MNRL Sub (MNRL) 10-K 28 Feb 22 2021 FY Annual report Financial data

Cover

Cover - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Feb. 18, 2022	Jun. 30, 2021
Document Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2021
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	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Public Float			$ 987.3
Documents Incorporated by Reference	Portions of the registrant’s definitive proxy statement for the 2022 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	2021
Document Fiscal Period Focus	FY
Entity Central Index Key	0001745797
Common Class A
Document Information [Line Items]
Entity Common Stock, Shares Outstanding		48,360,253
Common Class B
Document Information [Line Items]
Entity Common Stock, Shares Outstanding		11,371,517

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2021
Audit Information [Abstract]
Auditor Name	KPMG LLP
Auditor Location	Austin, TX
Auditor Firm ID	185

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Current assets:
Cash and cash equivalents	$ 20,819	$ 9,144
Restricted cash	200	0
Accounts receivable	30,539	17,632
Prepaid expenses and other	3,145	3,693
Total current assets	54,703	30,469
Oil and gas properties, at cost, using the full cost method of accounting:
Unevaluated property	338,613	325,091
Evaluated property	633,138	488,301
Less accumulated depreciation, depletion, and amortization	(239,612)	(189,546)
Total oil and gas properties, net	732,139	623,846
Other property and equipment	2,060	5,587
Less accumulated depreciation	(1,280)	(4,632)
Other property and equipment, net	780	955
Operating lease right-of-use asset	6,764	0
Deferred tax asset	25,308	24,920
Other assets, net	1,183	771
Total assets	820,877	680,961
Current liabilities:
Accounts payable and accrued liabilities	20,473	7,905
Current operating lease liability	1,178	0
Total current liabilities	21,651	7,905
Long-term bank debt	93,000	20,000
Non-current operating lease liability	5,742	0
Other non-current liabilities	810	1,126
Temporary equity	0	146,280
Equity:
Preferred stock, $0.01 par value; 50,000,000 authorized; no shares issued and outstanding at December 31, 2021 and December 31, 2020	0	0
Additional paid-in capital	634,564	601,129
Accumulated deficit	(105,096)	(92,392)
Treasury stock, at cost; 436,630 shares at December 31, 2021 and December 31, 2020	(3,527)	(3,527)
Total equity attributable to Brigham Minerals, Inc.	526,429	505,650
Non-controlling interests	173,245	0
Total equity	699,674	505,650
Total liabilities and equity	820,877	680,961
Class A Common Stock
Equity:
Common stock	488	440
Class B Common Stock
Equity:
Common stock	$ 0	$ 0

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Dec. 31, 2021	Dec. 31, 2020
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	436,630
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)	48,796,518	43,995,124
Common stock, shares outstanding (in shares)	48,359,888	43,558,494
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)	11,371,517	13,167,687
Common stock, shares outstanding (in shares)	11,371,517	13,167,687

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
REVENUES
Mineral and royalty revenues	$ 156,699	$ 86,245	$ 97,886
Lease bonus and other revenues	4,518	5,478	3,629
Total revenues	161,217	91,723	101,515
OPERATING EXPENSES
Gathering, transportation and marketing	6,818	6,985	4,985
Severance and ad valorem taxes	9,320	5,606	6,409
Depreciation, depletion, and amortization	36,677	48,238	30,940
Impairment of oil and gas properties	0	79,569	0
General and administrative	22,475	21,619	21,963
Total operating expenses	75,290	162,017	64,297
INCOME (LOSS) FROM OPERATIONS	85,927	(70,294)	37,218
Loss on derivative instruments, net	0	0	(568)
Interest expense, net	(1,701)	(890)	(5,609)
Loss on extinguishment of debt	0	0	(6,892)
Other income, net	53	428	169
Income (loss) before income tax expense	84,279	(70,756)	24,318
Income tax expense (benefit)	16,253	(12,762)	2,679
NET INCOME (LOSS)	68,026	(57,994)	21,639
Net income attributable to predecessor	0	0	(5,092)
Less: net (income) loss attributable to non-controlling interests and temporary equity	(17,743)	15,582	(9,646)
Net income (loss) attributable to Brigham Minerals, Inc. stockholders	$ 50,283	$ (42,412)	$ 6,901
NET INCOME (LOSS) PER COMMON SHARE
Basic (in dollars per share)	$ 1.13	$ (1.11)	$ 0.26
Diluted (in dollars per share)	$ 1.10	$ (1.11)	$ 0.26
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING
Basic (in shares)	44,576	38,178	22,870
Diluted (in shares)	45,632	38,178	22,870

Consolidated Statement of Chang

Consolidated Statement of Changes in Stockholders' and Members' Equity - USD ($) $ in Thousands	Total	Members' Contributed Capital	Additional Paid-In Capital	Retained Earnings (Accumulated Deficit)	Treasury Stock	Noncontrolling Interest	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
Beginning balance at Dec. 31, 2018	$ 373,948	$ 208,728	$ (3,057)	$ 168,277				$ 0		$ 0
Beginning balance (in shares) at Dec. 31, 2018								0		0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to stockholders	848			848
Net income attributable to predecessor	5,092			5,092
Ending balance at Apr. 16, 2019	379,888	208,728	(3,057)	174,217				$ 0		$ 0
Ending balance (in shares) at Apr. 16, 2019								0		0
Beginning balance at Dec. 31, 2018	373,948	208,728	(3,057)	168,277				$ 0		$ 0
Beginning balance (in shares) at Dec. 31, 2018								0		0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to stockholders	6,901
Net income attributable to predecessor	(5,092)
Ending balance at Dec. 31, 2019	317,319	0	323,578	(6,599)	$ 0	$ 0		$ 340		$ 0
Ending balance (in shares) at Dec. 31, 2019					0			34,041,000		22,847,000
Beginning balance at Apr. 16, 2019	379,888	208,728	(3,057)	174,217				$ 0		$ 0
Beginning balance (in shares) at Apr. 16, 2019								0		0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to stockholders	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 (in shares)								16,675,000					6,000,000
Issuance of common stock	273,448		273,281					$ 167			$ 102,680	$ 102,620	$ 60
Deferred tax asset arising from issuance of stock	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
Shares surrendered for tax withholdings on vested equity awards			(1,256)
Conversion of shares of Class B Common Stock to Class A Common Stock (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
Share-based compensation expense	13,888		13,888
Dividends and distributions declared	(15,339)			(15,339)
Adjustment of temporary equity to redemption amount	(51,572)		(51,572)
Restricted stock forfeited (in shares)								(11,000)
Restricted stock forfeited	(34)		(34)
Ending balance at Dec. 31, 2019	317,319	$ 0	323,578	(6,599)	$ 0	0		$ 340		$ 0
Ending balance (in shares) at Dec. 31, 2019					0			34,041,000		22,847,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to stockholders	(42,412)			(42,412)
Net income attributable to predecessor	0
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 surrendered for tax withholding on vested equity awards (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	13,615		13,615
Dividends and distributions declared	(43,381)			(43,381)
Adjustment of temporary equity to redemption amount	170,361		170,361
Restricted stock forfeited (in shares)								(10,000)
Ending balance at Dec. 31, 2020	505,650		601,129	(92,392)	$ (3,527)	0		$ 440		$ 0
Ending balance (in shares) at Dec. 31, 2020					437,000		43,558,494	43,558,000	13,167,687	13,168,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income attributable to stockholders	50,283
Net income attributable to predecessor	0
Issuance of common stock (in shares)								2,180,000
Issuance of common stock	46,326		46,304					$ 22
Issuance of common stock upon vesting of RSUs, net of shares withheld for income taxes (in shares)								840,000
Issuance of common stock upon vesting of RSUs, net of shares withheld for income taxes	9,547		9,556					$ 9
Shares surrendered for tax withholding on vested equity awards (in shares)								(9,000)
Shares surrendered for tax withholdings on vested equity awards	(145)		(145)
Adjustment of temporary equity to carrying value	(54,294)		(54,294)
Reclassification from temporary equity to non-controlling interest	202,496					202,496
Conversion of shares of Class B Common Stock to Class A Common Stock (in shares)								1,796,000		(1,796,000)
Conversion of shares of Class B Common Stock to Class A Common Stock	0		27,222			(27,239)		$ 17
Deferred tax asset arising from conversion of shares of Class B Common Stock to Class A Common Stock	6,153		6,153
Share-based compensation expense	17,751		17,751
Dividends and distributions declared	(80,820)			(62,987)		(17,833)
Restricted stock forfeited (in shares)								(5,000)
Net income	66,104			50,283		15,821
Ending balance at Dec. 31, 2021	$ 699,674		$ 634,564	$ (105,096)	$ (3,527)	$ 173,245		$ 488		$ 0
Ending balance (in shares) at Dec. 31, 2021					437,000		48,359,888	48,360,000	11,371,517	11,372,000

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	$ 68,026	$ (57,994)	$ 21,639
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	36,677	48,238	30,940
Impairment of oil and gas properties	0	79,569	0
Share-based compensation expense	9,703	7,529	10,049
Loss on extinguishment of debt	0	0	6,892
Amortization of debt issue costs	313	605	433
Deferred income tax expense/(benefit)	5,766	(9,942)	665
Loss on derivative instruments, net	0	0	568
Net cash received for derivative settlements	0	0	470
Credit losses	475	299	669
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivables	(13,382)	12,359	(10,246)
Decrease (increase) in other current assets	442	(2,005)	1,787
Decrease in other deferred charges	0	45	0
Increase (decrease) in accounts payables and accrued liabilities	1,288	(3,608)	5,112
(Decrease) increase in other long-term liabilities	(109)	165	47
Net cash provided by operating activities	109,199	75,260	69,025
CASH FLOWS FROM INVESTING ACTIVITIES
Additions to oil and gas properties	(103,547)	(66,498)	(219,481)
Additions to other fixed assets	(56)	(492)	(474)
Proceeds from sale of oil and gas properties, net	13,620	1,565	3,123
Net cash used in investing activities	(89,983)	(65,425)	(216,832)
CASH FLOWS FROM FINANCING ACTIVITIES
Payments of short-term debt	0	0	(4,596)
Payments of long-term debt	(4,000)	0	(275,404)
Borrowing of long-term debt	77,000	20,000	105,000
Payment of debt extinguishment fees	0	0	(2,091)
Proceeds from issuance of Class A common stock sold in initial public offering, net of offering costs	0	0	277,075
Proceeds from issuance of Class A common stock, net of offering costs	0	0	102,680
Capital distributions	0	0	(441)
Purchase of treasury stock	0	(3,527)	0
Dividends paid	(60,614)	(42,216)	(14,663)
Distributions to holders of non-controlling interest and temporary equity	(17,864)	(24,670)	(19,731)
Debt issuance cost	(727)	(208)	(1,348)
Payment of employee tax withholding for settlement of equity compensation awards	(1,136)	(1,203)	0
Net cash (used in) provided by financing activities	(7,341)	(51,824)	166,481
Change in cash and cash equivalents and restricted cash	11,875	(41,989)	18,674
Cash and cash equivalents and restricted cash, beginning of period	9,144	51,133	32,459
Cash and cash equivalents and restricted cash, end of period	21,019	9,144	51,133
Supplemental disclosure of non-cash activity:
Accrued capital expenditures	561	146	63
Capitalized share-based compensation expense	8,048	6,086	3,818
Issuance of common stock for acquisitions of oil and gas properties	46,349	0	0
Temporary equity cumulative adjustment to redemption value	54,294	(170,361)	51,572
Supplemental cash flow information:
Cash payments for loan commitment fees and interest	(1,318)	(715)	(6,192)
Tax (payments) refunds received	$ (8,030)	$ 1,211	$ (832)

Business and Basis of Presentat

Business and Basis of Presentation	12 Months Ended
	Dec. 31, 2021
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”, "we", "us", "our", 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 and Non-controlling Interest", 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 stockholders of the Company (the "Selling Stockholders"), 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 mineral and royalty acquisitions. Brigham Minerals did not receive any proceeds from the sale of shares of Class A common stock by the Selling Stockholders. 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 stockholders of the Company (the “June 2020 Selling Stockholders”), and 4,872,669 of which represented shares issued upon redemption of an equivalent number of the June 2020 Selling Stockholders’ 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 stockholders of the Company (the "September 2020 Selling Stockholders"), and 3,062,011 of which represented shares issued upon redemption of an equivalent number of the September 2020 Selling Stockholders’ 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 Stockholders 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 Stockholders 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. As of December 31, 2021, Brigham Minerals owned a 81.0% interest in Brigham LLC and the Original Owners owned 19.0% 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 8.7% of the outstanding voting stock of Brigham Minerals as of December 31, 2021. Yorktown ceased to be an affiliate of the Company on January 20, 2022 in connection with the resignation of W. Howard Keenan, Jr. from the Board of Directors. Basis of Presentation The accompanying consolidated financial statements of Brigham Minerals have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). The consolidated financial statements reflect all normal recurring adjustments that, in the opinion of management, are necessary for a fair representation. Brigham Minerals operates in one segment: oil and natural gas exploration and production. As the primary beneficiary, Brigham Minerals consolidates the financial results of Brigham LLC and its subsidiaries and reports the interest related to the portion of the units in Brigham LLC not owned by Brigham Minerals as temporary equity at December 31, 2020 and as non-controlling interest at March 31, 2021 and thereafter, which will reduce net income attributable to the holders of Brigham Minerals' Class A common stock. For more information, see "Note 9—Temporary equity and Non-controlling interest.”

