400	$ 13,300
Full cost pool depletion per barrel of oil equivalent | $ / Boe			13.63	11.22	9.38
Capitalized costs			$ 10,200	$ 7,400	$ 2,700
Impairment of oil and gas properties	$ 60,700	$ 18,900	$ 79,569	$ 0	$ 0
Decrease in proved undeveloped reserves (in Mboe) | MBoe			8,209
Reclassification from proved to probable and possible reserves | MMBoe			7,036

Acquisitions and Divestitures -

Acquisitions and Divestitures - Schedule of Acquisitions (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Business Acquisition [Line Items]
Assets acquired, evaluated	$ 30,856	$ 140,025	$ 137,496
Assets acquired, unevaluated	35,725	78,093	59,460
Total	66,581	218,118	$ 196,956
Texas, Oklahoma, Colorado, New Mexico, North Dakota
Business Acquisition [Line Items]
Assets acquired, evaluated	30,856	140,025
Assets acquired, unevaluated	35,725	78,093
Total	$ 66,581	$ 218,118

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details) - USD ($) $ in Millions	May 31, 2019	Jul. 31, 2018
Brigham Resources, LLC
Derivative [Line Items]
Cash collateral posted for existing swap contracts	$ 1.6	$ 1.4

Derivative Instruments - Schedu

Derivative Instruments - Schedule of Gains (Losses) on Derivatives (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Realized gain (loss)	$ 0	$ 470	$ (754)
Unrealized (loss) gain	0	(1,038)	1,178
(Loss) gain on derivative instruments, net	$ 0	$ (568)	$ 424

Long-Term Debt (Details)

Long-Term Debt (Details)	May 16, 2019	May 07, 2019USD ($)	Jul. 27, 2018USD ($)	Sep. 30, 2018USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Jul. 26, 2018USD ($)
Debt Instrument [Line Items]
Unamortized debt issuance costs written off		$ 4,000,000			$ 300,000
Loss on extinguishment of debt		6,900,000			0	$ 6,892,000	$ 0
Prepayment premium paid					0	$ 2,091,000	$ 0
Term Loan Facility
Debt Instrument [Line Items]
Line of credit, borrowing base			$ 125,000,000
Prepayment premium paid		2,100,000
Legal fees paid		$ 800,000
Term Loan Facility | Base Rate
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)			4.50%
Term Loan Facility | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)			5.50%
Term Loan Facility | London Interbank Offered Rate (LIBOR) | Minimum
Debt Instrument [Line Items]
Interest rate, floor (as a percent)			1.00%
Delayed Draw Term Loan
Debt Instrument [Line Items]
Line of credit, borrowing base			$ 75,000,000
Revolving Credit Facility
Debt Instrument [Line Items]
Line of credit, borrowing base					135,000,000			$ 150,000,000
Line of credit facility available			70,000,000
Unamortized debt issuance costs written off				$ 300,000
Long-term debt outstanding			70,000,000
Outstanding borrowings					20,000,000
Remaining borrowing availability					$ 115,000,000
Revolving Credit Facility | Term Loan Facility
Debt Instrument [Line Items]
Line of credit, borrowing base			$ 10,000,000
Brigham Resources, LLC | New Revolving Credit Facility
Debt Instrument [Line Items]
Debt instrument, covenant, current ratio, minimum	1
Debt instrument, covenant, total net funded debt to consolidated EBITDA ratio, maximum	4
Brigham Resources, LLC | New Revolving Credit Facility | Interest period, one month
Debt Instrument [Line Items]
Interest payment, period (in months)	1 month
Brigham Resources, LLC | New Revolving Credit Facility | Interest period, two months
Debt Instrument [Line Items]
Interest payment, period (in months)	2 months
Brigham Resources, LLC | New Revolving Credit Facility | Interest period, three months
Debt Instrument [Line Items]
Interest payment, period (in months)	3 months
Brigham Resources, LLC | New Revolving Credit Facility | Interest period, six months
Debt Instrument [Line Items]
Interest payment, period (in months)	6 months
Brigham Resources, LLC | New Revolving Credit Facility | Interest period, twelve months
Debt Instrument [Line Items]
Interest payment, period (in months)	12 months
Brigham Resources, LLC | New Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Commitment fee, percentage	0.375%
Brigham Resources, LLC | New Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Commitment fee, percentage	0.50%
Brigham Resources, LLC | New Revolving Credit Facility | London Interbank Offered Rate (LIBOR) | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)	1.75%
Brigham Resources, LLC | New Revolving Credit Facility | London Interbank Offered Rate (LIBOR) | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)	2.75%
Brigham Resources, LLC | New Revolving Credit Facility | Adjusted Base Rate | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)	0.75%
Brigham Resources, LLC | New Revolving Credit Facility | Adjusted Base Rate | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)	1.75%

