Reserve and Related Financial Data (SMOG) - Unaudited (Tables)

12 Months Ended

Dec. 31, 2019

Extractive Industries [Abstract]

Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities

The reserves at December 31, 2019 and December 31, 2018 presented below were audited by CG&A and the reserves at December 31, 2017 presented below were prepared 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, Montana and Pennsylvania. All of the proved reserves are located in the continental United States.

	Crude Oil (MBbl)		Natural Gas (Mmcf)		NGL (MBbl)		Total (MBoe)
Proved reserve quantities, December 31, 2016	7,174		22,991		2,356		13,363
Sales of minerals-in-place	(1,291	)	(815	)	(200	)	(1,627	)
Extensions and discoveries	1,548		6,012		709		3,259
Acquisitions	2,141		9,380		1,116		4,820
Revisions of previous estimates	(394	)	2,601		108		147
Production	(454	)	(1,768	)	(109	)	(858	)
Proved reserve quantities, December 31, 2017	8,724		38,401		3,980		19,104
Sales of minerals-in-place	—		—		—		—
Extensions and discoveries	1,765		5,285		562		3,208
Acquisitions	3,669		13,862		1,374		7,354
Revisions of previous estimates	(390	)	(3,245	)	(577	)	(1,508	)
Production	(777	)	(2,507	)	(222	)	(1,417	)
Proved reserve quantities, December 31, 2018	12,991		51,796		5,117		26,741
Sales of minerals-in-place	(182	)	(697	)	(110	)	(409	)
Extensions and discoveries	1,997		7,780		817		4,110
Acquisitions	4,256		13,053		1,218		7,651
Revisions of previous estimates	(586	)	(5,495	)	(797	)	(2,299	)
Production	(1,515	)	(4,707	)	(407	)	(2,706	)
Proved reserve quantities, December 31, 2019	16,961		61,730		5,838		33,088
Proved reserve quantities at December 31, 2019 attributable to temporary equity	6,812		24,792		2,345		13,289
Proved developed reserve quantities:
December 31, 2017	2,804		13,028		1,185		6,160
December 31, 2018	6,067		21,735		1,898		11,588
December 31, 2019	9,924		33,232		2,494		17,957
Proved developed reserves at December 31, 2019 attributable to temporary equity	3,986		13,346		1,002		7,212
Proved undeveloped reserve quantities:
December 31, 2017	5,920		25,373		2,795		12,944
December 31, 2018	6,924		30,061		3,219		15,153
December 31, 2019	7,037		28,498		3,344		15,131
Proved undeveloped reserves at December 31, 2019 attributable to temporary equity	2,826		11,445		1,343		6,077

Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure

The following summary sets forth the future net cash flows relating to proved oil and gas reserves based on

the standardized measure prescribed in ASC Topic 932:

	For the Year Ended December 31,
(In thousands)	2019			2018			2017
Future crude oil, natural gas, and NGL sales	$	1,042,118		$	1,049,141		$	595,874
Future severance tax and ad valorem taxes	(73,627		)	(70,248		)	(40,225		)
Future income tax expense	(143,599		)	(144,421		)	(1,151		)
Future net cash flows	824,892			834,472			554,498
10% annual discount	(359,258		)	(391,013		)	(238,030		)
Standardized measure of discounted future net cash flows	$	465,634		$	443,459		$	316,468
Standardized measure of discounted future net cash flows attributable to temporary equity	$	186,999		$	—		$	—

Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure

The following prices were used in the determination of standardized measure:

	For the Year Ended December 31,
	2019		2018		2017
Oil (per Bbl)	$	51.01	$	61.31	$	47.80
Natural gas (per Mcf)	1.51		2.51		2.74
NGLs (per Bbl)	14.39		23.98		18.56

Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows

The principal sources of change in the standardized measure of discounted future net cash flows are:

	For the Year Ended December 31,
(In thousands)	2019			2018			2017
Standardized measure of discounted future net cash flows, beginning of the year	$	443,459		$	316,468		$	185,752
Changes in the year resulting from:
Sales, less production costs	(86,492		)	(52,278		)	(26,711		)
Revisions of previous quantity estimates	(41,539		)	(22,942		)	4,894
Extensions, discoveries, and other additions	69,057			71,668			56,511
Net change in prices and production costs	(99,660		)	71,770			30,565
Accretion of discount	51,949			31,713			18,612
Purchase of reserves in place	137,819			148,580			79,190
Divestitures of reserves in place	(5,783		)	—			(26,742		)
Net change in taxes	(5,739		)	(75,369		)	(298		)
Timing differences and other	2,563			(46,151		)	(5,305		)
Standardized measure of discounted future net cash flows, end of the year	$	465,634		$	443,459		$	316,468

Schedule of Capitalized Oil and Natural Gas Costs

Costs associated with general corporate activities are expensed in the period incurred. Oil and gas properties consisted of the following:

	December 31,
(In thousands)	2019			2018
Oil and gas properties, at cost, using the full cost method of accounting:
Not subject to depletion	$	291,664		$	228,151
Subject to depletion	449,061			289,851
Total oil and gas properties, at cost	740,725			518,002
Less accumulated depreciation, depletion, and amortization	(61,103		)	(27,628		)
Total oil and gas properties, net	$	679,622		$	490,374

Costs not subject to depletion are as follows, by the year in which such costs were incurred:

By Year:	Total		2019		2018		2017		2016		Prior
(In thousands)
Property Acquisition costs	$	291,664	$	80,964	$	73,002	$	66,139	$	10,745	$	60,814

The aggregate amounts of costs capitalized for oil and natural gas producing activities and related aggregate amounts of accumulated depletion follow:

	For the Year Ended December 31,
(In thousands)	2019			2018			2017
Oil and gas properties, at cost, using full cost method of accounting:
Not subject to depletion	$	291,664		$	228,151		$	168,691
Subject to depletion	449,061			289,851			152,354
Total oil and gas properties, at cost	740,725			518,002			321,045
Less accumulated depreciation, depletion, and amortization	(61,103		)	(27,628		)	(14,210		)
Total oil and gas properties, net	$	679,622		$	490,374		$	306,835

Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure

During the years ended December 31, 2019 and 2018, Brigham Minerals entered into a number of individually insignificant acquisitions of mineral and royalty interests from various sellers in Texas, Oklahoma, Colorado, New Mexico, and North Dakota, as reflected in the table below. The change in the oil and natural gas property balance is comprised of payments for acquisitions of minerals, land brokerage costs and capitalized general and administrative expenses that were funded with borrowings under its Owl Rock credit facility, our revolving credit facility and proceeds from the IPO.

	Assets Acquired				Cash Consideration Paid
(In thousands)	Evaluated		Unevaluated
Twelve months ended December 31, 2019	$	140,025	$	78,093	$	218,118
Twelve months ended December 31, 2018	$	115,589	$	81,367	$	196,956

The following costs were incurred in oil and natural gas producing activities:

	For the Year Ended December 31,
(In thousands)	2019		2018		2017
Acquisition of properties
Unevaluated	$	78,093	$	59,460	$	50,224
Evaluated	140,025		137,496		51,862
Total	$	218,118	$	196,956	$	102,086