Forestar (FOR) 10-K 3 Mar 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Feb. 27, 2017	Jun. 30, 2016
Entity Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Trading Symbol	FOR
Entity Registrant Name	FORESTAR GROUP INC.
Entity Central Index Key	1,406,587
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		41,694,432
Entity Public Float			$ 210

CONSOLIDATED BALANCE SHEET

CONSOLIDATED BALANCE SHEET - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
ASSETS
Cash and cash equivalents	$ 265,798	$ 96,442
Real estate, net	293,003	586,715
Assets of discontinued operations	14	104,967
Assets held for sale	30,377	0
Investment in unconsolidated ventures	77,611	82,453
Timber	0	7,683
Receivables, net	8,931	19,025
Income taxes receivable	10,867	12,056
Prepaid expenses	2,000	3,116
Property and equipment, net	3,116	10,732
Deferred tax asset, net	323	0
Goodwill and other intangible assets	37,900	43,455
Other assets	3,268	5,602
TOTAL ASSETS	733,208	972,246
LIABILITIES AND EQUITY
Accounts payable	4,804	11,617
Accrued employee compensation and benefits	4,126	5,547
Accrued property taxes	2,008	4,529
Accrued interest	1,585	3,267
Deferred tax liability, net	0	1,037
Earnest money deposits	10,511	10,214
Other accrued expenses	12,598	14,556
Liabilities of discontinued operations	5,295	11,192
Liabilities held for sale	103	0
Other liabilities	19,702	24,657
Debt, net	110,358	381,515
TOTAL LIABILITIES	171,090	468,131
COMMITMENTS AND CONTINGENCIES
Forestar Group Inc. shareholders’ equity:
Common stock, par value $1.00 per share, 200,000,000 authorized shares, 44,803,603 issued at December 31, 2016 and 36,946,603 issued at December 31, 2015	44,804	36,947
Additional paid-in capital	553,005	561,850
Retained earnings (Accumulated deficit)	12,602	(46,046)
Treasury stock, at cost, 3,187,253 shares at December 31, 2016 and 3,203,768 shares at December 31, 2015	(49,760)	(51,151)
Total Forestar Group Inc. shareholders’ equity	560,651	501,600
Noncontrolling interests	1,467	2,515
TOTAL EQUITY	562,118	504,115
TOTAL LIABILITIES AND EQUITY	$ 733,208	$ 972,246

CONSOLIDATED BALANCE SHEET (Par

CONSOLIDATED BALANCE SHEET (Parenthetical) - $ / shares	Dec. 31, 2016	Dec. 31, 2015
Statement of Financial Position [Abstract]
Common stock, par value	$ 1	$ 1
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares issued	44,803,603	36,946,603
Treasury stock, common shares	3,187,253	3,203,768

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME (LOSS) AND COMPREHENSIVE INCOME (LOSS) - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
REVENUES
Real estate sales and other	$ 176,535	$ 120,022	$ 171,672
Commercial and income producing properties	13,738	82,808	41,440
Real estate	190,273	202,830	213,112
Mineral resources	5,076	9,094	15,690
Other	1,965	6,652	9,362
Total revenues	197,314	218,576	238,164
COST AND EXPENSES
Cost of real estate sales and other	(147,653)	(52,640)	(86,432)
Cost of commercial and income producing properties	(15,442)	(61,251)	(37,332)
Cost of mineral resources	(763)	(2,998)	(3,790)
Cost of other	(5,075)	(3,081)	(3,006)
Other operating	(33,177)	(48,996)	(44,326)
General and administrative	(21,597)	(27,253)	(22,230)
Total expenses	(223,707)	(196,219)	(197,116)
GAIN ON SALE OF ASSETS	166,747	1,585	29,512
OPERATING INCOME	140,354	23,942	70,560
Equity in earnings of unconsolidated ventures	6,123	16,008	8,685
Interest expense	(19,985)	(34,066)	(30,286)
Loss on extinguishment of debt, net	(35,864)	0	0
Other non-operating income	1,718	3,006	8,588
INCOME FROM CONTINUING OPERATIONS BEFORE TAXES	92,346	8,890	57,547
Income tax expense	(15,302)	(35,131)	(20,850)
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	77,044	(26,241)	36,697
LOSS FROM DISCONTINUED OPERATIONS, NET OF TAXES	(16,865)	(186,130)	(19,609)
Net income	60,179	(212,371)	17,088
Less: Net (income) attributable to noncontrolling interests	(1,531)	(676)	(505)
NET INCOME (LOSS) ATTRIBUTABLE TO FORESTAR GROUP INC.	$ 58,648	$ (213,047)	$ 16,583
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING
Basic (shares)	34,546	34,266	35,317
Diluted (shares)	42,334	34,266	43,596
NET INCOME (LOSS) PER BASIC SHARE
Continuing operations, basic (usd per share)	$ 1.80	$ (0.79)	$ 0.84
Discontinued operations, basic (usd per share)	(0.40)	(5.43)	(0.46)
Basic (usd per share)	1.40	(6.22)	0.38
NET INCOME (LOSS) PER DILUTED SHARE
Continuing operations, diluted (usd per share)	1.78	(0.79)	0.83
Discontinued operations, diluted (usd per share)	(0.40)	(5.43)	(0.45)
Diluted (usd per share)	$ 1.38	$ (6.22)	$ 0.38
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO FORESTAR GROUP INC.	$ 58,648	$ (213,047)	$ 16,583