Shareholders' and Members' Eq_3

Shareholders' and Members' Equity - Narrative (Details)	Sep. 15, 2020$ / sharesshares	Dec. 31, 2020voteshares	Dec. 31, 2019shares
Class of Stock [Line Items]
Treasury stock (in shares)		436,630	0
Class A Common Stock
Class of Stock [Line Items]
Common stock outstanding (in shares)		43,558,494	34,040,934
Number of votes per share (vote) | vote		1
Class A Common Stock | September Offering
Class of Stock [Line Items]
Purchase of treasury stock (in shares)	436,630
Stock repurchased, average cost (in dollars per share) | $ / shares	$ 8.08
Class B Common Stock
Class of Stock [Line Items]
Common stock outstanding (in shares)		13,167,687	22,847,045
Number of votes per share (vote) | vote		1
Performance-Based Restricted Stock Units
Class of Stock [Line Items]
Shares granted during period (in shares)		1,187,811

Shareholders' and Members' Eq_4

Shareholders' and Members' Equity - Schedule of Earnings per Share, Basic and Diluted (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended								4 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Apr. 16, 2019	Dec. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Numerator:
Basic net income attributable to Brigham Minerals, Inc. shareholders									$ 848	$ 6,053	$ (42,412)	$ 6,901	$ 1,839
Less: net income attributable to Brigham Minerals, Inc. shareholders pre-IPO											0	(848)
Basic net income attributable to Brigham Minerals, Inc. shareholders post-IPO											$ (42,412)	$ 6,053
Denominator:
Basic weighted average shares outstanding (in shares)											38,178	22,870	0
Basic EPS attributable to Brigham Minerals, Inc. stockholders (in dollars per share)	$ (0.78)	$ (0.24)	$ (0.11)	$ 0.14	$ 0.20	$ 0.14	$ (0.12)	$ 0			$ (1.11)	$ 0.26	$ 0
Numerator:
Diluted net income attributable to Brigham Minerals, Inc. shareholders											$ (42,412)	$ 6,053
Denominator:
Basic weighted average shares outstanding (in shares)											38,178	22,870	0
Effect of dilutive securities (in shares)											0	0
Diluted weighted average shares outstanding (in shares)											38,178	22,870	0
Diluted EPS attributable to Brigham Minerals, Inc. stockholders (in dollars per share)	$ (0.78)	$ (0.24)	$ (0.11)	$ 0.14	$ 0.20	$ 0.14	$ (0.12)	$ 0			$ (1.11)	$ 0.26	$ 0

Temporary Equity (Details)