Significant Accounting Policies

Significant Accounting Policies	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Significant Accounting Policies	Significant Accounting Policies Emerging Growth Company and Large Accelerated Filer Status As a company with less than $1.07 billion in revenues during its during the twelve months ended December 31, 2020, Brigham Minerals qualified as an “emerging growth company” (“EGC”) as defined in the Jumpstart Our Business Startups Act of 2012 (the “JOBS Act”). An EGC may take advantage of specified reduced reporting and other regulatory requirements. As a result of Brigham Minerals’ election to avail itself of certain provisions of the JOBS Act, the information that Brigham Minerals provides for periods prior to January 1, 2021, may be different than the information provided by other public companies. As of June 30, 2021 the total market value of Brigham Minerals’ common equity securities held by non-affiliates exceeded $700 million and as a result, Brigham Minerals became a "large accelerated filer" and ceased to be an EGC as of December 31, 2021. Brigham Minerals was required to accelerate the adoption of Accounting Standards Update (“ASU”) 2016-02 Leases (Topic 842) and ASU 2016-13, Financial Instruments—Credit Losses (Topic 326) for the year ended December 31, 2021 as described below under the heading, "Recently Adopted Accounting Standards". Recently Adopted Accounting Standards Leases In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), (or "the new lease standard") amending the guidance on the accounting for leasing transactions. The new lease standard requires lessees to recognize a lease liability for the obligation to make lease payments and a right-of-use (“ROU”) asset for the right to use the underlying asset for the lease term. ASU 2016-02 does not apply to leases of mineral rights to explore for or use crude oil and natural gas. The ASU replaced most existing lease guidance in GAAP effective upon adoption. The Company adopted the new lease standard during the fiscal year ending December 31, 2021, with a beginning period of adoption of January 1, 2021. The Company made policy elections to apply the following practical expedients as provided in the standards update: • an accounting policy election to not apply the recognition requirements in the new standards update to short-term leases (a lease that at commencement date has a lease term of twelve months or less) and not to separate non-lease components from lease components for all asset classes; and • a package of practical expedients to not reassess whether a contract contains a lease, lease classification and initial direct costs prior to January 1, 2021. 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. The Company enters into land easements as a lessor, on a routine basis as part of its ongoing operations and has many such agreements currently in place; however, the Company did not account for any land easements under Topic 840. As this guidance serves as an amendment to the new lease standard, the Company elected this practical expedient, which became effective upon the date of adoption of the new lease standard. For Brigham Minerals, as a lessor, the amounts received with respect to term-based land easement payments were immaterial during the fiscal year ending December 31, 2021. The Company will assess any new land easements to determine whether the arrangement should be accounted for as a lease. Perpetual-based land easements are not in scope under the new lease standard. 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) and applying the modified retrospective approach, with a cumulative-effect adjustment to the opening balance of retained earnings as of the adoption date. The Company elected this transition approach, however the cumulative impact of adoption in the opening balance of retained earnings as of January 1, 2021 was immaterial. Financial Instruments — Credit Losses 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 replaced the currently required incurred loss approach with an expected loss model for instruments measured at amortized cost. The Company adopted ASU 2016-13 during the fiscal year ending December 31, 2021, with a beginning period of adoption of January 1, 2021. The impact of the adoption of ASU 2016-13 on the consolidated financial statements of Brigham Minerals was immaterial. ASU 2016-13 was applied using a modified retrospective approach, with a cumulative-effect adjustment to the opening balance of retained earnings as of the adoption date, however, the cumulative impact of adoption in the opening balance of retained earnings as of January 1, 2021 was immaterial. Use of Estimates The preparation of consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities in the consolidated 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 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, share-based compensation expenses 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. Accounts Receivable 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 operators and records a reserve for amounts not expected to be fully recovered, using a current expected credit loss model. We recorded credit losses of $0.5 million, $0.3 million and $0.6 million for the years ended December 31, 2021, 2020 and 2019, respectively, which was included in general and administrative expenses. At December 31, 2021 and 2020, accounts receivable was comprised of the following: December 31, (In Thousands) 2021 2020 Accounts receivable Oil and gas sales $ 30,485 $ 17,413 Reserve for credit losses (995) (855) Other 1,049 1,074 Total accounts receivables $ 30,539 $ 17,632 Concentration of Credit Risk and Significant Customers Financial instruments that potentially subject Brigham Minerals to concentrations of credit risk consist of cash, accounts receivable, and its 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 Years Ended December 31, 2021 2020 2019 Exxon Mobil Corp. 13 % 11 % 10 % Occidental Petroleum Corp. 11 % 12 % 16 % ConocoPhillips Company (1) 11 % 14 % — % Continental Resources, Inc. 10 % 10 % 12 % (1) ConocoPhillips Company acquired Royal Dutch Shell's subsidiary, Shell Enterprises LLC, interest in Shell's Permian assets. 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. For the year ended December 31, 2021, we received revenues from 178 operators with approximately 67% of revenues coming from the top ten operators on our properties. For the year ended December 31, 2020, we received revenues from 145 operators with approximately 70% of revenues coming from the top ten operators on our properties. Financial Instruments Brigham Minerals’ financial instruments consist of cash and cash equivalents, receivables, payables, derivative assets and liabilities, 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—Fair Value Measurements” and “Note 6—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 2021, 2020 and 2019. 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, 2021, 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. See “Note 3—Oil and Gas Properties” for further discussion. Leases The Company determines if an arrangement is a lease at inception of the arrangement. To the extent that we determine an arrangement represents a lease, we classify that lease as an operating lease or a finance lease, depending on the lease classification guidance. We currently do not have any finance leases. We capitalize our operating leases through an operating lease ROU asset and a corresponding operating lease liability on our consolidated balance sheets. ROU assets represent our right to use an underlying asset for the lease term and operating lease liabilities represent our obligation to make lease payments arising from the lease. Short-term leases that have an initial term of one year or less are not capitalized but are disclosed. Short-term lease costs exclude expenses related to leases with a lease term of one month or less. Our operating leases are reflected as operating lease right-of-use asset, current operating lease liability and non-current operating lease liability on our consolidated balance sheets. Operating lease ROU assets and liabilities are recognized at the commencement date of an arrangement based on the present value of lease payments over the lease term. In addition to the present value of lease payments, the operating lease ROU asset also includes any lease payments made to the lessor prior to lease commencement less any lease incentives and initial direct costs incurred. Lease expense for operating lease payments is recognized on a straight-line basis over the lease term. Nature of Leases We lease certain office space under a non-cancelable lease for our corporate headquarters. Our office agreements are typically structured with non-cancelable terms of one Discount Rate Our office agreement does not provide an implicit rate. Accordingly, we are required to use our incremental borrowing rate in determining the present value of lease payments based on the information available at commencement date. Our incremental borrowing rate reflects the estimated rate of interest that we would pay to borrow on a collateralized basis over a similar term in an amount equal to the lease payments in a similar economic environment. We use the implicit rate in the limited circumstances in which that rate is readily determinable. Practical Expedients and Accounting Policy Elections Certain of our lease agreements include lease and non-lease components. For all existing asset classes with multiple component types, we have utilized the practical expedient that exempts us from separating lease components from non-lease components. Accordingly, we account for the lease and non-lease components in an arrangement as a single lease component. In addition, for all of our existing asset classes, we have made an accounting policy election not to apply the lease recognition requirements to our short-term leases (that is, a lease that, at commencement, has a lease term of 12 months or less and does not include an option to purchase the underlying asset that we are reasonably certain to exercise). Accordingly, we recognize lease payments related to our short-term leases in our statements of operations on a straight-line basis over the lease term which has not changed from our prior recognition. To the extent that there are variable lease payments, we recognize those payments in our statements of operations in the period in which the obligation for those payments is incurred. Lease payments on our short-term leases during the years ended December 31, 2021, 2020 and 2019 were immaterial. Accounting for Leases as a Lessor The Company acts as a lessor with respect to amounts received for land easements (also commonly referred to as rights of way). Land easements represent the right to use, access, or cross another entity's land for a specified purpose. The Company elected to apply the land easement practical expedients and does not evaluate existing or expired land easements that were not previously accounted for as leases under Topic 840. A land easement may be perpetual or term-based. Perpetual easements are not in scope under the new leasing standard. All term-based land easements granted by the Company during the year ended December 31, 2021 were immaterial in the aggregate. See "Note 7—Leases" for additional disclosures of the Company's leases. 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 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 expense 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 statements of operations included within this Annual Report. There was approximately $16.5 million of unamortized compensation expense relating to outstanding awards at December 31, 2021, 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, $0.4 million and $0.3 million, to the 401(k) plan for each of the years ended December 31, 2021, 2020, and 2019. 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 accounted 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 and Non-controlling Interest.” As such, the Company adjusted 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 Company's Board of Directors (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. As a result of the appointment of an additional independent member to our Board of Directors on February 19, 2021, the holders of Class B common stock no longer hold a majority of the votes of the Board of Directors and no longer control the Board of Directors through direct representation on the Board of Directors. Consequently, after February 19, 2021, Class B common stock is presented as non-controlling interest (as discussed below) in the consolidated balance sheets of Brigham Minerals. Non-Controlling Interest As of February 19, 2021 and thereafter, the 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 each holder of Brigham LLC Unit's (each a "Brigham LLC Unit Holder") exercise of its Redemption Right (as hereinafter defined). As such, at December 31, 2021, Brigham Minerals accounts for Brigham LLC Unit Holders' 19.0% interest in Brigham LLC not owned by Brigham Minerals as non-controlling interest. For further discussion, see “Note 9—Temporary Equity and Non-controlling Interest.” Revenue from Contracts with Customers Mineral and royalty revenues Mineral and royalty 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. During the twelve months ending December 31, 2021, 2020 and 2019 the disaggregated revenues from sales of oil, natural gas and NGLs are as follows: For the Years Ended December 31, Disaggregated revenues (in thousands) 2021 2020 2019 Oil sales $ 110,791 $ 67,909 $ 82,048 Natural gas sales 27,070 10,443 9,724 NGL sales 18,838 7,893 6,114 Total mineral and royalty revenues $ 156,699 $ 86,245 $ 97,886 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 Mineral and royalty revenues 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, 2021, 2020 and 2019, revenue recognized in the reporting periods related to performance obligations satisfied in prior reporting periods was immaterial. Debt Issuance Cost

Oil and Gas Properties

Oil and Gas Properties	12 Months Ended
	Dec. 31, 2021
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 are capitalized into a full cost pool. In addition, certain internal costs (or "capitalized general and administrative costs"), are also included in the full cost pool. Capitalized general and administrative costs were $13.0 million, $10.2 million and $7.4 million for the years ended December 31, 2021, 2020, and 2019, respectively. Capitalized costs do not include any costs related to general corporate overhead or similar activities, which are expensed in the period incurred. Oil and gas properties consisted of the following: December 31, (In Thousands) 2021 2020 Oil and gas properties, at cost, using the full cost method of accounting: Unevaluated property $ 338,613 $ 325,091 Evaluated property 633,138 488,301 Total oil and gas properties, at cost 971,751 813,392 Less accumulated depreciation, depletion, and amortization (239,612) (189,546) Total oil and gas properties, net $ 732,139 $ 623,846 Costs not subject to depletion are as follows, by the year in which such costs were incurred: By Year: (In Thousands) Total 2021 2020 2019 2018 2017 Prior Property Acquisition costs $ 338,613 $ 45,885 $ 32,456 $ 71,385 $ 64,582 $ 58,619 $ 65,686 Capitalized costs are depleted on a unit of production basis based on proved oil and natural gas reserves. Depletion expense was $36.4 million, $47.3 million and $30.4 million for the year ended December 31, 2021, 2020 and 2019, respectively. Average depletion of proved properties was $11.05, $13.63 and $11.22 per Boe for the year ended December 31, 2021, 2020 and 2019, respectively. 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 test"). A write-down of the carrying value of the full cost pool ("impairment charge") 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. A ceiling test is calculated at each reporting period. The ceiling test 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, adjusted by area for energy content, transportation fees and regional price differentials, as required under the guidelines established by the SEC. At December 31, 2021, 2020 and 2019, 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 $66.56, $39.57, and $55.65 per barrel of oil and $3.64, $2.00, and $2.60 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 were no impairment charges during the years ended December 31, 2021 and 2019. A decline in the SEC oil price or the SEC gas price could lead to impairment charges in the future and such impairment charges could be material, such as occurred in the third and fourth quarters of 2020. 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.

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2021
Business Combination and Asset Acquisition [Abstract]
Acquisitions and Divestitures	Acquisitions and Divestitures DJ Acquisition On November 3, 2021, the Company entered into a definitive purchase and sale agreement to acquire approximately 8,400 net royalty acres primarily in Weld County, Colorado, operated by PDC Energy, Inc., Chevron Corporation, Occidental Petroleum and Civitas Resources for 2.2 million shares of the Company’s common stock and $43.1 million of cash, net of $1.7 million of customary closing adjustments. The DJ Acquisition closed on December 15, 2021. The cash portion of the purchase price was funded through a combination of cash on hand and borrowings under the Company’s revolving credit facility. The following table presents the acquisition consideration paid in the DJ Acquisition (in thousands, except the number of shares and price per share): Consideration: Class A shares of Brigham Minerals, Inc. common stock issued at closing 2,180,128 Closing price per share of Brigham Minerals, Inc. common stock on the closing date $ 21.26 Fair Value of Brigham Minerals, Inc. common stock issued $ 46,349 Cash consideration 43,083 Total consideration (including fair value of Brigham Minerals, Inc. common stock issued) $ 89,432 The DJ Acquisition has been accounted for as an asset acquisition and the allocation of the purchase price was $17.9 million to unevaluated properties and $71.5 million to evaluated properties. Other Acquisitions During the years ended December 31, 2021 and 2020, Brigham Minerals entered into a number of 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 for the year ended December 31, 2021 is comprised of payments for acquisitions of minerals, land brokerage costs and capitalized general and administrative expenses that were funded with our retained operating cash flow, proceeds from asset sales and our revolving credit facility (hereinafter defined). The changes in the oil and natural gas property balance for the year ended December 31, 2020 were partially funded with proceeds from the December 2019 Offering as well as our retained cash flow and our revolving credit facility. Assets Acquired Cash Consideration Paid (In Thousands) Evaluated Unevaluated Year ended December 31, 2021 $ 26,822 $ 34,056 $ 60,878 Year ended December 31, 2020 $ 30,856 $ 35,725 $ 66,581 Divestitures During the year ended December 31, 2021, Brigham Minerals divested certain non-core, primarily undeveloped acreage in Oklahoma and received cash of $13.6 million. 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, 2021, 2020 and 2019 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, 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 Sales of minerals-in-place (71) (780) (73) (275) Extensions and discoveries 1,666 4,404 623 3,024 Acquisitions 2,739 14,683 1,662 6,849 Revisions of previous estimates 1,053 10,107 1,706 4,444 Production (1,677) (5,886) (642) (3,300) Proved reserve quantities, December 31, 2021 16,910 66,172 7,866 35,805 Proved reserve quantities at December 31, 2021 attributable to non-controlling interest 3,213 12,573 1,495 6,803 Proved developed reserve quantities: December 31, 2019 9,924 33,232 2,494 17,957 December 31, 2020 9,403 31,873 3,426 18,141 December 31, 2021 13,148 56,372 6,367 28,911 Proved developed reserves at December 31, 2021 attributable to temporary equity 2,498 10,711 1,210 5,493 Proved undeveloped reserve quantities: December 31, 2019 7,037 28,498 3,344 15,131 December 31, 2020 3,797 11,771 1,164 6,922 December 31, 2021 3,762 9,800 1,499 6,894 Proved undeveloped reserves at December 31, 2021 attributable to temporary equity 715 1,862 285 1,310 Changes in proved reserves that occurred during 2021 were primarily due to: • the acquisition of additional mineral interests located in the Permian, DJ and Williston Basins in multiple transactions. The acquired proved reserves of 6,849 MBoe throughout the year were offset by the divestiture of 275 MBoe of proved reserves; • well additions, extensions and discoveries of approximately 3,024 MBoe, as 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; • positive revision of 3,591 MBoe attributable to an increase in SEC pricing; and • positive revision of 852 MBoe due to PDP outperformance, estimate ultimate recovery ("EUR") adjustments, refined gas and NGL processing assumptions, and unit configuration. 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. 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 Years Ended December 31, (In Thousands) 2021 2020 2019 Future crude oil, natural gas, and NGL sales $ 1,512,784 $ 562,545 $ 1,042,118 Future severance tax and ad valorem taxes (109,849) (39,318) (73,627) Future income tax expense (214,311) (46,908) (143,599) Future net cash flows 1,188,624 476,319 824,892 10% annual discount (549,768) (205,551) (359,258) Standardized measure of discounted future net cash flows $ 638,856 $ 270,768 $ 465,634 Standardized measure of discounted future net cash flows attributable to temporary equity $ 121,383 $ 62,853 $ 186,999 The following prices were used in the determination of standardized measure: For the Years Ended December 31, 2021 2020 2019 Oil (per Bbl) $ 64.46 $ 36.35 $ 51.01 Natural gas (per Mcf) 3.22 1.03 1.51 NGLs (per Bbl) 26.65 8.19 14.39 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 29% to 41% of WTI. All p rices 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 Years Ended December 31, (In Thousands) 2021 2020 2019 Standardized measure of discounted future net cash flows, beginning of the year $ 270,768 $ 465,634 $ 443,459 Changes in the year resulting from: Sales, less production costs (140,561) (73,654) (86,492) Revisions of previous quantity estimates 106,664 (135,926) (41,539) Extensions, discoveries, and other additions 74,305 21,011 69,057 Net change in prices and production costs 268,687 (131,886) (99,660) Accretion of discount 23,763 54,741 51,949 Purchase of reserves in place 151,547 27,241 137,819 Divestitures of reserves in place (2,375) (250) (5,783) Net change in taxes (87,960) 53,786 (5,739) Timing differences and other (25,982) (9,929) 2,563 Standardized measure of discounted future net cash flows, end of the year $ 638,856 $ 270,768 $ 465,634 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 Years Ended December 31, (In Thousands) 2021 2020 2019 Oil and gas properties, at cost, using full cost method of accounting: Unevaluated property $ 338,613 $ 325,091 $ 291,664 Evaluated property 633,138 488,301 449,061 Total oil and gas properties, at cost 971,751 813,392 740,725 Less accumulated depreciation, depletion, and amortization (239,612) (189,546) (61,103) Total oil and gas properties, net $ 732,139 $ 623,846 $ 679,622 Costs incurred in oil and natural gas activities The following costs were incurred in oil and natural gas producing activities: For the Years Ended December 31, (In Thousands) 2021 2020 2019 Acquisition of oil and gas properties Unevaluated $ 51,934 $ 35,725 $ 78,093 Evaluated 98,377 30,856 140,025 Total $ 150,311 $ 66,581 $ 218,118