CONSOLIDATED STATEMENTS OF EQUI

CONSOLIDATED STATEMENTS OF EQUITY - USD ($) $ in Thousands	Total	Common Stock	Additional Paid-in Capital	Treasury Stock	Retained Earnings	Noncontrolling Interest	Stock Options	Former Affiliated EntityAdditional Paid-in Capital	Former Affiliated EntityTreasury Stock	Former Affiliated EntityStock Options
Beginning Balances at Dec. 31, 2013	$ 715,397	$ 36,947	$ 556,676	$ (34,196)	$ 150,418	$ 5,552
Beginning Balances, Shares at Dec. 31, 2013		36,946,603		(2,199,666)
Net income	17,088				16,583	505
Distributions to noncontrolling interest	(4,171)					(4,171)
Contributions from noncontrolling interest	2,585					2,585
Dissolution of noncontrolling interests	1,342					1,342
Purchase of noncontrolling interests, net	(6,242)		(2,969)			(3,273)
Issuances of common stock, Shares				164,914
Issuances of common stock, Value	(2,567)			$ 2,567
Issuances from exercises of stock options, net of swaps, shares				45,062					60,823
Issuances from exercises of stock options, net of swaps, Value	329		(333)	$ 662				$ (43)	$ 920	$ 877
Shares withheld for payroll taxes, Shares				(55,238)
Shares withheld for payroll taxes, Value	$ (1,043)		(4)	$ (1,039)
Shares repurchased, Shares	(1,491,187)			(1,491,187)
Shares repurchased, Value	$ (24,595)			$ (24,595)
Forfeitures of restricted stock, Shares				(9,986)
Forfeitures of restricted stock, Value	0		10	$ (10)
Share-based compensation	8,033		8,033
Tax benefit from exercise of restricted stock units and stock options and vested restricted stock	142		142
Ending Balances at Dec. 31, 2014	709,742	$ 36,947	558,945	$ (55,691)	167,001	2,540
Ending Balances, Shares at Dec. 31, 2014		36,946,603		(3,485,278)
Net income	(212,371)				(213,047)	676
Distributions to noncontrolling interest	(701)					(701)
Issuances of common stock, Shares				335,611
Issuances of common stock, Value	$ 0		(5,362)	$ 5,362
Issuances from exercises of stock options, net of swaps, shares									3,999
Issuances from exercises of stock options, net of swaps, Value								$ (33)	$ 64	$ 31
Shares withheld for payroll taxes, Shares	(51,521)			(51,521)
Shares withheld for payroll taxes, Value	$ (762)		(1)	$ (761)
Forfeitures of restricted stock, Shares				(6,579)
Forfeitures of restricted stock, Value	0		125	$ (125)
Share-based compensation	8,576		8,576
Tax benefit from exercise of restricted stock units and stock options and vested restricted stock	(400)		(400)
Ending Balances at Dec. 31, 2015	504,115	$ 36,947	561,850	$ (51,151)	(46,046)	2,515
Ending Balances, Shares at Dec. 31, 2015		36,946,603		(3,203,768)
Net income	60,179				58,648	1,531
Distributions to noncontrolling interest	(2,579)					(2,579)
Issuances of common stock, Shares				288,397
Issuances of common stock, Value	0		(4,570)	$ 4,570
Issuances from exercises of stock options, net of swaps, shares				35,406			35,000
Issuances from exercises of stock options, net of swaps, Value	$ 328		(224)	$ 552
Shares withheld for payroll taxes, Shares	(25,082)			(23,312)
Shares withheld for payroll taxes, Value	$ (222)		(28)	$ (194)
Shares repurchased, Shares	(283,976)			(283,976)
Shares repurchased, Value	$ (3,537)			$ (3,537)
Share-based compensation	4,045		4,045
Settlement of tangible equity units, Shares		7,857,000
Settlement of tangible equity units, Value		$ 7,857	(7,857)
Reacquisition of equity component related to convertible debt	(211)		(211)
Ending Balances at Dec. 31, 2016	$ 562,118	$ 44,804	$ 553,005	$ (49,760)	$ 12,602	$ 1,467
Ending Balances, Shares at Dec. 31, 2016		44,803,603		(3,187,253)

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
CASH FLOWS FROM OPERATING ACTIVITIES:
Consolidated net income (loss)	$ 60,179	$ (212,371)	$ 17,088
Adjustments:
Depreciation, depletion and amortization	11,447	45,085	41,715
Change in deferred income taxes	(1,360)	41,261	1,645
Equity in earnings of unconsolidated ventures	(6,123)	(16,008)	(8,685)
Distributions of earnings of unconsolidated ventures	7,719	12,741	5,721
Share-based compensation	4,037	4,246	3,417
Real estate cost of sales	98,412	87,733	84,665
Dry hole and unproved leasehold impairment costs	0	67,639	29,528
Real estate development and acquisition expenditures, net	(81,179)	(107,988)	(114,694)
Reimbursements from utility and improvement districts	27,107	15,176	66,047
Asset impairments	60,939	108,184	15,934
Loss on debt extinguishment, net	35,864	0	0
Gain on sale of assets	(153,083)	(879)	(38,038)
Other	5,359	4,680	5,887
Changes in:
Notes and accounts receivables	13,214	(978)	10,704
Prepaid expenses and other	(133)	3,026	2,180
Accounts payable and other accrued liabilities	(16,711)	(11,868)	(4,653)
Income taxes	1,189	(4,553)	(11,379)
Net cash provided by operating activities	66,877	35,126	107,082
CASH FLOWS FROM INVESTING ACTIVITIES:
Property, equipment, software, reforestation and other	(6,138)	(14,690)	(16,398)
Oil and gas properties and equipment	(579)	(49,717)	(101,145)
Acquisition of partner's interest in unconsolidated multifamily venture, net of cash	0	0	(20,155)
Acquisition of oil and gas properties	0	0	(1,100)
Investment in unconsolidated ventures	(6,089)	(26,349)	(14,692)
Proceeds from sale of assets	427,849	18,260	21,962
Return of investment in unconsolidated ventures	5,700	12,168	1,797
Net cash provided by (used for) investing activities	420,743	(60,328)	(129,731)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from issuance of senior secured notes, net	0	0	241,947
Payments of debt	(315,229)	(58,220)	(225,481)
Additions to debt	3,184	11,463	22,593
Deferred financing fees	0	(295)	(3,217)
Distributions to noncontrolling interests, net	(2,579)	(701)	(3,146)
Purchase of noncontrolling interests	0	0	(7,971)
Repurchases of common stock	(3,537)	0	(24,595)
Other	(103)	(730)	339
Net cash (used for) provided by financing activities	(318,264)	(48,483)	469
Net increase (decrease) in cash and cash equivalents	169,356	(73,685)	(22,180)
Cash and cash equivalents at beginning of year	96,442	170,127	192,307
Cash and cash equivalents at year-end	265,798	96,442	170,127
Cash paid during the year for:
Interest	14,790	27,330	22,936
Income taxes paid (refunds)	10,205	(4,077)	18,322
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION:
Capitalized interest	2,838	2,938	1,154
Noncontrolling interests	$ 0	$ 0	$ 2,904