Temporary Equity (Details) $ / shares in Units, $ in Thousands	Apr. 17, 2019USD ($)$ / sharesshares	Dec. 31, 2019USD ($)$ / sharesshares	Dec. 30, 2019USD ($)	Dec. 31, 2020USD ($)vote$ / sharesshares
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance				$ 454,507
Conversion of Class B shares to Class A shares			$ (104,390)	(97,491)
Net loss attribution to temporary equity			9,646	(15,582)
Distribution to holders of temporary equity			(20,321)	(24,793)
Adjustment of temporary equity to redemption amount	$ 194,500	$ 51,572	$ 51,572	(170,361)
Ending balance	$ 518,000	$ 454,507		$ 146,280
Class B Common Stock
Temporary Equity [Line Items]
Number of votes per share (vote) | vote				1
Conversion of stock, shares received (in shares) | shares	1
Increase (Decrease) in Temporary Equity [Roll Forward]
Temporary equity (in shares) | shares	28,777,802	22,847,045		13,167,687
Temporary equity, share price (in dollars per share) | $ / shares		$ 19.89		$ 11.11
Common Class A
Temporary Equity [Line Items]
Number of votes per share (vote) | vote				1
Conversion of stock, shares received (in shares) | shares	1
Existing Owners of Brigham Minerals | Class B Common Stock
Temporary Equity [Line Items]
Number of votes per share (vote) | vote				1
Initial Public Offering | Common Class A
Increase (Decrease) in Temporary Equity [Roll Forward]
Share price (in dollars per share) | $ / shares	$ 18

Share-Based Compensation - Narr

Share-Based Compensation - Narrative (Details) - USD ($) $ / shares in Units, $ in Thousands	Apr. 23, 2019	Apr. 17, 2019	Dec. 31, 2020	Dec. 31, 2019	May 08, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares surrendered for tax withholdings on vested equity awards			$ 185
Class B Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Conversion of stock, shares received (in shares)		1
Class A Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Conversion of stock, shares received (in shares)		1
Incentive Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares authorized (in shares)					120,000
Award vesting percentage at grant (as a percent)			20.00%
Award vesting percentage on each anniversary (as a percent)			20.00%
Conversion of stock, shares received (in shares)		1
Shares vested during period (in shares)			70,913
Nonvested PSUs (in shares)			141,820	212,733
RSAs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted during period, grant date fair value (in dollars per share)	$ 21.25
Shares granted during period (in shares)	312,189
Shares vested during period (in shares)	152,742		69,594
Vesting increments	0.3334%
Nonvested PSUs (in shares)			68,293	148,456
Restricted stock units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted during period, grant date fair value (in dollars per share)			$ 16.41
Shares granted during period (in shares)			555,534
Shares vested during period (in shares)			392,528
Shares withheld to satisfy employee tax withholding (in shares)			88,476
Shares surrendered for tax withholdings on vested equity awards			$ 1,000
Nonvested PSUs (in shares)			562,871	415,815
Performance-Based Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted during period, grant date fair value (in dollars per share)			$ 15.98
Shares granted during period (in shares)			1,187,811
Performance period (in years)			3 years
Performance-Based Restricted Stock Units | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting percentage at grant (as a percent)	0.00%
Performance-Based Restricted Stock Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting percentage at grant (as a percent)	200.00%
Target PSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted during period (in shares)			434,265
Nonvested PSUs (in shares)			1,187,811	753,546
Long Term Incentive Plan | Class A Common Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares authorized (in shares)			5,999,600
Shares available for future grants (in shares)			3,548,923