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2021
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, 2021 and 2020. Brigham Minerals had no derivative contracts in place as of December 31, 2021 and 2020. 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, 2021 and 2020. 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 commodity prices and 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 revolving credit facility approximates fair value as interest rates on the revolving credit facility 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, 2021
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt 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 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 a substantial portion of Brigham Resources and its domestic subsidiaries’ assets, including a substantial portion of their respective royalty and mineral properties. On July 7, 2021, Brigham Resources entered into the Third Amendment to the credit agreement (the "Third Amendment"). The Third Amendment, among other things, evidenced an increase of the borrowing base and elected commitments under the prior credit agreement from $135.0 million to $165.0 million and the addition of leverage (maximum 3.00x) and liquidity (minimum 10% of total net revolving commitments) conditions to Brigham Resources’ ability to pay dividends or distributions (other than permitted tax distributions) to the owners of its equity interests. On December 15, 2021, Brigham Resources entered into the Fourth Amendment to the credit agreement (the “Fourth Amendment”). The Fourth Amendment, among other things, evidenced a further increase of the borrowing base and elected commitments under the prior credit agreement from $165.0 million to $230.0 million. Availability under our revolving credit facility is governed by a borrowing base, which is subject to redetermination semi-annually. 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. The weighted average interest rate for the year ended December 31, 2021 was 2.31%. As of December 31, 2021, the borrowing base on our revolving credit facility was $230.0 million, with outstanding borrowings of $93.0 million, resulting in $137.0 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, 1.500% to 2.500% and (b) in the case of adjusted LIBOR rate loans, 2.500% to 3.500%. 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.

Leases

Leases	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
Leases	Leases The Company enters into leasing transactions in which the Company is the lessee. The Company's lease contracts are generally for office buildings, and office equipment. The Company performed evaluations of its contracts and determined it has only operating leases. In July 2019, the Company entered into a lease agreement for its corporate headquarters located in Austin, TX (the “Bridgepoint Lease”). The Bridgepoint Lease includes approximately 29,546 square feet and commenced in July 2019, with an expiration on June 30, 2027. The Bridgepoint Lease includes lease and non-lease components that we account for as a single lease component as an accounting policy election. See "Note 2—Significant Accounting Policies—Leases— Practical Expedients and Accounting Policy Elections " for further discussion. The Bridgepoint Lease requires monthly lease payments that may be subject to annual increases throughout the lease term and also includes renewal options at the election of the Company to renew or extend the lease for two, consecutive, five-year lease terms. This optional period has not been included in the lease term in the determination of the operating lease right-of-use-assets or operating lease liabilities associated with these leases as the Company did not consider it reasonably certain it would exercise the options. Since the Bridgepoint Lease does not contain an implicit rate, the Company used the incremental borrowing rate of 2% as the discount rate to calculate present value of lease payments. Rent expense on this operating leases is recognized over the term of the lease on a straight-line basis. Rent expense for the years ended December 31, 2021, 2020, and 2019 was $1.3 million, $1.1 million, and $0.6 million, respectively. The Company also enters into leasing transactions in which the Company is the lessor, primarily through land easements. The Company performed evaluations on all term-based land easements payments received during the year ended December 31, 2021 and determined that all such payments were immaterial in the aggregate. The following table summarizes the Company’s recognition of its operating lease: (In Thousands) Classification December 31, 2021 Assets Operating Operating lease right-of-use assets $ 6,764 Liabilities Current: Operating Current operating lease liability $ 1,178 Non-current: Operating Non-current operating lease liability $ 5,742 The table below presents the maturity of the Company’s liabilities under the Bridgepoint Lease as of December 31, 2021. Year Commitment 2022 $ 1,296 2023 1,319 2024 1,340 2025 1,360 2026 1,383 Thereafter 582 Total lease payments $ 7,280 Less imputed interest (360) Total lease liabilities $ 6,920

Equity

Equity	12 Months Ended
	Dec. 31, 2021
Equity [Abstract]
Equity	Equity Class A Common Stock Brigham Minerals had approximately 48.4 million shares of its Class A common stock outstanding as of December 31, 2021. 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 ha d approximately 11.4 million shares of its Class B common stock outstanding as of December 31, 2021. 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 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 Stockholders 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, 2021, 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 as defined in "Note 2 - Significant Accounting Policies - Earnings Per Share". 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, 2021, the Class B common stock and the Incentive Units were not recognized in the dilutive EPS calculations as the effect would have been antidilutive. 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, and the PSUs were not included in the computation of EPS because the performance goals had not been met, assuming the end of the reporting period was the end of the contingency period. 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. The following table reflects the allocation of net income (loss) to common stockholders 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) 2021 2020 2019 Basic EPS Numerator: Basic net income (loss) attributable to Brigham Minerals, Inc. stockholders $ 50,283 $ (42,412) $ 6,901 Less net income attributable to stockholders pre-IPO — — (848) Basic net income (loss) attributable to Brigham Minerals, Inc. stockholders post-IPO (1) $ 50,283 $ (42,412) $ 6,053 Denominator: Basic weighted average shares outstanding (1) 44,576 38,178 22,870 Basic EPS attributable to Brigham Minerals, Inc. stockholders $ 1.13 $ (1.11) $ 0.26 Diluted EPS Numerator: Basic net income (loss) attributable to Brigham Minerals, Inc. stockholders post-IPO (1) $ 50,283 $ (42,412) $ 6,053 Diluted net income (loss) attributable to Brigham Minerals, Inc. stockholders $ 50,283 $ (42,412) $ 6,053 Denominator: Basic weighted average shares outstanding (1) 44,576 38,178 22,870 Effect of dilutive securities: Unvested equity awards 1,056 — — Diluted weighted average shares outstanding 45,632 38,178 22,870 Diluted EPS attributable to Brigham Minerals, Inc. stockholders $ 1.10 $ (1.11) $ 0.26

Temporary equity and Non-contro

Temporary equity and Non-controlling interest	12 Months Ended
	Dec. 31, 2021
Temporary Equity Disclosure [Abstract]
Temporary equity and Non-controlling interest	Temporary Equity and Non-controlling Interest Temporary equity Temporary equity represented the 23.2% interest in the units of Brigham LLC not owned by Brigham Minerals, as of December 31, 2020. Class B common stock was classified as temporary equity in the consolidated balance sheet as of December 31, 2020, as pursuant to the Amended and Restated Limited Liability Company Agreement of Brigham LLC (the "Brigham LLC Agreement"), the Redemption Rights of a Brigham LLC Unit Holder for either shares of Class A common stock or an equivalent amount of cash was not solely within Brigham Minerals' control. This was due to the fact that the holders of Class B common stock controlled a majority of the votes of the Board of Directors through direct representation on the Board of Directors, which allowed the holders of Class B common stock to control the determination of whether to make a cash payment upon a Brigham LLC Unit Holder's exercise of its Redemption Right. As a result of the appointment of an additional independent member to our Board of Directors on February 19, 2021, the holders of Class B common stock no longer hold a majority of the votes of the Board of Directors and no longer control the Board of Directors through direct representation on the Board of Directors. Consequently, after February 19, 2021, Class B common stock is presented as non-controlling interest (as discussed below) in the consolidated balance sheet of Brigham Minerals. Temporary equity was 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 February 18, 2021, Brigham Minerals 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 Net income attributable to temporary equity 1,922 Adjustment of temporary equity to redemption value 54,294 Reclassification to non-controlling interest (4) (202,496) Balance - February 18, 2021 $ — (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. (4) Based on 13,167,687 shares of Class B common stock outstanding and Class A common stock 10-day volume-weighted average closing price of $15.38 at February 18, 2021. The February 18, 2021 redemption value of temporary equity became the carrying value of non-controlling interest, as discussed below. Non-controlling Interest Non-controlling interest represents the 19.0% interest in the units of Brigham LLC not owned by Brigham Minerals, as of December 31, 2021. Class B common stock is classified as non-controlling interest in the consolidated balance sheet as of February 19, 2021 and thereafter. 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 holders of Brigham LLC Units (and Class B common stock) have a redemption right into shares of Class A common stock. Under the Brigham LLC Agreement, each Brigham LLC 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 LLC 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 LLC 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. Non-controlling interest is recorded at its carrying value. For the period from February 19, 2021 to December 31, 2021, the Company recorded adjustments to the value of non-controlling interest as presented in the table below: (In Thousands) Non-controlling Interest Balance - February 19, 2021 $ — Reclassification from temporary equity (1) 202,496 Conversion of Class B common stock to Class A common stock (27,239) Net income attributable to non-controlling interest (2) 15,821 Distribution to holders of non-controlling interest declared (17,833) Balance - December 31, 2021 $ 173,245 (1) Represents the February 19, 2021, redemption value of temporary equity, prior to its reclassification to non-controlling interest. Based on 13,167,687 shares of Class B common stock outstanding and Class A common stock 10-day volume-weighted average closing price of $15.38 at February 18, 2021. (2) Net income attributable to non-controlling interest includes the period from February 19, 2021 through December 31, 2021.

Share-Based Compensation

Share-Based Compensation	12 Months Ended
	Dec. 31, 2021
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 and Non-controlling Interest,” 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 expense 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, 2021 is as follows: Incentive Units Number of Incentive Units Grant-date Fair Value Outstanding—January 1, 2021 141,820 $ 10.04 Vested (70,911) $ 10.04 Outstanding—December 31, 2021 70,909 $ 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 subject to time-based vesting ("RSUs") and restricted stock units subject to performance-based vesting ("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, 2021, 3,013,884 shares of Class A common stock remained available for future grants. Currently, all 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 expense measured at the fair value of the award on the date of grant. Brigham Minerals accounts for forfeitures as they occur. The Company has granted RSAs to certain employees, which 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 vested in one-third increments on each of April 23, 2020 and 2021 and will vest as to the final one-third increment on April 23, 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, 2021 is as follows: Restricted Stock Awards Number of RSAs Grant Date Fair Value Unvested at January 1, 2021 68,293 $ 21.25 Vested (1) (31,882) $ 21.25 Forfeited (5,978) $ 21.25 Unvested at December 31, 2021 30,433 $ 21.25 (1) 9,024 of these RSAs were withheld to satisfy employee tax withholding obligations. The Company has granted RSUs to certain employees and directors, which 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 issued to employees generally vest in one-third increments over a three-year period and RSUs issued to directors vest in one year from the date of grant. RSUs 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 such RSUs was determined using the closing share price on the applicable date of grant, which is then applied to the total number of RSUs granted. Brigham Minerals accounts for forfeitures as they occur. Brigham Minerals withheld 181,182 RSUs to satisfy employee tax withholding obligations totaling $3.8 million, related to the RSUs that vested in 2021. A summary of the RSU activity for the year ended December 31, 2021 is as follows: Restricted Stock Units Number of RSUs Weighted-Average Grant Date Fair Value Unvested at January 1, 2021 562,871 $ 17.81 Granted 583,998 $ 16.31 Vested (578,577) $ 17.48 Forfeited (14,316) $ 18.49 Unvested at December 31, 2021 553,976 $ 16.55 The Company has granted PSUs to certain officers and managers, which vest based on continuous employment and satisfaction of a market condition based on the absolute total stockholder return of the Company’s common stock, including paid dividends, over an approximate three-year performance period. The terms and conditions of the PSUs allow for vesting of the awards ranging between 0% (or forfeiture) and 200% of target. Expense related to these PSUs is recognized on a straight-line basis over the length of the applicable performance period. All compensation expense related to the market-based awards will be recognized if the requisite service period is fulfilled, even if the market condition is not achieved. The grant date fair value of such PSUs was determined using a Monte Carlo simulation model that 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 on the basis of historical volatility of a group of publicly traded oil and gas companies with a 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. The Company granted 753,546 PSUs (based on target) on April 23, 2019, with a performance period that ends on December 31, 2021. On December 31, 2021, 714,350 PSUs vested, based on 94.8% achievement of target, 39,196 PSUs were forfeited, and 271,521 PSUs totaling $5.7 million were withheld to satisfy employee tax withholding obligations. 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. During the year ended December 31, 2021, 472,378 PSUs (based on target) were granted with a performance period that ends on December 31, 2023. Using the assumptions in the table below, Brigham Minerals estimated the fair value of PSUs to be $17.02, $6.41 and $12.18, for PSUs granted in 2021, 2020 and 2019, respectively. Years Ended December 31, 2021 2020 2019 Expected dividend yield 6 % 11.5 % 8.1 % Risk-free interest rate 0.27 % 1.4 % 2.3 % Volatility 45 % 35 % 30 % A summary of the PSU activity for the year ended December 31, 2021 is as follows: Target PSUs Grant Date Fair Value Unvested at January 1, 2021 1,187,811 $ 10.07 Granted 472,378 $ 17.02 Vested (714,350) $ 12.18 Forfeited (39,196) $ 12.18 Unvested at December 31, 2021 906,643 $ 11.94 Share-Based Compensation Expense Share-based compensation expense is included in general and administrative expense in the Company’s consolidated statement of operations. Share-based compensation expense recorded for each type of share-based compensation award, was as follows for the periods indicated: Years Ended December 31, (In Thousands) 2021 2020 2019 Incentive Units (1) (3) $ 712 $ 712 $ 2,904 RSAs (2) (3) 623 1,254 3,972 RSUs (3) 10,128 7,390 4,630 PSUs (4) 6,288 4,259 2,361 Capitalized share-based compensation (5) (6) (8,048) (6,086) (3,818) Total share-based compensation expense $ 9,703 $ 7,529 $ 10,049 (1) Includes a cumulative effect adjustment to share-based compensation expense 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, 2021, Brigham Minerals capitalized $3.6 million of the share-based compensation to unevaluated property and $4.4 million to evaluated property on its consolidated balance sheet. (6) Brigham Minerals capitalizes a portion of the share-based compensation expense incurred after the IPO . Future Share-Based Compensation Expense The following table reflects the future share-based compensation expense expected to be recorded for the share-based compensation awards that were outstanding at December 31, 2021, a portion of which will be capitalized: (In Thousands) Incentive Units RSAs RSUs PSUs Total Year 2022 $ 534 $ 200 $ 5,815 $ 4,030 $ 10,579 2023 — — 2,822 3,063 5,885 Total $ 534 $ 200 $ 8,637 $ 7,093 $ 16,464