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Basis of Presentation Our consolidated financial statements include the accounts of Forestar Group Inc., all subsidiaries, ventures and other entities in which we have a controlling interest. We account for our investment in other entities in which we have significant influence over operations and financial policies using the equity method (we recognize our share of the entities’ income or loss and any preferential returns and treat distributions as a reduction of our investment). We eliminate all material intercompany accounts and transactions. Noncontrolling interests in consolidated pass-through entities are recognized before income taxes. We prepare our financial statements in accordance with generally accepted accounting principles in the United States, which require us to make estimates and assumptions about future events. Actual results can, and probably will, differ from those we currently estimate. Examples of significant estimates include those related to allocating costs to real estate, measuring long-lived assets for impairment, oil and gas revenue accruals, capital expenditure and lease operating expense accruals associated with our oil and gas production activities, oil and gas reserves and depletion of our oil and gas properties. At year-end 2016, we have divested substantially all of our oil and gas working interest properties. As a result of this significant change in our operations, we have reported the results of operations and financial position of these assets as discontinued operations within the consolidated statements of income (loss) and comprehensive income (loss) and consolidated balance sheets for all periods presented. In addition, in second quarter 2016, we changed the name of the oil and gas segment to mineral resources to reflect the strategic shift from oil and gas working interest investments to owned mineral interests. We also changed the name of the other natural resources segment to other. Cash and Cash Equivalents Cash and cash equivalents include cash and other short-term instruments with original maturities of three months or less. At year-end 2016 and 2015 , restricted cash was $275,000 and $200,000 and is included in other assets. Cash Flows The consolidated statements of cash flows for 2016, 2015 and 2014 reflect cash flows from both continuing and discontinued operations. Expenditures for the acquisition and development of single-family and multifamily real estate that we intend to develop for sale are classified as operating activities. Expenditures for the acquisition and development of properties to be held and operated, investment in oil and gas properties and equipment, and business acquisitions are classified as investing activities. Our accrued capital expenditures for unproved leasehold acquisitions and drilling and completion costs at year-end 2016 and 2015 were $834,000 and $7,033,000 and are included in liabilities of discontinued operations in our consolidated balance sheets. These oil and gas property additions will be reflected as cash used for investing activities in the period the accrued payables are settled. Capitalized Software We capitalize purchased software costs as well as the direct internal and external costs associated with software we develop for our own use. We amortize these capitalized costs using the straight-line method over estimated useful lives generally ranging from three to five years . The carrying value of capitalized software was $52,000 at year-end 2016 and $237,000 at year-end 2015 and is included in other assets. The amortization of these capitalized costs was $155,000 in 2016 , $996,000 in 2015 and $1,067,000 in 2014 and is included in general and administrative and operating expenses. Environmental and Asset Retirement Obligations We recognize environmental remediation liabilities on an undiscounted basis when environmental assessments or remediation are probable and we can reasonably estimate the cost. We adjust these liabilities as further information is obtained or circumstances change. Our asset retirement obligations are related to the abandonment and site restoration requirements that result from the acquisition, construction and development of oil and gas working interest properties, which we have divested substantially all at year-end 2016. We record the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. Accretion expense related to the asset retirement obligation and depletion expense related to capitalized asset retirement costs are included in cost of mineral resources and in discontinued operations on our consolidated statements of income (loss) and comprehensive income (loss). Our asset retirement obligations are recorded in liabilities held for sale at year-end 2016 and in other liabilities and liabilities of discontinued operations at year-end 2015. The following summarizes the changes in asset retirement obligations: Year-End 2016 2015 (In thousands) Beginning balance $ 1,758 $ 1,807 Additions 6 65 Oil and gas working interest property dispositions (1,610 ) (119 ) Liabilities settled (107 ) (139 ) Accretion expense 56 144 $ 103 $ 1,758 Fair Value Measurements Financial instruments for which we did not elect the fair value option include cash and cash equivalents, accounts and notes receivables, other assets, long-term debt, accounts payable and other liabilities. With the exception of long-term notes receivable and debt, the carrying amounts of these financial instruments approximate their fair values due to their short-term nature or variable interest rates. Goodwill and Other Intangible Assets We record goodwill when the purchase price of a business acquisition exceeds the estimated fair value of net identified tangible and intangible assets acquired. We do not amortize goodwill or other indefinite lived intangible assets. Instead, we measure these assets for impairment based on the estimated fair values at least annually or more frequently if impairment indicators exist. We perform the annual impairment measurement in the fourth quarter of each year. Intangible assets with finite useful lives are amortized over their estimated useful lives. In 2016 , we performed our annual goodwill impairment evaluation and concluded that goodwill related to our mineral interest assets was not impaired at year-end 2016 as the estimated fair value exceeded the carrying value. On February 17, 2017, we sold substantially all of the Company's remaining oil and gas assets for $85,600,000 . Please read Note 21—Subsequent Events for additional information about these items. In addition, we performed our annual goodwill impairment evaluation and concluded that goodwill related to our central Texas water assets was impaired at year-end 2016 as the estimated fair value exceeded the carrying value. We recorded a $3,874,000 non-cash impairment charge as a result of entering into an agreement to sell these assets. At year-end 2016, our central Texas water assets are classified as held for sale. Income Taxes We provide deferred income taxes using current tax rates for temporary differences between the financial accounting carrying value of assets and liabilities and their tax accounting carrying values. We recognize and value income tax exposures for the various taxing jurisdictions where we operate based on laws, elections, commonly accepted tax positions, and management estimates. We include tax penalties and interest in income tax expense. We provide a valuation allowance for any deferred tax asset that is not likely to be recoverable in future periods. When we believe a tax position is supportable but the outcome uncertain, we include the item in our tax return but do not recognize the related benefit in