Share-Based Compensation - Summ

Share-Based Compensation - Summary of Stock Activity (Details) - $ / shares	Apr. 23, 2019	Dec. 31, 2020
Incentive Units
Number of Incentive Units
Beginning balance (in shares)		212,733
Vested (in shares)		(70,913)
Ending balance (in shares)		141,820
Grant-date Fair Value
Beginning balance (in dollars per share)		$ 10.04
Grant-date fair value, Vested (in dollars per share)		10.04
Ending balance (in dollars per share)		$ 10.04
RSAs
Number of Incentive Units
Beginning balance (in shares)		148,456
Granted (in shares)	312,189
Vested (in shares)	(152,742)	(69,594)
Forfeited (in shares)		(10,569)
Ending balance (in shares)		68,293
Grant-date Fair Value
Beginning balance (in dollars per share)		$ 21.25
Grant-date fair value, Granted (in dollars per share)	$ 21.25
Grant-date fair value, Vested (in dollars per share)		21.25
Grant-date fair value, Forfeited (in dollars per share)		21.25
Ending balance (in dollars per share)		$ 21.25
RSUs
Number of Incentive Units
Beginning balance (in shares)		415,815
Granted (in shares)		555,534
Vested (in shares)		(392,528)
Forfeited (in shares)		(15,950)
Ending balance (in shares)		562,871
Grant-date Fair Value
Beginning balance (in dollars per share)		$ 21.25
Grant-date fair value, Granted (in dollars per share)		16.41
Grant-date fair value, Vested (in dollars per share)		19.36
Grant-date fair value, Forfeited (in dollars per share)		20.57
Ending balance (in dollars per share)		$ 17.81
Target PSUs
Number of Incentive Units
Beginning balance (in shares)		753,546
Granted (in shares)		434,265
Ending balance (in shares)		1,187,811
Estimated Earned PSUs
Number of Incentive Units
Beginning balance (in shares)		450,836
Granted (in shares)		174,106
Ending balance (in shares)		624,942
Performance-Based Restricted Stock Units
Number of Incentive Units
Granted (in shares)		1,187,811
Grant-date Fair Value
Beginning balance (in dollars per share)		$ 20.36
Grant-date fair value, Granted (in dollars per share)		15.98
Ending balance (in dollars per share)		$ 19.14

Share-Based Compensation - Weig

Share-Based Compensation - Weighted Average Assumptions (Details) - Performance-Based Restricted Stock Units	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected dividend yield (as a percent)	11.50%	8.10%
Risk-free interest rates	1.40%	2.30%
Expected volatility (as a percent)	35.00%	30.00%

Share-Based Compensation - Sche

Share-Based Compensation - Schedule of Compensation Expense and Future Stock Compensation Expense (Details) - USD ($) $ in Thousands	Apr. 23, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Capitalized share-based compensation		$ (6,086)	$ (3,818)	$ 0
Total share-based compensation expense		7,529	10,049	0
Future share-based compensation expense		17,041
Unevaluated Oil and Gas Property
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Capitalized share-based compensation		(3,000)
Evaluated Oil and Gas Property
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Capitalized share-based compensation		(3,000)
2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		12,663
2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		4,378
Incentive Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense		712	2,904	0
Compensation expense, cumulative effect adjustment at IPO		$ 2,000
Shares vested during period (in shares)		70,913
Future share-based compensation expense		$ 1,246
Incentive Units | 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		712
Incentive Units | 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		534
RSAs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 3,200	$ 1,254	3,972	0
Shares vested during period (in shares)	152,742	69,594
Future share-based compensation expense		$ 951
RSAs | 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		726
RSAs | 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		225
RSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense		$ 7,390	4,630	0
Shares vested during period (in shares)		392,528
Future share-based compensation expense		$ 9,504
RSUs | 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		6,851
RSUs | 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		2,653
PSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense		4,259	$ 2,361	$ 0
Future share-based compensation expense		5,340
PSUs | 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		4,374
PSUs | 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		$ 966