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The 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, 2021 and 2020. 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, 2021 and 2020, 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 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, 2021 was 19%. During the year ended December 31, 2021, the Company recognized income tax expense of $16.3 million. During the years ended December 31, 2020 and 2019, the Company recognized income tax benefit of $12.8 million and income tax expense of $2.7 million, respectively. Total income tax expense for the years ended December 31, 2021, 2020 and 2019 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) 2021 2020 2019 State Income Tax Current expense $ 270 $ 122 $ 692 Deferred expense/(benefit) 2,182 (1,876) 63 Federal Income Tax Current expense/(benefit) 10,217 (2,942) 1,322 Deferred expense/(benefit) 3,584 (8,066) 602 Totals: $ 16,253 $ (12,762) $ 2,679 Total current income tax expense/(benefit) $ 10,487 $ (2,820) $ 2,014 Total deferred income tax expense/(benefit) 5,766 (9,942) 665 Totals: $ 16,253 $ (12,762) $ 2,679 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) 2021 2020 2019 Income (loss) before income taxes $ 84,279 $ (70,756) $ 24,318 Less: income before income taxes attributable to predecessor — — 5,118 Less: income (loss) before income taxes attributable to non-controlling interests and temporary equity 17,851 (15,270) 9,858 Income (loss) before income taxes attributable to stockholders $ 66,428 $ (55,486) $ 9,342 Income tax at the federal statutory rate $ 13,950 $ (11,652) $ 1,962 State income taxes, net of federal benefit 540 (1,223) 717 State rate change (1) 1,397 — — Other federal tax effects 366 113 — Total income tax provision $ 16,253 $ (12,762) $ 2,679 (1) We recorded $1.4 million in deferred tax expenses to remeasure our deferred tax assets based on the tax rates that are expected to apply as the asset is realized in future periods. Brigham Minerals had $25.3 million and $24.9 million recorded as deferred tax asset as of December 31, 2021 and 2020. 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) 2021 2020 Deferred tax assets: Loss carryforwards $ 441 $ 627 Investment in subsidiary 25,102 24,405 Total deferred tax assets: $ 25,543 $ 25,032 Deferred tax liabilities: Oil and gas properties $ (235) $ (112) Total deferred tax liabilities $ (235) $ (112)

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies 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, 2021 and December 31, 2020.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2021
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, 2021, 2020 and 2019 the amounts paid to BLM for land brokerage services were immaterial. At December 31, 2021, 2020 and 2019, the liabilities recorded for services performed by BLM were immaterial. We provide certain services to Brigham Earth, LLC and affiliated entities. These include IT services and certain software, phone and equipment licenses. The IT services are passed through at our cost, which includes an allocable share of employee salary and administrative expenses. The software, phone and equipment licenses are passed through at our direct costs. Brigham Earth, LLC and its affiliated entities are owned in part by Ben M. Brigham, our founder and Executive Chairman of the Board.

COVID-19 Pandemic and Impact on

COVID-19 Pandemic and Impact on Global Demand for Oil and Natural Gas	12 Months Ended
	Dec. 31, 2021
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, remains a global pandemic, however, with the gradual easing of COVID-19 lockdown restrictions globally, primarily due to the increase in accessibility of vaccines and demand for the commodities produced by the oil and natural gas industry have continued to improve. In addition, commodity prices in 2021 have improved substantially from historic lows in 2020 and the current outlook on commodity prices is generally favorable. However, the duration of COVID-19 pandemic and potential future impact to our business and industry continues to be unpredictable and dynamic. Winter Storm Uri In February 2021, Winter Storm Uri caused severe winter weather and freezing temperatures in the southern United States, which effected our properties in the Permian and Anadarko Basins, resulting in the curtailment of a portion of our production, delays in drilling and completion of wells, other operational constraints and ultimately adversely impacted our first quarter 2021 production. These curtailments, delay and operational constraints also resulted in increases in commodity prices, primarily natural gas prices. For example, the Henry Hub spot market price for natural gas for the month of February 2021 ranged from a low of $2.66 per MMBtu to a high of $23.86 per MMBtu. Given we do not operate our properties, Brigham Minerals had limited visibility into the timing of when production resumed and was required to estimate the amount of production delivered to the purchaser and the price that would ultimately be received for the sale of the product.

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2021
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events On February 10, 2022, Brigham Minerals entered into a definitive purchase and sale agreement to acquire approximately 1,800 net royalty acres in the Midland Basin largely operated by Pioneer Natural Resources and Endeavor Energy Resources for approximately $15 million in cash and approximately 800,000 shares of Class A common stock subject to certain closing adjustments. On February 18, 2022, Brigham Minerals declared a dividend of $0.45 per Class A common stock payable on March 25, 2022, to stockholders of record at the close of business on March 18, 2022.

Reserve and Related Financial D

Reserve and Related Financial Data (SMOG) - Unaudited	12 Months Ended
	Dec. 31, 2021
Extractive Industries [Abstract]
Reserve and Related Financial Data (SMOG) - Unaudited	Acquisitions and Divestitures DJ Acquisition On November 3, 2021, the Company entered into a definitive purchase and sale agreement to acquire approximately 8,400 net royalty acres primarily in Weld County, Colorado, operated by PDC Energy, Inc., Chevron Corporation, Occidental Petroleum and Civitas Resources for 2.2 million shares of the Company’s common stock and $43.1 million of cash, net of $1.7 million of customary closing adjustments. The DJ Acquisition closed on December 15, 2021. The cash portion of the purchase price was funded through a combination of cash on hand and borrowings under the Company’s revolving credit facility. The following table presents the acquisition consideration paid in the DJ Acquisition (in thousands, except the number of shares and price per share): Consideration: Class A shares of Brigham Minerals, Inc. common stock issued at closing 2,180,128 Closing price per share of Brigham Minerals, Inc. common stock on the closing date $ 21.26 Fair Value of Brigham Minerals, Inc. common stock issued $ 46,349 Cash consideration 43,083 Total consideration (including fair value of Brigham Minerals, Inc. common stock issued) $ 89,432 The DJ Acquisition has been accounted for as an asset acquisition and the allocation of the purchase price was $17.9 million to unevaluated properties and $71.5 million to evaluated properties. Other Acquisitions During the years ended December 31, 2021 and 2020, Brigham Minerals entered into a number of 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 for the year ended December 31, 2021 is comprised of payments for acquisitions of minerals, land brokerage costs and capitalized general and administrative expenses that were funded with our retained operating cash flow, proceeds from asset sales and our revolving credit facility (hereinafter defined). The changes in the oil and natural gas property balance for the year ended December 31, 2020 were partially funded with proceeds from the December 2019 Offering as well as our retained cash flow and our revolving credit facility. Assets Acquired Cash Consideration Paid (In Thousands) Evaluated Unevaluated Year ended December 31, 2021 $ 26,822 $ 34,056 $ 60,878 Year ended December 31, 2020 $ 30,856 $ 35,725 $ 66,581 Divestitures During the year ended December 31, 2021, Brigham Minerals divested certain non-core, primarily undeveloped acreage in Oklahoma and received cash of $13.6 million. 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, 2021, 2020 and 2019 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, 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 Sales of minerals-in-place (71) (780) (73) (275) Extensions and discoveries 1,666 4,404 623 3,024 Acquisitions 2,739 14,683 1,662 6,849 Revisions of previous estimates 1,053 10,107 1,706 4,444 Production (1,677) (5,886) (642) (3,300) Proved reserve quantities, December 31, 2021 16,910 66,172 7,866 35,805 Proved reserve quantities at December 31, 2021 attributable to non-controlling interest 3,213 12,573 1,495 6,803 Proved developed reserve quantities: December 31, 2019 9,924 33,232 2,494 17,957 December 31, 2020 9,403 31,873 3,426 18,141 December 31, 2021 13,148 56,372 6,367 28,911 Proved developed reserves at December 31, 2021 attributable to temporary equity 2,498 10,711 1,210 5,493 Proved undeveloped reserve quantities: December 31, 2019 7,037 28,498 3,344 15,131 December 31, 2020 3,797 11,771 1,164 6,922 December 31, 2021 3,762 9,800 1,499 6,894 Proved undeveloped reserves at December 31, 2021 attributable to temporary equity 715 1,862 285 1,310 Changes in proved reserves that occurred during 2021 were primarily due to: • the acquisition of additional mineral interests located in the Permian, DJ and Williston Basins in multiple transactions. The acquired proved reserves of 6,849 MBoe throughout the year were offset by the divestiture of 275 MBoe of proved reserves; • well additions, extensions and discoveries of approximately 3,024 MBoe, as 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; • positive revision of 3,591 MBoe attributable to an increase in SEC pricing; and • positive revision of 852 MBoe due to PDP outperformance, estimate ultimate recovery ("EUR") adjustments, refined gas and NGL processing assumptions, and unit configuration. 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. 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 Years Ended December 31, (In Thousands) 2021 2020 2019 Future crude oil, natural gas, and NGL sales $ 1,512,784 $ 562,545 $ 1,042,118 Future severance tax and ad valorem taxes (109,849) (39,318) (73,627) Future income tax expense (214,311) (46,908) (143,599) Future net cash flows 1,188,624 476,319 824,892 10% annual discount (549,768) (205,551) (359,258) Standardized measure of discounted future net cash flows $ 638,856 $ 270,768 $ 465,634 Standardized measure of discounted future net cash flows attributable to temporary equity $ 121,383 $ 62,853 $ 186,999 The following prices were used in the determination of standardized measure: For the Years Ended December 31, 2021 2020 2019 Oil (per Bbl) $ 64.46 $ 36.35 $ 51.01 Natural gas (per Mcf) 3.22 1.03 1.51 NGLs (per Bbl) 26.65 8.19 14.39 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 29% to 41% of WTI. All p rices 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 Years Ended December 31, (In Thousands) 2021 2020 2019 Standardized measure of discounted future net cash flows, beginning of the year $ 270,768 $ 465,634 $ 443,459 Changes in the year resulting from: Sales, less production costs (140,561) (73,654) (86,492) Revisions of previous quantity estimates 106,664 (135,926) (41,539) Extensions, discoveries, and other additions 74,305 21,011 69,057 Net change in prices and production costs 268,687 (131,886) (99,660) Accretion of discount 23,763 54,741 51,949 Purchase of reserves in place 151,547 27,241 137,819 Divestitures of reserves in place (2,375) (250) (5,783) Net change in taxes (87,960) 53,786 (5,739) Timing differences and other (25,982) (9,929) 2,563 Standardized measure of discounted future net cash flows, end of the year $ 638,856 $ 270,768 $ 465,634 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 Years Ended December 31, (In Thousands) 2021 2020 2019 Oil and gas properties, at cost, using full cost method of accounting: Unevaluated property $ 338,613 $ 325,091 $ 291,664 Evaluated property 633,138 488,301 449,061 Total oil and gas properties, at cost 971,751 813,392 740,725 Less accumulated depreciation, depletion, and amortization (239,612) (189,546) (61,103) Total oil and gas properties, net $ 732,139 $ 623,846 $ 679,622 Costs incurred in oil and natural gas activities The following costs were incurred in oil and natural gas producing activities: For the Years Ended December 31, (In Thousands) 2021 2020 2019 Acquisition of oil and gas properties Unevaluated $ 51,934 $ 35,725 $ 78,093 Evaluated 98,377 30,856 140,025 Total $ 150,311 $ 66,581 $ 218,118

