Supplemental Oil and Gas Disclosures (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2017

Oil and Gas In Process Activities [Line Items]

Summary of Estimated Quantities of Proved Developed Oil and Natural Gas Reserves

Estimated quantities of proved oil and gas reserves are summarized as follows:

	Reserves
	Oil (a) (Barrels)		Gas (Mcf)
	(In thousands)
Consolidated entities:
Year-end 2014	7,672		12,649
Revisions of previous estimates	(855	)	(1,675	)
Extensions and discoveries	224		173
Acquisitions	—		—
Sales	(704	)	(1,223	)
Production	(1,158	)	(1,967	)
Year-end 2015	5,179		7,957
Revisions of previous estimates	(11	)	631
Extensions and discoveries	29		—
Acquisitions	—		—
Sales	(4,460	)	(3,756	)
Production	(291	)	(996	)
Year-end 2016	446		3,836
Revisions of previous estimates	—		—
Extensions and discoveries	—		—
Acquisitions	—		—
Sales	(446	)	(3,836	)
Production	—		—
Year-end 2017	—		—
Our share of ventures accounted for using the equity method:
Year-end 2014	—		1,751
Revisions of previous estimates	—		(320	)
Production	—		(168	)
Year-end 2015	—		1,263
Revisions of previous estimates	—		79
Production	—		(143	)
Year-end 2016	—		1,199
Sales	—		(1,199	)
Year-end 2017	—		—
Total consolidated and our share of equity method ventures:
Year-end 2015
Proved developed reserves	5,179		9,220
Proved undeveloped reserves	—		—
Total Year-end 2015	5,179		9,220
Year-end 2016
Proved developed reserves	446		5,035
Proved undeveloped reserves	—		—
Total Year-end 2016	446		5,035
Year-end 2017
Proved developed reserves	—		—
Proved undeveloped reserves	—		—
Total Year-end 2017	—		—

 _____________________

^(a)  Includes natural gas liquids (NGLs).

Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development Activities

Costs incurred in oil and gas property acquisition, exploration and development activities, whether capitalized or expensed, follows:

	For the Year
	2017		2016		2015
	(In thousands)
Consolidated entities:
Acquisition costs
Proved properties	$	—	$	—	$	—
Unproved properties	—		15		4,832
Exploration costs	—		21		17,922
Development costs	—		537		27,609
	$	—	$	573	$	50,363

Schedule of Development Wells Drilled

The following tables set forth the number of gross and net oil and gas wells in which we participated:

Gross Wells
		Exploratory			Development
Year	Total	Oil	Gas	Dry	Oil	Gas	Dry
2017	—	—	—	—	—	—	—
2016	—	—	—	—	—	—	—
2015 (a)	38	2	—	1	34	—	1

 _____________________

^(a)  Of the gross wells drilled in 2015, we operated 3 wells or 8 percent. The remaining wells represent our participations in wells operated by others. The exploratory dry hole was located in Oklahoma.

Net Wells
		Exploratory			Development
Year	Total	Oil	Gas	Dry	Oil	Gas	Dry
2017	—	—	—	—	—	—	—
2016	—	—	—	—	—	—	—
2015	6.3	0.7	—	0.8	4.3	—	0.5

Schedule of Exploratory Wells Drilled

The following tables set forth the number of gross and net oil and gas wells in which we participated:

Gross Wells
		Exploratory			Development
Year	Total	Oil	Gas	Dry	Oil	Gas	Dry
2017	—	—	—	—	—	—	—
2016	—	—	—	—	—	—	—
2015 (a)	38	2	—	1	34	—	1

 _____________________

^(a)  Of the gross wells drilled in 2015, we operated 3 wells or 8 percent. The remaining wells represent our participations in wells operated by others. The exploratory dry hole was located in Oklahoma.

Net Wells
		Exploratory			Development
Year	Total	Oil	Gas	Dry	Oil	Gas	Dry
2017	—	—	—	—	—	—	—
2016	—	—	—	—	—	—	—
2015	6.3	0.7	—	0.8	4.3	—	0.5

Estimates of Future Cash Flows from Proved Developed Oil and Natural Gas Reserves

Estimates of future cash flows from proved oil and gas reserves are shown in the following table. Estimated income taxes are calculated by applying the appropriate tax rates to the estimated future pre-tax net cash flows less depreciation of the tax basis of properties and the statutory depletion allowance.