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($) $ / shares in Units, $ in Thousands	Dec. 16, 2019	Apr. 17, 2019	Sep. 30, 2019	Dec. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Jul. 31, 2018
Operating Loss Carryforwards [Line Items]
Net deferred tax liability resulting from corporate reorganization				$ 198	$ 112	$ 198		$ 3,100
Deferred tax asset arising from the IPO			$ 13,700	13,664
Deferred tax asset arising from issuance of common stock in the December 2019 Offering					$ (9,500)	800	$ 2,800
Effective income tax rate (as a percent)					18.00%
Total income tax provision					$ (12,762)	2,679	$ 327
Deferred tax asset				18,823	$ 24,920	$ 18,823
December Offering
Operating Loss Carryforwards [Line Items]
Deferred tax asset arising from the IPO				$ 9,508
Class A Common Stock | Initial Public Offering
Operating Loss Carryforwards [Line Items]
Sale of stock, number of shares issued (in shares)		16,675,000
Share price (in dollars per share)		$ 18
Class A Common Stock | December Offering
Operating Loss Carryforwards [Line Items]
Sale of stock, number of shares issued (in shares)	12,650,000
Class A Common Stock | December Offering, Company
Operating Loss Carryforwards [Line Items]
Sale of stock, number of shares issued (in shares)	6,000,000
Class A Common Stock | December Offering, Selling Shareholders
Operating Loss Carryforwards [Line Items]
Sale of stock, number of shares issued (in shares)	6,650,000
Share price (in dollars per share)	$ 18.10
Class A Common Stock | December Offering, Equivalent Units Issued
Operating Loss Carryforwards [Line Items]
Sale of stock, number of shares issued (in shares)	5,496,813

Income Taxes - Schedule of Comp

Income Taxes - Schedule of Components of Income Tax Expense (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Current expense/(benefit)	$ 122	$ 692	$ (23)
Deferred (benefit)/expense	(1,876)	63	(138)
Current (benefit)/expense	(2,942)	1,322	114
Deferred (benefit)/expense	(8,066)	602	374
Total income tax provision	(12,762)	2,679	327
Total current income tax (benefit)/expense	(2,820)	2,014	91
Total deferred income tax (benefit)/expense	$ (9,942)	$ 665	$ 236

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Income Tax Expense With Income Tax Provision (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Income Tax Disclosure [Abstract]
(Loss) income before income taxes	$ (70,756)	$ 24,318	$ 33,142
Less: income before income taxes attributable to predecessor	0	(5,118)	(30,805)
Less: loss (income) before income taxes attributable to temporary equity	15,270	(9,858)	0
(Loss) income before income taxes attributable to shareholders	(55,486)	9,342	2,337
Income tax at the federal statutory rate	(11,652)	1,962	491
State income taxes, net of federal benefit	(1,223)	717	(150)
Other federal tax effects	113	0	0
Percentage depletion in excess of basis	0	0	(14)
Total income tax provision	$ (12,762)	$ 2,679	$ 327

Income Taxes - Schedule of Defe

Income Taxes - Schedule of Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019	Jul. 31, 2018
Deferred tax assets:
Loss carryforwards	$ 627	$ 0
Investment in subsidiary	24,405	19,021
Total deferred tax assets:	25,032	19,021
Deferred tax liabilities:
Oil and gas properties	(112)	(198)
Investment in subsidiary	0	0
Net noncurrent deferred tax liabilities	$ (112)	$ (198)	$ (3,100)

Commitments and Contingencies_2

Commitments and Contingencies (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Rent expense	$ 1,100	$ 600	$ 300
2021	1,272
2022	1,310
2023	1,347
2024	1,383
2025	1,419
2026 and Thereafter	2,251
Total	$ 8,982

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Land Brokerage Services | Brigham Land Management
Related Party Transaction [Line Items]
Related party transaction, amount		$ 0.1	$ 0.1
Leasing of Acreage Arrangement | Ben M. Brigham
Related Party Transaction [Line Items]
Amount received from related party		0.4
Service Agreement For Evaluating The Acquisition Of Mineral Interests | RS Energy Group | Maximum
Related Party Transaction [Line Items]
Related party transaction, amount	$ 0.1	$ 0.2
Borrowings From Related Party | Brigham Operating
Related Party Transaction [Line Items]
Amount received from related party			$ 7
Related party transaction, interest rate (as a percent)			7.00%

COVID-19 Pandemic and Impact _2

COVID-19 Pandemic and Impact on Global Demand for Oil and Natural Gas (Details)	12 Months Ended
	Dec. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
Office capacity, percent reopened	75.00%

Subsequent Events (Details)