Significant Accounting Polici_2

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Recently Adopted Accounting Standards	Recently Adopted Accounting Standards Leases In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), (or "the new lease standard") amending the guidance on the accounting for leasing transactions. The new lease standard requires lessees to recognize a lease liability for the obligation to make lease payments and a right-of-use (“ROU”) asset for the right to use the underlying asset for the lease term. ASU 2016-02 does not apply to leases of mineral rights to explore for or use crude oil and natural gas. The ASU replaced most existing lease guidance in GAAP effective upon adoption. The Company adopted the new lease standard during the fiscal year ending December 31, 2021, with a beginning period of adoption of January 1, 2021. The Company made policy elections to apply the following practical expedients as provided in the standards update: • an accounting policy election to not apply the recognition requirements in the new standards update to short-term leases (a lease that at commencement date has a lease term of twelve months or less) and not to separate non-lease components from lease components for all asset classes; and • a package of practical expedients to not reassess whether a contract contains a lease, lease classification and initial direct costs prior to January 1, 2021. 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. The Company enters into land easements as a lessor, on a routine basis as part of its ongoing operations and has many such agreements currently in place; however, the Company did not account for any land easements under Topic 840. As this guidance serves as an amendment to the new lease standard, the Company elected this practical expedient, which became effective upon the date of adoption of the new lease standard. For Brigham Minerals, as a lessor, the amounts received with respect to term-based land easement payments were immaterial during the fiscal year ending December 31, 2021. The Company will assess any new land easements to determine whether the arrangement should be accounted for as a lease. Perpetual-based land easements are not in scope under the new lease standard. 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) and applying the modified retrospective approach, with a cumulative-effect adjustment to the opening balance of retained earnings as of the adoption date. The Company elected this transition approach, however the cumulative impact of adoption in the opening balance of retained earnings as of January 1, 2021 was immaterial. Financial Instruments — Credit Losses
Use of Estimates	Use of Estimates The preparation of consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities in the consolidated 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 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, share-based compensation expenses 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	Accounts ReceivableReceivables 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 operators and records a reserve for amounts not expected to be fully recovered, using a current expected credit loss model.
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, and its 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.
Financial Instruments	Financial Instruments Brigham Minerals’ financial instruments consist of cash and cash equivalents, receivables, payables, derivative assets and liabilities, 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 2021, 2020 and 2019. 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.
Leases	Leases The Company determines if an arrangement is a lease at inception of the arrangement. To the extent that we determine an arrangement represents a lease, we classify that lease as an operating lease or a finance lease, depending on the lease classification guidance. We currently do not have any finance leases. We capitalize our operating leases through an operating lease ROU asset and a corresponding operating lease liability on our consolidated balance sheets. ROU assets represent our right to use an underlying asset for the lease term and operating lease liabilities represent our obligation to make lease payments arising from the lease. Short-term leases that have an initial term of one year or less are not capitalized but are disclosed. Short-term lease costs exclude expenses related to leases with a lease term of one month or less. Our operating leases are reflected as operating lease right-of-use asset, current operating lease liability and non-current operating lease liability on our consolidated balance sheets. Operating lease ROU assets and liabilities are recognized at the commencement date of an arrangement based on the present value of lease payments over the lease term. In addition to the present value of lease payments, the operating lease ROU asset also includes any lease payments made to the lessor prior to lease commencement less any lease incentives and initial direct costs incurred. Lease expense for operating lease payments is recognized on a straight-line basis over the lease term. Nature of Leases We lease certain office space under a non-cancelable lease for our corporate headquarters. Our office agreements are typically structured with non-cancelable terms of one Discount Rate Our office agreement does not provide an implicit rate. Accordingly, we are required to use our incremental borrowing rate in determining the present value of lease payments based on the information available at commencement date. Our incremental borrowing rate reflects the estimated rate of interest that we would pay to borrow on a collateralized basis over a similar term in an amount equal to the lease payments in a similar economic environment. We use the implicit rate in the limited circumstances in which that rate is readily determinable. Practical Expedients and Accounting Policy Elections Certain of our lease agreements include lease and non-lease components. For all existing asset classes with multiple component types, we have utilized the practical expedient that exempts us from separating lease components from non-lease components. Accordingly, we account for the lease and non-lease components in an arrangement as a single lease component. In addition, for all of our existing asset classes, we have made an accounting policy election not to apply the lease recognition requirements to our short-term leases (that is, a lease that, at commencement, has a lease term of 12 months or less and does not include an option to purchase the underlying asset that we are reasonably certain to exercise). Accordingly, we recognize lease payments related to our short-term leases in our statements of operations on a straight-line basis over the lease term which has not changed from our prior recognition. To the extent that there are variable lease payments, we recognize those payments in our statements of operations in the period in which the obligation for those payments is incurred. Lease payments on our short-term leases during the years ended December 31, 2021, 2020 and 2019 were immaterial.
Accounting for Leases as a Lessor	Accounting for Leases as a Lessor The Company acts as a lessor with respect to amounts received for land easements (also commonly referred to as rights of way). Land easements represent the right to use, access, or cross another entity's land for a specified purpose. The Company elected to apply the land easement practical expedients and does not evaluate existing or expired land easements that were not previously accounted for as leases under Topic 840. A land easement may be perpetual or term-based. Perpetual easements are not in scope under the new leasing standard. All term-based land easements granted by the Company during the year ended December 31, 2021 were immaterial in the aggregate.
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 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 expense 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 statements of operations included within this Annual Report. There was approximately $16.5 million of unamortized compensation expense relating to outstanding awards at December 31, 2021, 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	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
Temporary Equity	Temporary Equity Brigham Minerals accounted 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 and Non-controlling Interest.” As such, the Company adjusted 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 Company's Board of Directors (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. As a result of the appointment of an additional independent member to our Board of Directors on February 19, 2021, the holders of Class B common stock no longer hold a majority of the votes of the Board of Directors and no longer control the Board of Directors through direct representation on the Board of Directors. Consequently, after February 19, 2021, Class B common stock is presented as non-controlling interest (as discussed below) in the consolidated balance sheets of Brigham Minerals.
Non-Controlling Interest	Non-Controlling Interest As of February 19, 2021 and thereafter, the 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 each holder of Brigham LLC Unit's (each a "Brigham LLC Unit Holder") exercise of its Redemption Right (as hereinafter defined). As such, at December 31, 2021, Brigham Minerals accounts for Brigham LLC Unit Holders' 19.0% interest in Brigham LLC not owned by Brigham Minerals as non-controlling interest. For further discussion, see “Note 9—Temporary Equity and Non-controlling Interest.”
Revenue from Contracts with Customers	Revenue from Contracts with Customers Mineral and royalty revenues Mineral and royalty 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. During the twelve months ending December 31, 2021, 2020 and 2019 the disaggregated revenues from sales of oil, natural gas and NGLs are as follows: For the Years Ended December 31, Disaggregated revenues (in thousands) 2021 2020 2019 Oil sales $ 110,791 $ 67,909 $ 82,048 Natural gas sales 27,070 10,443 9,724 NGL sales 18,838 7,893 6,114 Total mineral and royalty revenues $ 156,699 $ 86,245 $ 97,886 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 Mineral and royalty revenues 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.
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, 2021
Accounting Policies [Abstract]
Schedule of Accounts Receivable	At December 31, 2021 and 2020, accounts receivable was comprised of the following: December 31, (In Thousands) 2021 2020 Accounts receivable Oil and gas sales $ 30,485 $ 17,413 Reserve for credit losses (995) (855) Other 1,049 1,074 Total accounts receivables $ 30,539 $ 17,632
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 Years Ended December 31, 2021 2020 2019 Exxon Mobil Corp. 13 % 11 % 10 % Occidental Petroleum Corp. 11 % 12 % 16 % ConocoPhillips Company (1) 11 % 14 % — % Continental Resources, Inc. 10 % 10 % 12 %
Summary of Disaggregation of Revenue	During the twelve months ending December 31, 2021, 2020 and 2019 the disaggregated revenues from sales of oil, natural gas and NGLs are as follows: For the Years Ended December 31, Disaggregated revenues (in thousands) 2021 2020 2019 Oil sales $ 110,791 $ 67,909 $ 82,048 Natural gas sales 27,070 10,443 9,724 NGL sales 18,838 7,893 6,114 Total mineral and royalty revenues $ 156,699 $ 86,245 $ 97,886

Oil and Gas Properties (Tables)

Oil and Gas Properties (Tables)	12 Months Ended
	Dec. 31, 2021
Extractive Industries [Abstract]
Schedule of Oil and Gas Properties	Oil and gas properties consisted of the following: December 31, (In Thousands) 2021 2020 Oil and gas properties, at cost, using the full cost method of accounting: Unevaluated property $ 338,613 $ 325,091 Evaluated property 633,138 488,301 Total oil and gas properties, at cost 971,751 813,392 Less accumulated depreciation, depletion, and amortization (239,612) (189,546) Total oil and gas properties, net $ 732,139 $ 623,846 Costs not subject to depletion are as follows, by the year in which such costs were incurred: By Year: (In Thousands) Total 2021 2020 2019 2018 2017 Prior Property Acquisition costs $ 338,613 $ 45,885 $ 32,456 $ 71,385 $ 64,582 $ 58,619 $ 65,686 The aggregate amounts of costs capitalized for oil and natural gas producing activities and related aggregate amounts of accumulated depletion follow: For the Years Ended December 31, (In Thousands) 2021 2020 2019 Oil and gas properties, at cost, using full cost method of accounting: Unevaluated property $ 338,613 $ 325,091 $ 291,664 Evaluated property 633,138 488,301 449,061 Total oil and gas properties, at cost 971,751 813,392 740,725 Less accumulated depreciation, depletion, and amortization (239,612) (189,546) (61,103) Total oil and gas properties, net $ 732,139 $ 623,846 $ 679,622

Acquisitions and Divestitures (

Acquisitions and Divestitures (Tables)	12 Months Ended
	Dec. 31, 2021
Business Combination and Asset Acquisition [Abstract]
Schedule of Acquisition Considerations	The following table presents the acquisition consideration paid in the DJ Acquisition (in thousands, except the number of shares and price per share): Consideration: Class A shares of Brigham Minerals, Inc. common stock issued at closing 2,180,128 Closing price per share of Brigham Minerals, Inc. common stock on the closing date $ 21.26 Fair Value of Brigham Minerals, Inc. common stock issued $ 46,349 Cash consideration 43,083 Total consideration (including fair value of Brigham Minerals, Inc. common stock issued) $ 89,432
Schedule of Asset Acquisitions	During the years ended December 31, 2021 and 2020, Brigham Minerals entered into a number of 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 for the year ended December 31, 2021 is comprised of payments for acquisitions of minerals, land brokerage costs and capitalized general and administrative expenses that were funded with our retained operating cash flow, proceeds from asset sales and our revolving credit facility (hereinafter defined). The changes in the oil and natural gas property balance for the year ended December 31, 2020 were partially funded with proceeds from the December 2019 Offering as well as our retained cash flow and our revolving credit facility. Assets Acquired Cash Consideration Paid (In Thousands) Evaluated Unevaluated Year ended December 31, 2021 $ 26,822 $ 34,056 $ 60,878 Year ended December 31, 2020 $ 30,856 $ 35,725 $ 66,581 The following costs were incurred in oil and natural gas producing activities: For the Years Ended December 31, (In Thousands) 2021 2020 2019 Acquisition of oil and gas properties Unevaluated $ 51,934 $ 35,725 $ 78,093 Evaluated 98,377 30,856 140,025 Total $ 150,311 $ 66,581 $ 218,118

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2021
Leases [Abstract]
Summary of Recognition of Operating Lease	The following table summarizes the Company’s recognition of its operating lease: (In Thousands) Classification December 31, 2021 Assets Operating Operating lease right-of-use assets $ 6,764 Liabilities Current: Operating Current operating lease liability $ 1,178 Non-current: Operating Non-current operating lease liability $ 5,742
Schedule of Future Minimum Lease Commitments	The table below presents the maturity of the Company’s liabilities under the Bridgepoint Lease as of December 31, 2021. Year Commitment 2022 $ 1,296 2023 1,319 2024 1,340 2025 1,360 2026 1,383 Thereafter 582 Total lease payments $ 7,280 Less imputed interest (360) Total lease liabilities $ 6,920

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2021
Equity [Abstract]
Schedule of Earnings Per Share, Basic and Diluted	The following table reflects the allocation of net income (loss) to common stockholders 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) 2021 2020 2019 Basic EPS Numerator: Basic net income (loss) attributable to Brigham Minerals, Inc. stockholders $ 50,283 $ (42,412) $ 6,901 Less net income attributable to stockholders pre-IPO — — (848) Basic net income (loss) attributable to Brigham Minerals, Inc. stockholders post-IPO (1) $ 50,283 $ (42,412) $ 6,053 Denominator: Basic weighted average shares outstanding (1) 44,576 38,178 22,870 Basic EPS attributable to Brigham Minerals, Inc. stockholders $ 1.13 $ (1.11) $ 0.26 Diluted EPS Numerator: Basic net income (loss) attributable to Brigham Minerals, Inc. stockholders post-IPO (1) $ 50,283 $ (42,412) $ 6,053 Diluted net income (loss) attributable to Brigham Minerals, Inc. stockholders $ 50,283 $ (42,412) $ 6,053 Denominator: Basic weighted average shares outstanding (1) 44,576 38,178 22,870 Effect of dilutive securities: Unvested equity awards 1,056 — — Diluted weighted average shares outstanding 45,632 38,178 22,870 Diluted EPS attributable to Brigham Minerals, Inc. stockholders $ 1.10 $ (1.11) $ 0.26

Temporary equity and Non-cont_2

Temporary equity and Non-controlling interest (Tables)	12 Months Ended
	Dec. 31, 2021
Temporary Equity Disclosure [Abstract]
Temporary Equity	From the date of the IPO through February 18, 2021, Brigham Minerals 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 Net income attributable to temporary equity 1,922 Adjustment of temporary equity to redemption value 54,294 Reclassification to non-controlling interest (4) (202,496) Balance - February 18, 2021 $ — (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. (4) Based on 13,167,687 shares of Class B common stock outstanding and Class A common stock 10-day volume-weighted average closing price of $15.38 at February 18, 2021. The February 18, 2021 redemption value of temporary equity became the carrying value of non-controlling interest, as discussed below.
Schedule Of Adjustments To Noncontrolling Interests	For the period from February 19, 2021 to December 31, 2021, the Company recorded adjustments to the value of non-controlling interest as presented in the table below: (In Thousands) Non-controlling Interest Balance - February 19, 2021 $ — Reclassification from temporary equity (1) 202,496 Conversion of Class B common stock to Class A common stock (27,239) Net income attributable to non-controlling interest (2) 15,821 Distribution to holders of non-controlling interest declared (17,833) Balance - December 31, 2021 $ 173,245 (1) Represents the February 19, 2021, redemption value of temporary equity, prior to its reclassification to non-controlling interest. Based on 13,167,687 shares of Class B common stock outstanding and Class A common stock 10-day volume-weighted average closing price of $15.38 at February 18, 2021. (2) Net income attributable to non-controlling interest includes the period from February 19, 2021 through December 31, 2021.