our provision for taxes. Instead, we record a reserve for unrecognized tax benefits, which represents our expectation of the most likely outcome considering the technical merits and specific facts of the position. Changes to liabilities are only made when an event occurs that changes the most likely outcome, such as settlement with the relevant tax authority, expiration of statutes of limitations, changes in tax law, or recent court rulings. Owned Mineral Interests When we lease our mineral interests to third-party exploration and production entities, we retain a royalty interest and may take an additional participation in production, including a working interest. At year-end 2016, mineral interests and any remaining oil and gas working interests are included in assets held for sale. Oil and Gas Properties (Discontinued Operations) We use the successful efforts method of accounting for our oil and gas producing activities. Costs to acquire mineral interests leased, costs to drill and complete development of oil and gas wells and related asset retirement costs are capitalized. Costs to drill exploratory wells are capitalized pending determination of whether the wells have proved reserves and if determined incapable of producing commercial quantities of oil and gas these costs are expensed as dry hole costs. At year-end 2016 , we have no capitalized exploratory well costs pending determination of proved reserves. Exploration costs include dry hole costs, geological and geophysical costs, expired unproved leasehold costs and seismic studies, and are expensed as incurred. Production costs incurred to maintain wells and related equipment are charged to expense as incurred. Depreciation and depletion of producing oil and gas properties is calculated using the units-of-production method. Proved developed reserves are used to compute unit rates for unamortized tangible and intangible drilling and completion costs. Proved reserves are used to compute unit rates for unamortized acquisition of proved leasehold costs. Unit-of-production amortization rates are revised whenever there is an indication of the need for revision but at least once a year and those revisions are accounted for prospectively as changes in accounting estimates. Impairment of Oil and Gas Properties We evaluate our oil and gas properties, including facilities and equipment, for impairment whenever events or changes in circumstances indicate that the carrying value of an asset may not be recoverable. We estimate the expected undiscounted future cash flows of our oil and gas properties and compare such undiscounted future cash flows to the carrying amount of the oil and gas properties to determine if the carrying amount is recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, we will adjust the carrying amount of the oil and gas properties to fair value. The factors used to determine fair value are subject to our judgment and expertise and include, but are not limited to, recent sales prices of comparable properties, the present value of future cash flows, net of estimated operating and development costs using estimates of proved reserves, future commodity pricing, future production estimates, anticipated capital expenditures, and various discount rates commensurate with the risk and current market conditions associated with realizing the expected cash flows projected. Because of the uncertainty inherent in these factors, we cannot predict when or if future impairment charges for proved properties will be recorded. The assessment of unproved leasehold properties to determine any possible impairment requires significant judgment. We assess our unproved leasehold properties periodically for impairment on a property-by-property basis based on remaining lease terms, drilling results or future plans to develop acreage. Impairment expense for proved and unproved oil and gas properties are included in cost of mineral resources and cost of oil and gas producing activities in discontinued operations. Operating Leases We occupy office space in various locations under operating leases. The lease agreements may contain rent escalation clauses, construction allowances and/or contingent rent provisions. We expense operating leases ratably over the shorter of the useful life or the lease term. For scheduled rent escalation clauses, we recognize the base rent expense on a straight-line basis and record the difference between the recognized rent expense and the amounts payable under the lease as deferred lease credits included in other liabilities in the consolidated balance sheets. Deferred lease credits are amortized over the lease term. For construction allowances, we record leasehold improvement assets included in property and equipment in the consolidated balance sheets amortized over the shorter of their economic lives or the lease term. The related deferred lease credits are amortized as a reduction of rent expense over the lease term. Property and Equipment We carry property and equipment at cost less accumulated depreciation. We capitalize the cost of significant additions and improvements, and we expense the cost of repairs and maintenance. We capitalize interest costs incurred on major construction projects. We depreciate these assets using the straight-line method over their estimated useful lives as follows: Estimated Year-End Useful Lives 2016 2015 (In thousands) Buildings and building improvements 10 to 40 years $ 2,700 $ 4,044 Property and equipment 2 to 10 years 4,957 12,230 7,657 16,274 Less: accumulated depreciation (4,541 ) (5,542 ) $ 3,116 $ 10,732 Depreciation expense of property and equipment was $889,000 in 2016 , $1,067,000 in 2015 and $903,000 in 2014 . Real Estate We carry real estate at the lower of cost or fair value less cost to sell. We capitalize interest costs once development begins, and we continue to capitalize throughout the development period. We also capitalize infrastructure, improvements, amenities, and other development costs incurred during the development period. We determine the cost of real estate sold using the relative sales value method. When we sell real estate from projects that are not finished, we include in the cost of real estate sold estimates of future development costs through completion, allocated based on relative sales values. These estimates of future development costs are reevaluated at least annually, with any adjustments being allocated prospectively to the remaining units available for sale. We receive cash deposits from home builders for purchases of vacant developed lots from community development projects. These earnest money deposits are released to the home builders as lots are developed and sold. Income producing properties are carried at cost less accumulated depreciation computed using the straight-line method over their estimated useful lives. We have agreements with utility or improvement districts, principally in Texas, whereby we agree to convey to the districts water, sewer and other infrastructure-related assets we have constructed in connection with projects within their jurisdiction. The reimbursement for these assets ranges from 70 to 90 percent of allowable cost as defined by the district. The transfer is consummated and we receive payment when the districts have a sufficient tax base to support funding of their bonds. The cost we incur in constructing these assets is included in capitalized development costs, and upon collection, we remove the assets from capitalized development costs. We provide an allowance to reflect our past experiences related to claimed allowable development costs. Impairment of Real Estate Long-Lived Assets We review real estate long-lived assets held for use for impairment when events or