Subsequent Events (Details)	Feb. 19, 2021$ / shares
Common Class A | Subsequent Event
Subsequent Event [Line Items]
Dividends declared (in dollars per share)	$ 0.26

Quarterly Financial Informati_3

Quarterly Financial Information-Unaudited (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Quarterly Financial Information Disclosure [Abstract]
Total revenues	$ 23,760	$ 23,078	$ 12,605	$ 32,280	$ 33,614	$ 25,107	$ 24,529	$ 18,265	$ 91,723	$ 101,515	$ 67,264
Income (loss) from operations	(57,678)	(15,885)	(7,144)	10,413	14,362	9,115	5,034	8,707	(70,294)	37,218	39,231
Net income (loss)	(46,962)	(13,017)	(6,816)	8,801	12,346	8,464	(3,207)	4,036	$ (57,994)	$ 21,639	$ 32,815
Net income (loss) attributable to Brigham Minerals, Inc.	$ (33,603)	$ (9,465)	$ (4,050)	$ 4,706	$ 5,077	$ 3,146	$ (1,856)	$ 534
Basic EPS attributable to Brigham Minerals, Inc. stockholders (in dollars per share)	$ (0.78)	$ (0.24)	$ (0.11)	$ 0.14	$ 0.20	$ 0.14	$ (0.12)	$ 0	$ (1.11)	$ 0.26	$ 0
Diluted EPS attributable to Brigham Minerals, Inc. stockholders (in dollars per share)	$ (0.78)	$ (0.24)	$ (0.11)	$ 0.14	$ 0.20	$ 0.14	$ (0.12)	$ 0	$ (1.11)	$ 0.26	$ 0
Impairment of oil and gas properties	$ 60,700	$ 18,900							$ 79,569	$ 0	$ 0