Share-Based Compensation (Table

Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2021
Share-based Payment Arrangement [Abstract]
Schedule of Restricted Incentive Unit Activity	A summary of the Incentive Unit activity for the year ended December 31, 2021 is as follows: Incentive Units Number of Incentive Units Grant-date Fair Value Outstanding—January 1, 2021 141,820 $ 10.04 Vested (70,911) $ 10.04 Outstanding—December 31, 2021 70,909 $ 10.04 A summary of the RSU activity for the year ended December 31, 2021 is as follows: Restricted Stock Units Number of RSUs Weighted-Average Grant Date Fair Value Unvested at January 1, 2021 562,871 $ 17.81 Granted 583,998 $ 16.31 Vested (578,577) $ 17.48 Forfeited (14,316) $ 18.49 Unvested at December 31, 2021 553,976 $ 16.55
Nonvested Restricted Stock Shares Activity	A summary of the RSA activity for the year ended December 31, 2021 is as follows: Restricted Stock Awards Number of RSAs Grant Date Fair Value Unvested at January 1, 2021 68,293 $ 21.25 Vested (1) (31,882) $ 21.25 Forfeited (5,978) $ 21.25 Unvested at December 31, 2021 30,433 $ 21.25 (1) 9,024 of these RSAs were withheld to satisfy employee tax withholding obligations.
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions	Using the assumptions in the table below, Brigham Minerals estimated the fair value of PSUs to be $17.02, $6.41 and $12.18, for PSUs granted in 2021, 2020 and 2019, respectively. Years Ended December 31, 2021 2020 2019 Expected dividend yield 6 % 11.5 % 8.1 % Risk-free interest rate 0.27 % 1.4 % 2.3 % Volatility 45 % 35 % 30 %
Schedule of Nonvested Performance-based Units Activity	A summary of the PSU activity for the year ended December 31, 2021 is as follows: Target PSUs Grant Date Fair Value Unvested at January 1, 2021 1,187,811 $ 10.07 Granted 472,378 $ 17.02 Vested (714,350) $ 12.18 Forfeited (39,196) $ 12.18 Unvested at December 31, 2021 906,643 $ 11.94
Schedule of Share-Based Compensation Expense	Share-based compensation expense recorded for each type of share-based compensation award, was as follows for the periods indicated: Years Ended December 31, (In Thousands) 2021 2020 2019 Incentive Units (1) (3) $ 712 $ 712 $ 2,904 RSAs (2) (3) 623 1,254 3,972 RSUs (3) 10,128 7,390 4,630 PSUs (4) 6,288 4,259 2,361 Capitalized share-based compensation (5) (6) (8,048) (6,086) (3,818) Total share-based compensation expense $ 9,703 $ 7,529 $ 10,049 (1) Includes a cumulative effect adjustment to share-based compensation expense 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, 2021, Brigham Minerals capitalized $3.6 million of the share-based compensation to unevaluated property and $4.4 million to evaluated property on its consolidated balance sheet. (6) Brigham Minerals capitalizes a portion of the share-based compensation expense incurred after the IPO . Future Share-Based Compensation Expense The following table reflects the future share-based compensation expense expected to be recorded for the share-based compensation awards that were outstanding at December 31, 2021, a portion of which will be capitalized: (In Thousands) Incentive Units RSAs RSUs PSUs Total Year 2022 $ 534 $ 200 $ 5,815 $ 4,030 $ 10,579 2023 — — 2,822 3,063 5,885 Total $ 534 $ 200 $ 8,637 $ 7,093 $ 16,464

Income Taxes Income Taxes (Tabl

Income Taxes Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit)	Years Ended December 31, (In Thousands) 2021 2020 2019 State Income Tax Current expense $ 270 $ 122 $ 692 Deferred expense/(benefit) 2,182 (1,876) 63 Federal Income Tax Current expense/(benefit) 10,217 (2,942) 1,322 Deferred expense/(benefit) 3,584 (8,066) 602 Totals: $ 16,253 $ (12,762) $ 2,679 Total current income tax expense/(benefit) $ 10,487 $ (2,820) $ 2,014 Total deferred income tax expense/(benefit) 5,766 (9,942) 665 Totals: $ 16,253 $ (12,762) $ 2,679
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) 2021 2020 2019 Income (loss) before income taxes $ 84,279 $ (70,756) $ 24,318 Less: income before income taxes attributable to predecessor — — 5,118 Less: income (loss) before income taxes attributable to non-controlling interests and temporary equity 17,851 (15,270) 9,858 Income (loss) before income taxes attributable to stockholders $ 66,428 $ (55,486) $ 9,342 Income tax at the federal statutory rate $ 13,950 $ (11,652) $ 1,962 State income taxes, net of federal benefit 540 (1,223) 717 State rate change (1) 1,397 — — Other federal tax effects 366 113 — Total income tax provision $ 16,253 $ (12,762) $ 2,679 (1) We recorded $1.4 million in deferred tax expenses to remeasure our deferred tax assets based on the tax rates that are expected to apply as the asset is realized in future periods.
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) 2021 2020 Deferred tax assets: Loss carryforwards $ 441 $ 627 Investment in subsidiary 25,102 24,405 Total deferred tax assets: $ 25,543 $ 25,032 Deferred tax liabilities: Oil and gas properties $ (235) $ (112) Total deferred tax liabilities $ (235) $ (112)

Reserve and Related Financial_2

Reserve and Related Financial Data (SMOG) - Unaudited (Tables)	12 Months Ended
	Dec. 31, 2021
Extractive Industries [Abstract]
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities	The reserves at December 31, 2021, 2020 and 2019 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, 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 Sales of minerals-in-place (71) (780) (73) (275) Extensions and discoveries 1,666 4,404 623 3,024 Acquisitions 2,739 14,683 1,662 6,849 Revisions of previous estimates 1,053 10,107 1,706 4,444 Production (1,677) (5,886) (642) (3,300) Proved reserve quantities, December 31, 2021 16,910 66,172 7,866 35,805 Proved reserve quantities at December 31, 2021 attributable to non-controlling interest 3,213 12,573 1,495 6,803 Proved developed reserve quantities: December 31, 2019 9,924 33,232 2,494 17,957 December 31, 2020 9,403 31,873 3,426 18,141 December 31, 2021 13,148 56,372 6,367 28,911 Proved developed reserves at December 31, 2021 attributable to temporary equity 2,498 10,711 1,210 5,493 Proved undeveloped reserve quantities: December 31, 2019 7,037 28,498 3,344 15,131 December 31, 2020 3,797 11,771 1,164 6,922 December 31, 2021 3,762 9,800 1,499 6,894 Proved undeveloped reserves at December 31, 2021 attributable to temporary equity 715 1,862 285 1,310
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 Years Ended December 31, (In Thousands) 2021 2020 2019 Future crude oil, natural gas, and NGL sales $ 1,512,784 $ 562,545 $ 1,042,118 Future severance tax and ad valorem taxes (109,849) (39,318) (73,627) Future income tax expense (214,311) (46,908) (143,599) Future net cash flows 1,188,624 476,319 824,892 10% annual discount (549,768) (205,551) (359,258) Standardized measure of discounted future net cash flows $ 638,856 $ 270,768 $ 465,634 Standardized measure of discounted future net cash flows attributable to temporary equity $ 121,383 $ 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 Years Ended December 31, 2021 2020 2019 Oil (per Bbl) $ 64.46 $ 36.35 $ 51.01 Natural gas (per Mcf) 3.22 1.03 1.51 NGLs (per Bbl) 26.65 8.19 14.39
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 Years Ended December 31, (In Thousands) 2021 2020 2019 Standardized measure of discounted future net cash flows, beginning of the year $ 270,768 $ 465,634 $ 443,459 Changes in the year resulting from: Sales, less production costs (140,561) (73,654) (86,492) Revisions of previous quantity estimates 106,664 (135,926) (41,539) Extensions, discoveries, and other additions 74,305 21,011 69,057 Net change in prices and production costs 268,687 (131,886) (99,660) Accretion of discount 23,763 54,741 51,949 Purchase of reserves in place 151,547 27,241 137,819 Divestitures of reserves in place (2,375) (250) (5,783) Net change in taxes (87,960) 53,786 (5,739) Timing differences and other (25,982) (9,929) 2,563 Standardized measure of discounted future net cash flows, end of the year $ 638,856 $ 270,768 $ 465,634
Schedule of Capitalized Oil and Natural Gas Costs	Oil and gas properties consisted of the following: December 31, (In Thousands) 2021 2020 Oil and gas properties, at cost, using the full cost method of accounting: Unevaluated property $ 338,613 $ 325,091 Evaluated property 633,138 488,301 Total oil and gas properties, at cost 971,751 813,392 Less accumulated depreciation, depletion, and amortization (239,612) (189,546) Total oil and gas properties, net $ 732,139 $ 623,846 Costs not subject to depletion are as follows, by the year in which such costs were incurred: By Year: (In Thousands) Total 2021 2020 2019 2018 2017 Prior Property Acquisition costs $ 338,613 $ 45,885 $ 32,456 $ 71,385 $ 64,582 $ 58,619 $ 65,686 The aggregate amounts of costs capitalized for oil and natural gas producing activities and related aggregate amounts of accumulated depletion follow: For the Years Ended December 31, (In Thousands) 2021 2020 2019 Oil and gas properties, at cost, using full cost method of accounting: Unevaluated property $ 338,613 $ 325,091 $ 291,664 Evaluated property 633,138 488,301 449,061 Total oil and gas properties, at cost 971,751 813,392 740,725 Less accumulated depreciation, depletion, and amortization (239,612) (189,546) (61,103) Total oil and gas properties, net $ 732,139 $ 623,846 $ 679,622
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure	During the years ended December 31, 2021 and 2020, Brigham Minerals entered into a number of 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 for the year ended December 31, 2021 is comprised of payments for acquisitions of minerals, land brokerage costs and capitalized general and administrative expenses that were funded with our retained operating cash flow, proceeds from asset sales and our revolving credit facility (hereinafter defined). The changes in the oil and natural gas property balance for the year ended December 31, 2020 were partially funded with proceeds from the December 2019 Offering as well as our retained cash flow and our revolving credit facility. Assets Acquired Cash Consideration Paid (In Thousands) Evaluated Unevaluated Year ended December 31, 2021 $ 26,822 $ 34,056 $ 60,878 Year ended December 31, 2020 $ 30,856 $ 35,725 $ 66,581 The following costs were incurred in oil and natural gas producing activities: For the Years Ended December 31, (In Thousands) 2021 2020 2019 Acquisition of oil and gas properties Unevaluated $ 51,934 $ 35,725 $ 78,093 Evaluated 98,377 30,856 140,025 Total $ 150,311 $ 66,581 $ 218,118

Business and Basis of Present_2

Business and Basis of Presentation (Details)	Sep. 15, 2020USD ($)$ / sharesshares	Jun. 12, 2020USD ($)$ / sharesshares	Dec. 16, 2019USD ($)$ / sharesshares	Apr. 30, 2019USD ($)shares	Dec. 31, 2021USD ($)segment	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Apr. 17, 2019$ / shares	Jul. 16, 2018
Schedule of Equity Method Investments [Line Items]
Proceeds from issuance of common stock | $					$ 0	$ 0	$ 102,680,000
Number of operating segments | segment					1
Brigham LLC
Schedule of Equity Method Investments [Line Items]
Sale of stock, ownership percentage					81.00%
Brigham LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage by subsidiary				43.30%
Existing Owners of Brigham Minerals | Brigham LLC
Schedule of Equity Method Investments [Line Items]
Sale of stock, ownership percentage					19.00%
Other Entities Affiliated With Yorktown Partners L L C And Pine Brook Road Advisors L P | Brigham Minerals
Schedule of Equity Method Investments [Line Items]
Sale of stock, ownership percentage					8.70%
New Revolving Credit Facility
Schedule of Equity Method Investments [Line Items]
Repayments of lines of credit | $			$ 80,000,000	$ 200,000,000
Initial Public Offering
Schedule of Equity Method Investments [Line Items]
Consideration received | $				$ 273,400,000
December Offering, Company
Schedule of Equity Method Investments [Line Items]
Consideration received | $			$ 102,700,000
September Offering | Existing Owners of Brigham Minerals | Brigham LLC
Schedule of Equity Method Investments [Line Items]
Sale of stock, ownership percentage						23.20%
Class A Common Stock | Initial Public Offering
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
Class A Common Stock | December Offering
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)			12,650,000
Class A Common Stock | December Offering, Company
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)			6,000,000
Class A Common Stock | December Offering, Selling Shareholders
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
Class A Common Stock | December Offering, Equivalent Units Issued
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)			5,496,813
Class A Common Stock | June Offering
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
Class A Common Stock | June Offering, Equivalent Units Issued By Selling Shareholders
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)		4,872,669
Class A Common Stock | September Offering
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
Class A Common Stock | September Offering, Over-Allotment Option
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)	654,931
Class A Common Stock | September Offering, Equivalent Units Issued By Selling Shareholders
Schedule of Equity Method Investments [Line Items]
Sale of stock, number of shares issued (in shares)	3,062,011
Brigham Resources
Schedule of Equity Method Investments [Line Items]
Equity method investment, ownership percentage									16.50%

Significant Accounting Polici_4

Significant Accounting Policies - Narrative (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2021USD ($)customer	Dec. 31, 2020USD ($)customer	Dec. 31, 2019USD ($)	Jul. 31, 2019
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Bad debt expense	$ 500	$ 300	$ 600
Number of operators | customer	178	145
Term of lease				5 years
Share based compensation expense	$ 16,464
Employer matching contribution, percent of match	100.00%
Employer matching contribution, percent of employees' total compensation	6.00%
Contributions	$ 400	$ 400	300
Debt issuance costs	1,200	800
Accumulated amortization of debt issuance costs	1,100	800
Amortization of debt issuance costs	$ 313	605	$ 433
Unamortized debt issuance costs written off		$ 300
Maximum
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Term of lease	10 years
Minimum
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Term of lease	1 year
Brigham LLC
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Sale of stock, ownership percentage	81.00%
Brigham LLC | Existing Owners of Brigham Minerals
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Sale of stock, ownership percentage	19.00%
Brigham LLC | September Offering | Existing Owners of Brigham Minerals
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Sale of stock, ownership percentage		23.20%
Top Ten Operators | Revenue Benchmark | Customer Concentration Risk
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Concentration risk (as a percentage)	67.00%	70.00%

Significant Accounting Polici_5

Significant Accounting Policies - Schedule of Accounts Receivable (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Accounting Policies [Abstract]
Oil and gas sales	$ 30,485	$ 17,413
Reserve for credit losses	(995)	(855)
Other	1,049	1,074
Total accounts receivables	$ 30,539	$ 17,632