circumstances indicate that their carrying value may not be recoverable. Impairment exists if the carrying amount of the long-lived asset is not recoverable from the undiscounted cash flows expected from its use and eventual disposition. We determine the amount of the impairment loss by comparing the carrying value of the long-lived asset to its estimated fair value. In the absence of quoted market prices, we determine estimated fair value generally based on the present value of future probability weighted cash flows expected from the sale of the long-lived asset. Non-cash impairment charges related to our owned and consolidated real estate assets are included in cost of real estate sales and other. In 2016, we recorded $56,453,000 in non-cash impairment charges related to six non-core community development projects and two multifamily sites. Revenue Real Estate We recognize revenue from sales of real estate when a sale is consummated, the buyer’s initial investment is adequate, any receivables are probable of collection, the usual risks and rewards of ownership have been transferred to the buyer, and we do not have significant continuing involvement with the real estate sold. If we determine that the earnings process is not complete, we defer recognition of any gain until earned. We recognize revenue from hotel room sales and other guest services when rooms are occupied and other guest services have been rendered. We recognize rental revenues from our multifamily properties when earned in accordance with the terms of the respective leases on a straight-line basis for the period of occupancy. We recognize construction revenues on multifamily projects that we develop as a general contractor. Construction revenues are recognized as costs are incurred plus fixed fee earned. We are reimbursed for costs paid to subcontractors plus we may earn a development and construction management fee on multifamily projects we develop, both of which are included in commercial and income producing properties revenue. On multifamily projects where our fee is based on a fixed fee plus guaranteed maximum price contract, any cost overruns incurred during construction, as compared to the original budget, will reduce the net fee generated on these projects. Any excess cost overruns estimated over the net fee generated are recognized in the period in which they become evident. At year-end 2016, we were not a general contractor on any of the multifamily projects currently under construction and we do not anticipate to be a general contractor on any new multifamily projects as we determined multifamily was non-core and we would not be making any new investments in this business. We exclude from revenue amounts we collect from utility or improvement districts related to the conveyance of water, sewer and other infrastructure related assets. We also exclude from revenue amounts we collect for timber sold on land being developed. These proceeds reduce capitalized development costs. We exclude from revenue amounts we collect from customers that represent sales tax or other taxes that are based on the sale. These amounts are included in other accrued expenses until paid. Oil and Gas Working Interest Revenues (Discontinued Operations) We recognize revenue as oil and gas is produced and sold. There are a significant amount of oil and gas properties which we do not operate and, therefore, revenue is typically recorded in the month of production based on an estimate of our share of volumes produced and prices realized. We obtain the most current available production data from the operators and price indices for each well to estimate the accrual of revenue. Obtaining production data on a timely basis for some wells is not feasible; therefore we utilize past production receipts and estimated sales price information to estimate accrual of working interest revenue on all other non-operated wells each month. Revisions to such estimates are recorded as actual results become known. We review accounts receivable periodically and reduce the carrying amount by a valuation allowance that reflects our best estimate of the amount that may not be collectible. A majority of our sales are made under contractual arrangements with terms that are considered to be usual and customary in the oil and gas industry. The contracts are for periods of up to five years with prices determined upon a percentage of pre-determined and published monthly index price. The terms of these contracts have not had an effect on how we recognize revenue. Mineral Resources We recognize revenue from mineral bonus payments when we have received an executed agreement with the exploration company transferring the rights to any oil or gas it may find and requiring drilling be done within a specified period, the payment has been collected, and we have no obligation to refund the payment. We recognize revenue from delay rentals received if drilling has not started within the specified period and when the payment has been collected. We recognize revenue from mineral royalties and non-working interests when the minerals have been delivered to the buyer, the value is determinable, and we are reasonably sure of collection. Other We recognize revenue from timber sales upon passage of title, which occurs at delivery; when the price is fixed and determinable; and we are reasonably sure of collection. We recognize revenue from recreational leases on the straight-line basis over the lease term. We recognize revenue from the sale of water rights or groundwater reservation agreements upon receipt of an executed agreement and payment has been collected and all conditions to the agreement have been met and we have no further performance obligations to meet. The water delivery revenues will be recognized as water is being delivered and metered at the delivery point. Share-Based Compensation We use the Black-Scholes option pricing model for stock options, Monte Carlo simulation pricing model for market-leveraged stock units and for stock options with market conditions, grant date fair value for equity-settled awards and period-end fair value for cash-settled awards. We expense share-based awards ratably over the vesting period or earlier based on retirement eligibility. Timber We carry timber at cost less the cost of timber cut. We expense the cost of timber cut based on the relationship of the timber carrying value to the estimated volume of recoverable timber multiplied by the amount of timber cut. We include the cost of timber cut in cost of other. We determine the estimated volume of recoverable timber using statistical information and other data related to growth rates and yields gathered from physical observations, models and other information gathering techniques. Changes in yields are generally due to adjustments in growth rates and similar matters and are accounted for prospectively as changes in estimates. We capitalize reforestation costs incurred in developing viable seedling plantations (up to two years from planting), such as site preparation, seedlings, planting, fertilization, insect and wildlife control, and herbicide application. We expense all other costs, such as property taxes and costs of forest management personnel, as incurred. Once the seedling plantation is viable, we expense all costs to maintain the viable plantations, such as fertilization, herbicide application, insect and wildlife control, and thinning, as incurred. We own about 19,000 acres of non-core timberland and undeveloped land, in Georgia and Texas. The non-cash cost of timber cut and sold is $63,000 in 2016 , $250,000 in 2015 and $371,000 in 2014 and is included in depreciation, depletion and amortization in our consolidated statements of cash flows.