Reserve and Related Financial_3

Reserve and Related Financial Data (SMOG) - Unaudited - Schedule of Proved Reserve Quantities (Details) MMcf in Thousands, MMBoe in Thousands, MBbls in Thousands	12 Months Ended
	Dec. 31, 2020MBoewellMMcfMBbls	Dec. 31, 2019MBoewellMBblsMMcf	Dec. 31, 2018MBoewellMMcfMBbls	Dec. 31, 2018MBoewellMBblsMMcf	Dec. 31, 2018MBoewellMBblsMMcf	Dec. 31, 2018MBoeMMBoewellMBblsMMcf
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Beginning balance | MBoe	33,088,000	26,741,000			19,104,000
Sales of minerals-in-place | MBoe	(48,000)	(409,000)			0
Extensions and discoveries | MBoe	1,591,000	4,110,000			3,208,000
Acquisitions | MBoe	2,174,000	7,651,000			7,354,000
Revisions of previous estimates	8,271,000	2,299,000			(1,508,000)	(1,508)
Production | MBoe	(3,471,000)	(2,706,000)			(1,417,000)
Ending balance | MBoe	25,063,000	33,088,000			26,741,000
Proved reserve quantities at December 31, 2020 attributable to temporary equity | MBoe	5,818,000
Proved developed reserve quantities | MBoe	18,141,000	17,957,000	11,588,000	11,588,000	11,588,000	11,588,000
Proved developed reserves at December 31, 2020 attributable to temporary equity | MBoe	4,211,000
Proved undeveloped reserve quantities | MBoe	6,922,000	15,131,000	15,153,000	15,153,000	15,153,000	15,153,000
Proved undeveloped reserves at December 31, 2020 attributable to temporary equity | MBoe	1,607,000
Number of well locations | well	342	900	555	555	555	555
Permian, DJ, Anadarko and Williston Basins
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Sales of minerals-in-place | MBoe	(48)	(409,000)
Acquisitions | MBoe	2,174	7,651,000			7,354,000
Crude Oil (MBbl)
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning balance	16,961	12,991	8,724
Sales of minerals-in-place	0	(182)	0
Extensions and discoveries	876	1,997	1,765
Acquisitions	1,235	4,256	3,669
Revisions of previous estimates	(4,049)	(586)	(390)
Production	(1,823)	(1,515)	(777)
Ending balance	13,200	16,961	12,991
Proved reserve quantities at December 31, 2020 attributable to temporary equity	3,064
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Proved developed reserve quantities	9,403	9,924	6,067	6,067	6,067	6,067
Proved developed reserves at December 31, 2020 attributable to temporary equity	2,183
Proved undeveloped reserve quantities	3,797	7,037	6,924	6,924	6,924	6,924
Proved undeveloped reserves at December 31, 2020 attributable to temporary equity	881
Natural Gas (MMcf)
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning balance | MMcf	61,730	51,796		38,401
Sales of minerals-in-place | MMcf	(286)	(697)		0
Extensions and discoveries | MMcf	2,545	7,780		5,285
Acquisitions | MMcf	3,652	13,053		13,862
Revisions of previous estimates | MMcf	(18,188)	(5,495)		(3,245)
Production | MMcf	(5,809)	(4,707)		(2,507)
Ending balance | MMcf	43,644	61,730		51,796
Proved reserve quantities at December 31, 2020 attributable to temporary equity | MMcf	10,131
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Proved developed reserve quantities | MMcf	31,873	33,232	21,735	21,735	21,735	21,735
Proved developed reserves at December 31, 2020 attributable to temporary equity | MMcf	7,399
Proved undeveloped reserve quantities | MMcf	11,771	28,498	30,061	30,061	30,061	30,061
Proved undeveloped reserves at December 31, 2020 attributable to temporary equity | MMcf	2,732
NGL (MBbl)
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning balance	5,838	5,117	3,980
Sales of minerals-in-place	(1)	(110)	0
Extensions and discoveries	291	817	562
Acquisitions	331	1,218	1,374
Revisions of previous estimates	(1,189)	(797)	(577)
Production	(680)	(407)	(222)
Ending balance	4,590	5,838	5,117
Proved reserve quantities at December 31, 2020 attributable to temporary equity	1,065
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Proved developed reserve quantities	3,426	2,494	1,898	1,898	1,898	1,898
Proved developed reserves at December 31, 2020 attributable to temporary equity	795
Proved undeveloped reserve quantities	1,164	3,344	3,219	3,219	3,219	3,219
Proved undeveloped reserves at December 31, 2020 attributable to temporary equity	270
Revisions To Pricing
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Revisions of previous estimates | MBoe	(2,645)	(902,000)			536,000
Revisions Attributable to Operator Development Timing
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Revisions of previous estimates | MBoe	(7,036)	(1,397,000)			(1,100,000)

Reserve and Related Financial_4

Reserve and Related Financial Data (SMOG) - Unaudited - Narrative (Details) MMBoe in Thousands	12 Months Ended
	Dec. 31, 2020MBoewell	Dec. 31, 2019MBoewell	Dec. 31, 2018MBoewell	Dec. 31, 2018MMBoewell
Reserve Quantities [Line Items]
Proved developed reserve quantities	2,174,000	7,651,000	7,354,000
Divestiture through sale of mineral and royalty interests	48,000	409,000	0
Extensions and discoveries	1,591,000	4,110,000	3,208,000
Number of well locations | well	342	900	555	555
Revisions of previous estimates	8,271,000	2,299,000	(1,508,000)	(1,508)
Permian, DJ, Anadarko and Williston Basins
Reserve Quantities [Line Items]
Proved developed reserve quantities	2,174	7,651,000	7,354,000
Divestiture through sale of mineral and royalty interests	48	409,000
Additional proved reserves		7,242,000
Proved Developed and Undeveloped Reserve, Conversion of Reserves
Reserve Quantities [Line Items]
Extensions and discoveries	1,591
Revisions To Pricing
Reserve Quantities [Line Items]
Revisions of previous estimates	(2,645)	(902,000)	536,000
Proved Reserves, Revisions Attributable to Production
Reserve Quantities [Line Items]
Revisions of previous estimates	1,410
Revisions Attributable to Operator Development Timing
Reserve Quantities [Line Items]
Revisions of previous estimates	(7,036)	(1,397,000)	(1,100,000)
Revisions Associated With Unit Configuration and EUR Adjustments
Reserve Quantities [Line Items]
Revisions of previous estimates			(944,000)
Minimum
Reserve Quantities [Line Items]
Average sales price, percent	10.00%
Maximum
Reserve Quantities [Line Items]
Average sales price, percent	25.00%