Significant Accounting Polici_6

Significant Accounting Policies - Schedule of Concentration Risk (Details) - Sales Revenue, Product Line - Customer Concentration Risk	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Exxon Mobil Corp.
Concentration Risk [Line Items]
Concentration risk (as a percentage)	13.00%	11.00%	10.00%
Occidental Petroleum Corp.
Concentration Risk [Line Items]
Concentration risk (as a percentage)	11.00%	12.00%	16.00%
ConocoPhillips Company
Concentration Risk [Line Items]
Concentration risk (as a percentage)	11.00%	14.00%	0.00%
Continental Resources, Inc.
Concentration Risk [Line Items]
Concentration risk (as a percentage)	10.00%	10.00%	12.00%

Significant Accounting Polici_7

Significant Accounting Policies - Summary of Disaggregation of Revenue (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Total mineral and royalty revenues	$ 156,699	$ 86,245	$ 97,886
Oil sales
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Total mineral and royalty revenues	110,791	67,909	82,048
Natural gas sales
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Total mineral and royalty revenues	27,070	10,443	9,724
NGL sales
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Total mineral and royalty revenues	$ 18,838	$ 7,893	$ 6,114

Oil and Gas Properties - Schedu

Oil and Gas Properties - Schedule of Oil and Gas Properties (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Oil and gas properties, at cost, using the full cost method of accounting:
Unevaluated property	$ 338,613	$ 325,091
Evaluated property	633,138	488,301
Total oil and gas properties, at cost	971,751	813,392
Less accumulated depreciation, depletion, and amortization	(239,612)	(189,546)
Total oil and gas properties, net	732,139	623,846
Costs not subject to depletion, cost per year	$ 45,885	$ 32,456	$ 71,385	$ 64,582	$ 58,619	$ 65,686

Oil and Gas Properties - Narrat

Oil and Gas Properties - Narrative (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2021USD ($)$ / Boe	Dec. 31, 2020USD ($)$ / Boe	Dec. 31, 2019USD ($)$ / Boe
Extractive Industries [Abstract]
Capitalized costs	$ 13,000	$ 10,200	$ 7,400
Depletion expense	$ 36,400	$ 47,300	$ 30,400
Full cost pool depletion per barrel of oil equivalent | $ / Boe	11.05	13.63	11.22
Impairment of oil and gas properties	$ 0	$ 79,569	$ 0

Acquisitions and Divestitures -

Acquisitions and Divestitures - Narrative (Details) $ in Thousands	Dec. 15, 2021USD ($)shares	Nov. 03, 2021USD ($)ashares	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Asset Acquisition [Line Items]
Unevaluated property			$ 338,613	$ 325,091	$ 291,664
Evaluated property			633,138	$ 488,301	$ 449,061
DJ Acquisition
Asset Acquisition [Line Items]
Acquisition of land | a		8,400
Shares transferred during acquisition (in shares) | shares	2,180,128	2,200,000
Cash consideration	$ 43,083	$ 43,100
Unevaluated property	17,900
Closing adjustments to payments for acquisition		$ 1,700
Evaluated property	$ 71,500
Oklahoma
Asset Acquisition [Line Items]
Proceeds from undeveloped acreage			$ 13,600

Acquisitions and Divestitures_2

Acquisitions and Divestitures - Schedule of Acquisition Considerations (Details) - USD ($) $ / shares in Units, $ in Thousands	Dec. 15, 2021	Nov. 03, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Asset Acquisition [Line Items]
Evaluated property			$ 633,138	$ 488,301	$ 449,061
DJ Acquisition
Asset Acquisition [Line Items]
Shares transferred during acquisition (in shares)	2,180,128	2,200,000
Closing price per share of Brigham Minerals, Inc. common stock on the closing date (in dollars per share)	$ 21.26
Fair Value of Brigham Minerals, Inc. common stock issued	$ 46,349
Cash consideration	43,083	$ 43,100
Total consideration (including fair value of Brigham Minerals, Inc. common stock issued)	89,432
Evaluated property	$ 71,500

Acquisitions and Divestitures_3

Acquisitions and Divestitures - Schedule of Acquisitions (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Asset Acquisition [Line Items]
Assets acquired, evaluated	$ 98,377	$ 30,856	$ 140,025
Assets acquired, unevaluated	51,934	35,725	78,093
Total	150,311	66,581	$ 218,118
Texas, Oklahoma, Colorado, New Mexico, North Dakota
Asset Acquisition [Line Items]
Assets acquired, evaluated	26,822	30,856
Assets acquired, unevaluated	34,056	35,725
Total	$ 60,878	$ 66,581

Long-Term Debt (Details)

Long-Term Debt (Details) $ in Millions	Dec. 15, 2021USD ($)	Dec. 31, 2021USD ($)	Jul. 07, 2021USD ($)	May 16, 2019USD ($)
New Revolving Credit Facility | Brigham Resources, LLC
Debt Instrument [Line Items]
Debt instrument, covenant, current ratio, minimum	1
Debt instrument, covenant, total net funded debt to consolidated EBITDA ratio, maximum	3.50
New Revolving Credit Facility | Brigham Resources, LLC | Interest period, one month
Debt Instrument [Line Items]
Interest payment, period (in months)	1 month
New Revolving Credit Facility | Brigham Resources, LLC | Interest period, two months
Debt Instrument [Line Items]
Interest payment, period (in months)	2 months
New Revolving Credit Facility | Brigham Resources, LLC | Interest period, three months
Debt Instrument [Line Items]
Interest payment, period (in months)	3 months
New Revolving Credit Facility | Brigham Resources, LLC | Interest period, six months
Debt Instrument [Line Items]
Interest payment, period (in months)	6 months
New Revolving Credit Facility | Brigham Resources, LLC | Interest period, twelve months
Debt Instrument [Line Items]
Interest payment, period (in months)	12 months
New Revolving Credit Facility | Minimum | Brigham Resources, LLC
Debt Instrument [Line Items]
Commitment fee, percentage	0.375%
New Revolving Credit Facility | Maximum | Brigham Resources, LLC
Debt Instrument [Line Items]
Commitment fee, percentage	0.50%
New Revolving Credit Facility | London Interbank Offered Rate (LIBOR) | Minimum | Brigham Resources, LLC
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)	2.50%
New Revolving Credit Facility | London Interbank Offered Rate (LIBOR) | Maximum | Brigham Resources, LLC
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)	3.50%
New Revolving Credit Facility | Adjusted Base Rate | Minimum | Brigham Resources, LLC
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)	1.50%
New Revolving Credit Facility | Adjusted Base Rate | Maximum | Brigham Resources, LLC
Debt Instrument [Line Items]
Basis spread on variable rate (as a percent)	2.50%
Revolving Credit Facility
Debt Instrument [Line Items]
Line of credit, borrowing base	$ 230	$ 230	$ 165	$ 135
Maximum leverage ratio			3
Minimum liquidity ratio			0.10
Weighted average interest rate		2.31%
Outstanding borrowings		$ 93
Remaining borrowing availability		$ 137

Leases - Narrative (Details)

Leases - Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Jul. 31, 2019ft²extension
Leases [Abstract]
Land lease | ft²				29,546
Amount of renewal terms | extension				2
Term of lease				5 years
Discount rate	2.00%
Rent expense | $	$ 1.3	$ 1.1	$ 0.6

Leases - Summary of Future Mini

Leases - Summary of Future Minimum Lease Commitments (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Operating lease right-of-use asset	$ 6,764	$ 0
Current operating lease liability	1,178	0
Non-current operating lease liability	$ 5,742	$ 0

Leases - Schedule of Future Min

Leases - Schedule of Future Minimum Lease Commitments (Details) $ in Thousands	Dec. 31, 2021USD ($)
Leases [Abstract]
2022	$ 1,296
2023	1,319
2024	1,340
2025	1,360
2026	1,383
Thereafter	582
Total lease payments	7,280
Less imputed interest	(360)
Total lease liabilities	$ 6,920

Equity - Narrative (Details)

Equity - Narrative (Details)	Sep. 15, 2020$ / sharesshares	Dec. 31, 2021voteshares	Dec. 31, 2020shares
Class of Stock [Line Items]
Treasury stock (in shares)		436,630	436,630
Class A Common Stock
Class of Stock [Line Items]
Common stock outstanding (in shares)		48,359,888	43,558,494
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)		11,371,517	13,167,687
Number of votes per share (vote) | vote		1

Equity - Schedule of Earnings p

Equity - Schedule of Earnings per Share, Basic and Diluted (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	4 Months Ended	8 Months Ended	12 Months Ended
	Apr. 16, 2019	Dec. 31, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Numerator:
Basic net income (loss) attributable to Brigham Minerals, Inc. stockholders	$ 848	$ 6,053	$ 50,283	$ (42,412)	$ 6,901
Less net income attributable to stockholders pre-IPO			0	0	(848)
Basic net income (loss) attributable to Brigham Minerals, Inc. stockholders post-IPO			$ 50,283	$ (42,412)	$ 6,053
Denominator:
Basic weighted average shares outstanding (in shares)			44,576	38,178	22,870
Basic EPS attributable to Brigham Minerals, Inc. stockholders (in dollars per share)			$ 1.13	$ (1.11)	$ 0.26
Numerator:
Diluted net income (loss) attributable to Brigham Minerals, Inc. stockholders			$ 50,283	$ (42,412)	$ 6,053
Denominator:
Basic weighted average shares outstanding (in shares)			44,576	38,178	22,870
Unvested equity awards (in shares)			1,056	0	0
Diluted weighted average shares outstanding (in shares)			45,632	38,178	22,870
Diluted EPS attributable to Brigham Minerals, Inc. stockholders (in dollars per share)			$ 1.10	$ (1.11)	$ 0.26

Temporary equity and Noncontrol

Temporary equity and Noncontrolling interest - Narrative (Details)	Apr. 17, 2019shares	Dec. 31, 2021voteshares	Dec. 31, 2020
Class B Common Stock
Temporary Equity [Line Items]
Number of votes per share (vote)		1
Conversion of stock, shares received (in shares) | shares	1
Class A Common Stock
Temporary Equity [Line Items]
Number of votes per share (vote)		1
Conversion of stock, shares received (in shares) | shares	1	1
Existing Owners of Brigham Minerals | Class B Common Stock
Temporary Equity [Line Items]
Number of votes per share (vote)		1
Brigham LLC
Temporary Equity [Line Items]
Sale of stock, ownership percentage		81.00%
Brigham LLC | Existing Owners of Brigham Minerals
Temporary Equity [Line Items]
Sale of stock, ownership percentage		19.00%
Brigham LLC | Existing Owners of Brigham Minerals | September Offering
Temporary Equity [Line Items]
Sale of stock, ownership percentage			23.20%

Temporary equity and Non-cont_3

Temporary equity and Non-controlling interest - Temporary Equity (Details) - USD ($) $ / shares in Units, $ in Thousands	Apr. 17, 2019	Feb. 18, 2021	Dec. 31, 2019	Dec. 30, 2019	Dec. 31, 2021	Dec. 31, 2021	Dec. 31, 2020
Increase (Decrease) in Temporary Equity [Roll Forward]
Beginning balance		$ 146,280				$ 146,280	$ 454,507
Conversion of Class B shares to Class A shares				$ (104,390)			(97,491)
Net loss attribution to temporary equity		1,922		9,646			(15,582)
Distribution to holders of temporary equity				(20,321)			(24,793)
Adjustment of temporary equity to redemption value	$ 194,500	54,294	$ 51,572	$ 51,572			(170,361)
Reclassification to non-controlling interest		(202,496)			$ (202,496)	$ (202,496)
Ending balance	$ 518,000	$ 0	$ 454,507				$ 146,280
Class B Common Stock
Increase (Decrease) in Temporary Equity [Roll Forward]
Temporary equity (in shares)	28,777,802	13,167,687	22,847,045				13,167,687
Temporary equity, share price (in dollars per share)		$ 15.38	$ 19.89				$ 11.11
Initial Public Offering | Common Class A
Increase (Decrease) in Temporary Equity [Roll Forward]
Share price (in dollars per share)	$ 18

Temporary equity and Noncontr_2

Temporary equity and Noncontrolling Interest - Schedule of Noncontrolling Interest (Details) - USD ($) $ / shares in Units, $ in Thousands	2 Months Ended	10 Months Ended	12 Months Ended
	Feb. 18, 2021	Dec. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Apr. 17, 2019
Stockholders' Equity Attributable to Noncontrolling Interest [Roll Forward]
Beginning balance	$ 0	$ 0	$ 0
Reclassification from temporary equity to non-controlling interest	$ 202,496	202,496	202,496
Conversion of shares of Class B Common Stock to Class A Common Stock		(27,239)
Net income attributable to non-controlling interest		15,821
Distribution to holders of non-controlling interest declared		(17,833)
Ending balance		$ 173,245	$ 173,245
Class B Common Stock
Stockholders' Equity Attributable to Noncontrolling Interest [Roll Forward]
Temporary equity (in shares)	13,167,687			13,167,687	22,847,045	28,777,802
Temporary equity, share price (in dollars per share)	$ 15.38			$ 11.11	$ 19.89

Share-Based Compensation - Narr

Share-Based Compensation - Narrative (Details) - USD ($) $ / shares in Units, $ in Thousands	Apr. 23, 2019	Apr. 17, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	May 08, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Amount withheld to satisfy employee tax withholding obligation			$ 1,136	$ 1,203	$ 0
Shares surrendered for tax withholdings on vested equity awards			$ 145	$ 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	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)			70,911
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		31,882
Shares withheld to satisfy employee tax withholding (in shares)			9,024
Shares forfeited (in shares)			5,978
RSAs | 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting percentage at grant (as a percent)			33.34%
RSAs | 2023
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting percentage at grant (as a percent)			33.34%
RSAs | Share-based Payment Arrangement, Tranche Three [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting percentage at grant (as a percent)			33.34%
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)			$ 16.31
Shares granted during period (in shares)			583,998
Shares vested during period (in shares)			578,577
Shares withheld to satisfy employee tax withholding (in shares)			181,182
Shares surrendered for tax withholdings on vested equity awards			$ 3,800
Shares forfeited (in shares)			14,316
Restricted stock units | 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting percentage at grant (as a percent)			33.34%
Restricted stock units | 2023
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting percentage at grant (as a percent)			33.34%
Restricted stock units | Share-based Payment Arrangement, Tranche Three [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting percentage at grant (as a percent)			33.34%
Restricted stock units | Employees
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period			3 years
Restricted stock units | Director
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period			1 year
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)			$ 17.02	$ 6.41	$ 12.18
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]
Award vesting percentage at grant (as a percent)			94.80%
Shares granted during period (in shares)	753,546		472,378	434,265
Shares vested during period (in shares)			714,350
Amount withheld to satisfy employee tax withholding obligation			$ 5,700
Shares withheld to satisfy employee tax withholding (in shares)			271,521
Shares forfeited (in shares)			39,196
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)			3,013,884