New and Pending Accounting Pron

New and Pending Accounting Pronouncements	12 Months Ended
	Dec. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
New and Pending Accounting Pronouncements	New and Pending Accounting Pronouncements Adoption of New Accounting Standards In April 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2015-03, Interest – Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs, as part of its initiative to reduce complexity in accounting standards. To simplify presentation of debt issuance costs, the amendments in this update require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. In August 2015, the FASB issued ASU 2015-15, Interest-Imputation of Interest (Subtopic 835-30), Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements - Amendments to SEC Paragraphs Pursuant to Staff Announcement at June 18, 2015 EITF Meeting (SEC Update), which allows an entity to defer and present debt issuance costs as an asset and subsequently amortize the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. The updated standards are effective for financial statements issued for annual and interim periods beginning after December 15, 2015. We adopted ASU 2015-03 in first quarter 2016 and prior period amounts have been reclassified to conform to the current period presentation. As of December 31, 2015, $8,267,000 of debt issuance costs were reclassified in the consolidated balance sheets from other assets to debt. The adoption did not impact our consolidated financial position, results of operations or cash flows. As permitted under this guidance, we will continue to present debt issuance costs associated with revolving-debt agreements as other assets. In February 2015, the FASB issued ASU 2015-02, Consolidation: Amendments to the Consolidation Analysis (Topic 810) , requiring entities to evaluate whether they should consolidate certain legal entities. All legal entities are subject to reevaluation under the revised consolidation model. The revised consolidation model: (1) modifies the evaluation of whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities, (2) eliminates the presumption that a general partner should consolidate a limited partnership, (3) affects the consolidation analysis of reporting entities that are involved with VIEs, and (4) provides a scope exception from consolidation guidance for reporting entities with interests in certain legal entities. The updated standard is effective for financial statements issued for annual and interim periods beginning after December 15, 2015. The adoption of this guidance, which was applied retrospectively, had no impact to our consolidated financial statements. In January 2015, the FASB issued ASU 2015-01, Income Statement - Extraordinary and Unusual Items (Subtopic 225-20), which eliminates the concept of extraordinary items from U.S. GAAP. The updated standard is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015. Early adoption is permitted, provided that the guidance is applied from the beginning of the fiscal year of adoption. The adoption of this guidance had no impact on our financial statements and related disclosures. Pending Accounting Standards In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , requiring an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The updated standard will replace most existing revenue recognition guidance in U.S. GAAP when it becomes effective and permits the use of either the retrospective or cumulative effect transition method. Early adoption is not permitted. The updated standard becomes effective for annual and interim periods beginning after December 15, 2017. The guidance permits two methods of adoption: retrospectively to each prior reporting period presented (full retrospective method), or retrospectively with the cumulative effect initially applying the guidance recognized at the date of initial application (the cumulative catch-up transition method). We currently anticipate adopting the standard using the cumulative catch-up transition method. We anticipate this standard will not have a material impact on our consolidated financial statements. While we are continuing to assess all potential impacts of the standard, we expect revenue related to lot and tract sales to remain substantially unchanged. Due to the complexity of certain of our real estate sale transactions, the revenue recognition treatment required under the standard will be dependent on contract-specific terms, and may vary in some instances from recognition at the time of the sale closing. In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842). This ASU requires lessees to put most leases on their balance sheets but recognize expenses on their income statements in a manner that is similar to today's accounting. This guidance also eliminates today's real estate-specific provisions for all entities. For lessors, the guidance modifies the classification criteria and the accounting for sales-type and direct financing leases. This guidance is effective in 2019, and interim periods within that year. Early adoption is permitted. The new leases standard requires a modified retrospective transition approach for all leases existing at, or entered into after, the date of initial application, with an option to use certain transition relief. We are currently evaluating the effect the updated standard will have on our financial position and disclosures. In March 2016, the FASB issued ASU 2016-09, Compensation-Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting , as part of its simplification initiative. The areas for simplification in this update involve several aspects of the accounting for share-based payment transactions, including income tax consequences, classification of awards as either equity or liabilities, and the classification on the statement of cash flows. The updated standard becomes effective for annual and interim periods beginning after December 31, 2016. We are currently evaluating the effect that the updated standard will have on our earnings, financial position and disclosures, but we do not expect it to have a material impact on our consolidated financial statements. In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230) , in order to address eight specific cash flow issues with the objective of reducing the existing diversity in practice. The updated standard is effective for financial statements issued for annual periods beginning after December 15, 2017 and interim periods within those fiscal years with early adoption permitted. We are currently evaluating the effect that the updated standard will have on our earnings, financial position and disclosures, but we do not expect it to have a material effect on our consolidated financial statements. In November, 2016, the FASB issued ASU 2016-18, Statement of Cash Flows (Topic 230). This ASU requires that a statement of cash flow explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash investments. This standard is effective for fiscal years beginning after December 15, 2017. The adoption of ASU 2016-18 will modify our current disclosures and reclassifications relating to the consolidated statements of cash flows, but we do not expect it to have a material effect on our consolidated financial statements.