	At Year-End
	2017		2016			2015
	(In thousands)
Consolidated entities:
Future cash inflows	$	—	$	24,304		$	216,588
Future production and development costs	—		(2,988		)	(93,623		)
Future income tax expenses	—		(3,926		)	(22,218		)
Future net cash flows	—		17,390			100,747
10% annual discount for estimated timing of cash flows	—		(7,077		)	(33,951		)
Standardized measure of discounted future net cash flows	$	—	$	10,313		$	66,796
Our share in ventures accounted for using the equity method:
Future cash inflows	$	—	$	2,010		$	2,283
Future production and development costs	—		(216		)	(245		)
Future income tax expenses	—		(537		)	(774		)
Future net cash flows	—		1,257			1,264
10% annual discount for estimated timing of cash flows	—		(585		)	(562		)
Standardized measure of discounted future net cash flows	$	—	$	672		$	702
Total consolidated and our share of equity method ventures	$	—	$	10,985		$	67,498

Changes in Standardized Measure of Discounted Future Net Cash Flow

Changes in the standardized measure of discounted future net cash flow follows:

	For the Year
	Consolidated			Our Share of Equity Method Ventures			Total
	(In thousands)
Year-end 2014	$	163,841		$	1,775		$	165,616
Changes resulting from:
Net change in sales prices and production costs	(136,536		)	(1,112		)	(137,648		)
Net change in future development costs	92			—			92
Sales of oil and gas, net of production costs	(31,732		)	(428		)	(32,160		)
Net change due to extensions and discoveries	11,747			—			11,747
Net change due to acquisition of reserves	—			—			—
Net change due to divestitures of reserves	(15,855		)	—			(15,855		)
Net change due to revisions of quantity estimates	(15,164		)	(267		)	(15,431		)
Previously estimated development costs incurred	15,096			—			15,096
Accretion of discount	22,600			286			22,886
Net change in timing and other	4,018			(210		)	3,808
Net change in income taxes	48,689			658			49,347
Aggregate change for the year	(97,045		)	(1,073		)	(98,118		)
Year-end 2015	66,796			702			67,498
Changes resulting from:
Net change in sales prices and production costs	(3,585		)	(60		)	(3,645		)
Net change in future development costs	—			—			—
Sales of oil and gas, net of production costs	(5,663		)	(208		)	(5,871		)
Net change due to extensions and discoveries	410			—			410
Net change due to acquisition of reserves	—			—			—
Net change due to divestitures of reserves	(63,535		)	—			(63,535		)
Net change due to revisions of quantity estimates	1,304			63			1,367
Previously estimated development costs incurred	—			—			—
Accretion of discount	2,992			113			3,105
Net change in timing and other	(128		)	(80		)	(208		)
Net change in income taxes	11,722			142			11,864
Aggregate change for the year	(56,483		)	(30		)	(56,513		)
Year-end 2016	10,313			672			10,985
Changes resulting from:
Net change in sales prices and production costs	—			—			—
Net change in future development costs	—			—			—
Sales of oil and gas, net of production costs	—			—			—
Net change due to extensions and discoveries	—			—			—
Net change due to acquisition of reserves	—			—			—
Net change due to divestitures of reserves	(10,313		)	(672		)	(10,985		)
Net change due to revisions of quantity estimates	—			—			—
Previously estimated development costs incurred	—			—			—
Accretion of discount	—			—			—
Net change in timing and other	—			—			—
Net change in income taxes	—			—			—
Aggregate change for the year	(10,313		)	(672		)	(10,985		)
Year-end 2017	$	—		$	—		$	—

Information About Results of Operations of Oil and Natural Gas Interests

Information about the results of operations of our oil and gas interests follows:

	For the Year
	2017			2016			2015
	(In thousands)
Consolidated entities
Revenues	$	1,399		$	10,111		$	51,553
Production costs	(209		)	(4,392		)	(19,820		)
Exploration costs	(34		)	(124		)	(11,864		)
Depreciation, depletion, amortization	—			(2,157		)	(28,774		)
Non-cash impairment of proved oil and gas properties and unproved leasehold interests	(224		)	(612		)	(164,831		)
Oil and gas administrative expenses	(1,197		)	(8,700		)	(11,700		)
Accretion expense	—			(56		)	(144		)
Income tax (expense) benefit	(7		)	(20		)	14,717
Results of operations	(272		)	(5,950		)	(170,863		)
Our share in ventures accounted for using the equity method:
Revenues	$	100		$	284		$	428
Production costs	(19		)	(76		)	(102		)
Oil and gas administrative expenses	(2		)	(35		)	(51		)
Income tax (expense) benefit	—			—			21
Results of operations	$	79		$	173		$	296
Total results of operations	$	(193	)	$	(5,777	)	$	(170,567	)

Consolidated Entities

Oil and Gas In Process Activities [Line Items]

Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure

Capitalized costs related to our oil and gas producing activities classified as assets held for sale at year-end 2016 are as follows:

	At Year-End
	2017		2016
	(In thousands)
Consolidated entities:
Unproved oil and gas properties	$	—	$	374
Proved oil and gas properties	—		5,159
Total costs	—		5,533
Less accumulated depreciation, depletion and amortization	—		(4,751		)
	$	—	$	782