Share-Based Compensation - Summ

Share-Based Compensation - Summary of Stock Activity (Details) - $ / shares	Apr. 23, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Incentive Units
Number of Incentive Units
Beginning balance (in shares)		141,820
Vested (in shares)		(70,911)
Ending balance (in shares)		70,909	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	$ 10.04
RSAs
Number of Incentive Units
Beginning balance (in shares)		68,293
Granted (in shares)	312,189
Vested (in shares)	(152,742)	(31,882)
Forfeited (in shares)		(5,978)
Ending balance (in shares)		30,433	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	$ 21.25
Shares withheld to satisfy employee tax withholding (in shares)		9,024
RSUs
Number of Incentive Units
Beginning balance (in shares)		562,871
Granted (in shares)		583,998
Vested (in shares)		(578,577)
Forfeited (in shares)		(14,316)
Ending balance (in shares)		553,976	562,871
Grant-date Fair Value
Beginning balance (in dollars per share)		$ 17.81
Grant-date fair value, Granted (in dollars per share)		16.31
Grant-date fair value, Vested (in dollars per share)		17.48
Grant-date fair value, Forfeited (in dollars per share)		18.49
Ending balance (in dollars per share)		$ 16.55	$ 17.81
Shares withheld to satisfy employee tax withholding (in shares)		181,182
Target PSUs
Number of Incentive Units
Beginning balance (in shares)		1,187,811
Granted (in shares)	753,546	472,378	434,265
Vested (in shares)		(714,350)
Forfeited (in shares)		(39,196)
Ending balance (in shares)		906,643	1,187,811
Grant-date Fair Value
Shares withheld to satisfy employee tax withholding (in shares)		271,521
Performance-Based Restricted Stock Units
Grant-date Fair Value
Beginning balance (in dollars per share)		$ 10.07
Grant-date fair value, Granted (in dollars per share)		17.02	$ 6.41	$ 12.18
Grant-date fair value, Vested (in dollars per share)		12.18
Ending balance (in dollars per share)		$ 11.94	$ 10.07

Share-Based Compensation - Weig

Share-Based Compensation - Weighted Average Assumptions (Details) - Performance-Based Restricted Stock Units - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected dividend yield (as a percent)	6.00%	11.50%	8.10%
Risk-free interest rates	0.27%	1.40%	2.30%
Expected volatility (as a percent)	45.00%	35.00%	30.00%
Shares granted during period, grant date fair value (in dollars per share)	$ 17.02	$ 6.41	$ 12.18

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, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Capitalized share-based compensation		$ (8,048)	$ (6,086)	$ (3,818)
Total share-based compensation expense		9,703	7,529	10,049
Future share-based compensation expense		16,464
Unevaluated Oil and Gas Property
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Capitalized share-based compensation		(3,600)
Evaluated Oil and Gas Property
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Capitalized share-based compensation		(4,400)
2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		10,579
2023
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		5,885
Incentive Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense		$ 712	712	2,904
Compensation expense, cumulative effect adjustment at IPO				2,000
Shares vested during period (in shares)		70,911
Future share-based compensation expense		$ 534
Incentive Units | 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		534
Incentive Units | 2023
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		0
RSAs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 3,200	$ 623	1,254	3,972
Shares vested during period (in shares)	152,742	31,882
Future share-based compensation expense		$ 200
RSAs | 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		200
RSAs | 2023
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		0
RSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense		$ 10,128	7,390	4,630
Shares vested during period (in shares)		578,577
Future share-based compensation expense		$ 8,637
RSUs | 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		5,815
RSUs | 2023
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		2,822
PSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense		6,288	$ 4,259	$ 2,361
Future share-based compensation expense		7,093
PSUs | 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		4,030
PSUs | 2023
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Future share-based compensation expense		$ 3,063

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended			5 Months Ended	8 Months Ended	12 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Apr. 30, 2019	Sep. 30, 2019	Dec. 31, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Apr. 17, 2019	Jul. 31, 2018
Operating Loss Carryforwards [Line Items]
Net deferred tax liability resulting from corporate reorganization						$ 235	$ 112			$ 3,100
Deferred tax asset arising from issuance of stock				$ 13,700	$ 13,664
Deferred tax asset arising from issuance of common stock in the December 2019 Offering	$ (2,800)	$ (800)						$ 9,500
Effective income tax rate (as a percent)						19.00%
Income tax expense (benefit)						$ 16,253	(12,762)	$ 2,679
Deferred tax asset						$ 25,308	$ 24,920
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

Income Taxes - Schedule of Comp

Income Taxes - Schedule of Components of Income Tax Expense (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Current expense	$ 270	$ 122	$ 692
Deferred expense/(benefit)	2,182	(1,876)	63
Current expense/(benefit)	10,217	(2,942)	1,322
Deferred expense/(benefit)	3,584	(8,066)	602
Total income tax provision	16,253	(12,762)	2,679
Total current income tax expense/(benefit)	10,487	(2,820)	2,014
Total deferred income tax expense/(benefit)	$ 5,766	$ (9,942)	$ 665

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Income Tax Expense With Income Tax Provision (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Income (loss) before income taxes	$ 84,279	$ (70,756)	$ 24,318
Less: income before income taxes attributable to predecessor	0	0	5,118
Less: income (loss) before income taxes attributable to non-controlling interests and temporary equity	17,851	(15,270)	9,858
Income (loss) before income taxes attributable to stockholders	66,428	(55,486)	9,342
Income tax at the federal statutory rate	13,950	(11,652)	1,962
State income taxes, net of federal benefit	540	(1,223)	717
State rate change	1,397	0	0
Other federal tax effects	366	113	0
Total income tax provision	$ 16,253	$ (12,762)	$ 2,679

Income Taxes - Schedule of Defe

Income Taxes - Schedule of Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020	Jul. 31, 2018
Deferred tax assets:
Loss carryforwards	$ 441	$ 627
Investment in subsidiary	25,102	24,405
Total deferred tax assets:	25,543	25,032
Deferred tax liabilities:
Oil and gas properties	(235)	(112)
Total deferred tax liabilities	$ (235)	$ (112)	$ (3,100)

Related Party Transactions (Det

Related Party Transactions (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)
Leasing of Acreage Arrangement | Ben M. Brigham
Related Party Transaction [Line Items]
Amount received from related party	$ 0.4

Subsequent Events (Details)

Subsequent Events (Details) $ / shares in Units, $ in Millions	Feb. 18, 2022$ / shares	Feb. 10, 2021USD ($)ashares
Midland Basin
Subsequent Event [Line Items]
Acquisition of land | a		1,800
Cash consideration | $		$ 15
Common Class A | Midland Basin
Subsequent Event [Line Items]
Shares transferred during acquisition (in shares) | shares		800,000
Common Class A | Subsequent Event
Subsequent Event [Line Items]
Dividends declared (in dollars per share) | $ / shares	$ 0.45

Reserve and Related Financial_3

Reserve and Related Financial Data (SMOG) - Unaudited - Schedule of Proved Reserve Quantities (Details) MMcf in Thousands, MMBoe in Thousands, MBoe in Thousands, MBbls in Thousands	12 Months Ended
	Dec. 31, 2021MBoeMMBoeMMcfMBbls	Dec. 31, 2020MBoeMBblsMMcf	Dec. 31, 2019MBoeMMcfMBbls
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Beginning balance | MBoe	25,063	33,088	26,741
Sales of minerals-in-place | MBoe	(275)	(48)	(409)
Extensions and discoveries | MBoe	3,024	1,591	4,110
Acquisitions | MBoe	6,849	2,174	7,651
Revisions of previous estimates | MBoe	(4,444)	8,271	(2,299)
Production | MBoe	(3,300)	(3,471)	(2,706)
Ending balance | MBoe	35,805	25,063	33,088
Proved reserve quantities at December 31, 2021 attributable to non-controlling interest | MBoe	6,803
Proved developed reserve quantities | MBoe	28,911	18,141	17,957
Proved developed reserves at December 31, 2021 attributable to temporary equity | MMBoe	5,493
Proved undeveloped reserve quantities | MBoe	6,894	6,922	15,131
Proved undeveloped reserves at December 31, 2021 attributable to temporary equity | MMBoe	1,310
Oil sales
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning balance	13,200	16,961	12,991
Sales of minerals-in-place	(71)	0	(182)
Extensions and discoveries	1,666	876	1,997
Acquisitions	2,739	1,235	4,256
Revisions of previous estimates	1,053	(4,049)	(586)
Production	(1,677)	(1,823)	(1,515)
Ending balance	16,910	13,200	16,961
Proved reserve quantities at December 31, 2021 attributable to non-controlling interest	3,213
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Proved developed reserve quantities	13,148	9,403	9,924
Proved developed reserves at December 31, 2021 attributable to temporary equity	2,498
Proved undeveloped reserve quantities	3,762	3,797	7,037
Proved undeveloped reserves at December 31, 2021 attributable to temporary equity	715
Natural Gas (MMcf)
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning balance | MMcf	43,644	61,730	51,796
Sales of minerals-in-place | MMcf	(780)	(286)	(697)
Extensions and discoveries | MMcf	4,404	2,545	7,780
Acquisitions | MMcf	14,683	3,652	13,053
Revisions of previous estimates | MMcf	10,107	(18,188)	(5,495)
Production | MMcf	(5,886)	(5,809)	(4,707)
Ending balance | MMcf	66,172	43,644	61,730
Proved reserve quantities at December 31, 2021 attributable to non-controlling interest | MMcf	12,573
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Proved developed reserve quantities | MMcf	56,372	31,873	33,232
Proved developed reserves at December 31, 2021 attributable to temporary equity | MMcf	10,711
Proved undeveloped reserve quantities | MMcf	9,800	11,771	28,498
Proved undeveloped reserves at December 31, 2021 attributable to temporary equity | MMcf	1,862
NGL sales
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning balance	4,590	5,838	5,117
Sales of minerals-in-place	(73)	(1)	(110)
Extensions and discoveries	623	291	817
Acquisitions	1,662	331	1,218
Revisions of previous estimates	1,706	(1,189)	(797)
Production	(642)	(680)	(407)
Ending balance	7,866	4,590	5,838
Proved reserve quantities at December 31, 2021 attributable to non-controlling interest	1,495
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Proved developed reserve quantities	6,367	3,426	2,494
Proved developed reserves at December 31, 2021 attributable to temporary equity	1,210
Proved undeveloped reserve quantities	1,499	1,164	3,344
Proved undeveloped reserves at December 31, 2021 attributable to temporary equity	285

Reserve and Related Financial_4

Reserve and Related Financial Data (SMOG) - Unaudited - Narrative (Details)	12 Months Ended
	Dec. 31, 2021MMBoeMBoe	Dec. 31, 2020MBoewell	Dec. 31, 2019MBoewell
Reserve Quantities [Line Items]
Extensions and discoveries	3,024,000	1,591,000	4,110,000
Number of well locations | well		342	900
Revisions of previous estimates	(4,444,000)	8,271,000	(2,299,000)
Acquisitions	6,849,000	2,174,000	7,651,000
Divestiture through sale of mineral and royalty interests	275,000	48,000	409,000
Permian, DJ, Anadarko and Williston Basins
Reserve Quantities [Line Items]
Additional proved reserves	6,849,000		7,242,000
Acquisitions		2,174,000	7,651,000
Divestiture through sale of mineral and royalty interests	275,000	48,000	409,000
Revisions To Pricing
Reserve Quantities [Line Items]
Revisions of previous estimates	3,591,000	(2,645,000)	(902,000)
Revisions Attributable to Operator Development Timing
Reserve Quantities [Line Items]
Revisions of previous estimates		(7,036,000)	(1,397,000)
Proved Developed and Undeveloped Reserve, Conversion of Reserves
Reserve Quantities [Line Items]
Extensions and discoveries	3,024,000	1,591,000
Proved Reserves, Revisions Attributable to Production
Reserve Quantities [Line Items]
Revisions of previous estimates	852,000	(1,410,000)
Minimum
Reserve Quantities [Line Items]
Average sales price, percent	29.00%
Maximum
Reserve Quantities [Line Items]
Average sales price, percent	41.00%

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, 2021USD ($)$ / MMBTU$ / bbl	Dec. 31, 2020USD ($)$ / bbl$ / MMBTU	Dec. 31, 2019USD ($)$ / bbl$ / MMBTU	Dec. 31, 2018USD ($)
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future crude oil, natural gas, and NGL sales	$ 1,512,784	$ 562,545	$ 1,042,118
Future severance tax and ad valorem taxes	(109,849)	(39,318)	(73,627)
Future income tax expense	(214,311)	(46,908)	(143,599)
Future net cash flows	1,188,624	476,319	824,892
10% annual discount	(549,768)	(205,551)	(359,258)
Standardized measure of discounted future net cash flows	638,856	270,768	465,634	$ 443,459
Standardized measure of discounted future net cash flows attributable to temporary equity	$ 121,383	$ 62,853	$ 186,999
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	64.46	36.35	51.01
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	3.22	1.03	1.51
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	26.65	8.19	14.39

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, 2021	Dec. 31, 2020	Dec. 31, 2019
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	$ 270,768	$ 465,634	$ 443,459
Sales, less production costs	(140,561)	(73,654)	(86,492)
Revisions of previous quantity estimates	106,664	(135,926)	(41,539)
Extensions, discoveries, and other additions	74,305	21,011	69,057
Net change in prices and production costs	268,687	(131,886)	(99,660)
Accretion of discount	23,763	54,741	51,949
Purchase of reserves in place	151,547	27,241	137,819
Divestitures of reserves in place	(2,375)	(250)	(5,783)
Net change in taxes	(87,960)	53,786	(5,739)
Timing differences and other	(25,982)	(9,929)	2,563
Standardized measure of discounted future net cash flows, end of the year	$ 638,856	$ 270,768	$ 465,634

Reserve and Related Financial_7

Reserve and Related Financial Data (SMOG) - Unaudited - Capitalized Costs (Details) - USD ($) $ in Thousands	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Extractive Industries [Abstract]
Unevaluated property	$ 338,613	$ 325,091	$ 291,664
Evaluated property	633,138	488,301	449,061
Total oil and gas properties, at cost	971,751	813,392	740,725
Less accumulated depreciation, depletion, and amortization	(239,612)	(189,546)	(61,103)
Total oil and gas properties, net	$ 732,139	$ 623,846	$ 679,622

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, 2021	Dec. 31, 2020	Dec. 31, 2019
Extractive Industries [Abstract]
Unevaluated	$ 51,934	$ 35,725	$ 78,093
Evaluated	98,377	30,856	140,025
Total	$ 150,311	$ 66,581	$ 218,118