Real Estate

Real Estate	12 Months Ended
	Dec. 31, 2016
Real Estate [Abstract]
Real Estate	Real Estate Real estate consists of: Year-End 2016 Year-End 2015 Carrying Value Accumulated Depreciation Net Carrying Value Carrying Value Accumulated Depreciation Net Carrying Value (In thousands) Entitled, developed and under development projects $ 263,859 $ — $ 263,859 $ 352,141 $ — $ 352,141 Undeveloped land (includes land in entitlement) 29,144 — 29,144 98,181 — 98,181 Commercial Radisson Hotel & Suites (a) — — — 62,889 (29,268 ) 33,621 Income producing properties Eleven (a) — — — 53,896 (2,861 ) 51,035 Dillon (a) — — — 19,987 — 19,987 Music Row (a) — — — 9,947 — 9,947 Downtown Edge (a) — — — 12,706 — 12,706 West Austin (b) — — — 9,097 — 9,097 $ 293,003 $ — $ 293,003 $ 618,844 $ (32,129 ) $ 586,715 _________________________ (a) Sold in 2016. (b) Classified as assets held for sale at year-end 2016. In 2016, we recognized non-cash impairment charges of $56,453,000 related to six non-core community development projects and two multifamily sites. These impairments were a result of our key initiative to review our entire portfolio of assets which resulted in business plan changes, inclusive of cash tax savings considerations, to market these properties for sale, which resulted in adjustment of the carrying value to fair value. In 2016, we sold the Radisson Hotel & Suites, a 413 room hotel in Austin, for $130,000,000 , generating $128,764,000 in net proceeds before paying in full the associated debt of $15,400,000 and recognized a gain on sale of $95,336,000 . We also sold Eleven, a wholly-owned 257 -unit multifamily property in Austin, for $60,150,000 , generating $59,719,000 in net proceeds before paying in full the associated debt of $23,936,000 and recognized a gain on sale of $9,116,000 . In addition, we sold Dillon, a planned 379 -unit multifamily property that was under construction in Charlotte, for $25,979,000 , generating $25,428,000 in net proceeds and recognized a gain on sale of $1,223,000 , and Music Row, a planned 230 -unit multifamily property that was under construction in Nashville, for $15,025,000 , generating $14,703,000 in net proceeds and recognized a gain on sale of $3,968,000 . We also sold Downtown Edge, a multifamily site in Austin, for $5,000,000 , generating $4,975,000 in net proceeds and recognized a loss of $3,870,000 . In 2016, we sold over 58,300 acres of timber and timberland in Georgia and Alabama for $104,172,000 in three transactions generating combined net proceeds of $103,238,000 . These transactions resulted in a combined gain on sale of assets of $48,891,000 . In 2015, we sold Midtown Cedar Hill, a 354 -unit multifamily property we developed near Cedar, Hill, Texas for $42,880,000 , generating segment earnings of $9,265,000 and generating $42,639,000 in net proceeds before paying in full the associated debt of $24,166,000 . Depreciation expense related to commercial and income producing properties was $816,000 in 2016 , $6,810,000 in 2015 and $3,319,000 in 2014 and is included in other operating expense. As a general contractor on guaranteed maximum price contracts associated with two multifamily venture properties, we recognized charges of $392,000 in 2016 , $1,543,000 in 2015 and $5,111,000 in 2014 related to cost overruns. Our estimated cost of assets for which we expect to be reimbursed by utility and improvement districts were $45,157,000 at year-end 2016 and $67,554,000 at year-end 2015 , which included $14,749,000 at year-end 2016 and $22,302,000 at year-end 2015 related to our Cibolo Canyons project near San Antonio. In 2016, we collected $26,606,000 in reimbursements that were previously submitted to these districts. At year-end 2016, our inception to-date submitted and approved reimbursements for the Cibolo Canyons project were $54,376,000 , of which we have collected $45,132,000 . These costs are principally for water, sewer and other infrastructure assets that we have incurred and submitted or will submit to utility or improvement districts for approval and reimbursement. We expect to be reimbursed by utility and improvement districts when these districts achieve adequate tax basis or otherwise have funds available to support payment. In 2014, we received $50,550,000 from Cibolo Canyons special improvement district (CCSID) and recognized a gain of $6,577,000 related to its issuance of $48,900,000 Hotel Occupancy Tax (HOT) and Sales and Use Tax Revenue Bonds. These bonds are obligations solely of CCSID and are payable from HOT and sales and use taxes levied on the Resort by CCSID. To facilitate the issuance of the bonds, we provided a $6,846,000 letter of credit to the bond trustee as security for certain debt service fund obligations in the event CCSID tax collections are not sufficient to support payment of the bonds in accordance with their terms. The letter of credit must be maintained until the earlier of redemption of the bonds or scheduled bond maturity in 2034. We also entered into an agreement with the owner of the Resort to assign its senior rights to us in exchange for consideration provided by us, including a surety bond to be drawn if CCSID tax collections are not sufficient to support ad valorem tax rebates payable. The surety bond has a balance of $6,631,000 at year-end 2016. The deferred gains related to the letter of credit and surety bond are included in other liabilities on our consolidated balance sheet. The surety bond decreases and gains are recognized as CCSID makes annual ad valorem tax rebate payments, which obligation is scheduled to be retired in full by 2020. All future receipts are expected to be recognized as gains in the period collected. We recorded gains of $1,219,000 and $1,160,000 in 2016 and 2015 associated with reduction of surety bond and gains of $501,000 and $425,000 in 2016 and 2015 associated with excess hotel occupancy and sales and use tax revenues from CCSID in 2015.