Reserve and Related Financial_5

Reserve and Related Financial Data (SMOG) - Unaudited - Standardized Measure of Discounted Future Net Cash Flow (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2020USD ($)$ / bbl$ / MMBTU	Dec. 31, 2019USD ($)$ / bbl$ / MMBTU	Dec. 31, 2018USD ($)$ / bbl$ / MMBTU	Dec. 31, 2017USD ($)
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future crude oil, natural gas, and NGL sales	$ 562,545	$ 1,042,118	$ 1,049,141
Future severance tax and ad valorem taxes	(39,318)	(73,627)	(70,248)
Future income tax expense	(46,908)	(143,599)	(144,421)
Future net cash flows	476,319	824,892	834,472
10% annual discount	(205,551)	(359,258)	(391,013)
Standardized measure of discounted future net cash flows	270,768	465,634	443,459	$ 316,468
Standardized measure of discounted future net cash flows attributable to temporary equity	$ 62,853	$ 186,999	$ 0
Oil (per Bbl)
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Prices used in determination of standardized measure (in dollars per unit) | $ / bbl	36.35	51.01	61.31
Natural gas (per Mcf)
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Prices used in determination of standardized measure (in dollars per unit) | $ / MMBTU	1.03	1.51	2.51
NGLs (per Bbl)
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Prices used in determination of standardized measure (in dollars per unit) | $ / bbl	8.19	14.39	23.98

Reserve and Related Financial_6

Reserve and Related Financial Data (SMOG) - Unaudited - Principal Sources of Change in Standardized Measure of Discounted Net Cash Flows (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Roll Forward]
Standardized measure of discounted future net cash flows, beginning of the year	$ 465,634	$ 443,459	$ 316,468
Sales, less production costs	(73,654)	(86,492)	(52,278)
Revisions of previous quantity estimates	(135,926)	(41,539)	(22,942)
Extensions, discoveries, and other additions	21,011	69,057	71,668
Net change in prices and production costs	(131,886)	(99,660)	71,770
Accretion of discount	54,741	51,949	31,713
Purchase of reserves in place	27,241	137,819	148,580
Divestitures of reserves in place	(250)	(5,783)	0
Net change in taxes	53,786	(5,739)	(75,369)
Timing differences and other	(9,929)	2,563	(46,151)
Standardized measure of discounted future net cash flows, end of the year	$ 270,768	$ 465,634	$ 443,459

Reserve and Related Financial_7

Reserve and Related Financial Data (SMOG) - Unaudited - Capitalized Costs (Details) - USD ($) $ in Thousands	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Extractive Industries [Abstract]
Not subject to depletion	$ 325,091	$ 291,664	$ 228,151
Subject to depletion	488,301	449,061	289,851
Total oil and gas properties, at cost	813,392	740,725	518,002
Less accumulated depreciation, depletion, and amortization	(189,546)	(61,103)	(27,628)
Total oil and gas properties, net	$ 623,846	$ 679,622	$ 490,374

Reserve and Related Financial_8

Reserve and Related Financial Data (SMOG) - Unaudited - Costs Incurred In Acquisition of Properties (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Extractive Industries [Abstract]
Unevaluated	$ 35,725	$ 78,093	$ 59,460
Evaluated	30,856	140,025	137,496
Total	$ 66,581	$ 218,118	$ 196,956