Investment in Unconsolidated Ve

Investment in Unconsolidated Ventures	12 Months Ended
	Dec. 31, 2016
Equity Method Investments and Joint Ventures [Abstract]
Investment in Unconsolidated Ventures	Investment in Unconsolidated Ventures We participate in real estate ventures for the purpose of acquiring and developing residential, multifamily and mixed-use communities in which we may or may not have a controlling financial interest. U.S. GAAP requires consolidation of Variable Interest Entities (VIEs) in which an enterprise has a controlling financial interest and is the primary beneficiary. A controlling financial interest will have both of the following characteristics: (a) the power to direct the VIE activities that most significantly impact economic performance and (b) the obligation to absorb the VIE losses and right to receive benefits that are significant to the VIE. We examine specific criteria and use judgment when determining whether a venture is a VIE and whether we are the primary beneficiary. We perform this review initially at the time we enter into venture agreements and reassess upon reconsideration events. At year-end 2016 , we had ownership interests in 16 ventures that we accounted for using the equity method, none of which are a VIE. In 2016, we sold our interest in FMF Peakview LLC (360 0 ), a 304 -unit multifamily joint venture near Denver, generating $13,917,000 in net proceeds and recognized a gain of $10,363,000 which is included in gain on sale of assets. Combined summarized balance sheet information for our ventures accounted for using the equity method follows: Venture Assets Venture Borrowings (a) Venture Equity Our Investment At Year-End 2016 2015 2016 2015 2016 2015 2016 2015 (In thousands) 242, LLC (b) $ 26,503 $ 26,687 $ 1,107 $ — $ 23,136 $ 24,877 $ 10,934 $ 11,766 CL Ashton Woods, LP (c) 2,653 7,654 — — 2,198 6,084 1,107 3,615 CL Realty, LLC 8,048 7,872 — — 7,899 7,662 3,950 3,831 CREA FMF Nashville LLC (b) 56,081 57,820 37,446 50,845 17,091 4,291 4,923 3,820 Elan 99, LLC 49,652 34,192 36,238 14,587 13,100 15,838 11,790 14,255 FMF Littleton LLC 70,282 52,376 44,446 22,347 23,798 24,370 6,128 6,270 FMF Peakview LLC — 48,869 — 30,485 — 16,828 — 3,447 FOR/SR Forsyth LLC 10,672 6,500 1,568 — 8,990 6,500 8,091 5,850 HM Stonewall Estates, Ltd (c) 852 2,842 — — 852 2,842 477 1,294 LM Land Holdings, LP (c) 25,538 31,984 3,477 7,728 20,945 22,751 9,685 9,664 MRECV DT Holdings LLC 4,155 4,215 — — 4,144 4,215 3,729 3,807 MRECV Edelweiss LLC 3,484 2,237 — — 3,484 2,237 3,358 2,029 MRECV Juniper Ridge LLC 4,156 3,006 — — 4,156 3,006 3,741 2,730 MRECV Meadow Crossing II LLC 2,492 728 — — 2,491 728 2,242 655 Miramonte Boulder Pass, LLC 10,738 12,627 4,006 5,869 5,265 5,474 5,330 5,349 Temco Associates, LLC 4,368 5,284 — — 4,253 5,113 2,126 2,557 Other ventures (d) — 4,174 — 2,242 — 1,922 — 1,514 $ 279,674 $ 309,067 $ 128,288 $ 134,103 $ 141,802 $ 154,738 $ 77,611 $ 82,453 Combined summarized income statement information for our ventures accounted for using the equity method follows: Revenues Earnings (Loss) Our Share of Earnings (Loss) For the Year 2016 2015 2014 2016 2015 2014 2016 2015 2014 (In thousands) 242, LLC (b) $ 5,835 $ 20,995 $ 5,612 $ 1,259 $ 9,588 $ 2,951 $ 668 $ 4,919 $ 1,514 CL Ashton Woods, LP (c) 2,870 9,820 5,431 914 3,881 1,748 1,332 5,000 2,471 CL Realty, LLC 567 856 1,573 237 424 1,068 119 212 534 CREA FMF Nashville LLC (b) (d) 4,955 1,227 — (1,420 ) (1,696 ) (163 ) 1,103 (1,696 ) (163 ) Elan 99, LLC 1,392 — — (2,739 ) (49 ) (87 ) (2,465 ) (44 ) (78 ) FMF Littleton LLC 3,116 120 — (571 ) (367 ) (239 ) (143 ) (92 ) (60 ) FMF Peakview LLC 939 2,057 4 (248 ) (1,116 ) (410 ) (50 ) (223 ) (83 ) FOR/SR Forsyth LLC — — (65 ) — (58 ) — HM Stonewall Estates, Ltd. (c) 2,112 3,990 1,728 832 1,881 613 361 952 248 LM Land Holdings, LP (c) 10,001 10,956 21,980 7,288 8,251 15,520 2,458 3,342 4,827 MRECV DT Holdings LLC 495 — 477 167 429 — MRECV Edelweiss LLC 416 — 409 151 368 137 MRECV Juniper Ridge LLC 379 — 380 106 342 — MRECV Meadow Crossing II LLC 267 — — 220 — — 198 — — Miramonte Boulder Pass, LLC 4,923 — (399 ) (250 ) (200 ) (125 ) PSW Communities, LP — 29,986 — — 2,688 (86 ) — 1,169 (76 ) TEMCO Associates, LLC 1,344 9,485 2,155 440 2,358 494 220 1,179 247 Other ventures 6,519 36,237 3,960 2,105 33,303 3,879 1,441 1,278 (696 ) $ 46,130 $ 125,729 $ 42,443 $ 9,119 $ 59,320 $ 25,288 $ 6,123 $ 16,008 $ 8,685 _____________________ (a) Total includes current maturities of $89,756,000 at year-end 2016 , of which $78,557,000 is non-recourse to us, and $39,590,000 at year-end 2015 , of which $29,691,000 is non-recourse to us. (b) Includes unamortized deferred gains on real estate contributed by us to ventures. We recognize deferred gains as income as real estate is sold to third parties. Deferred gains of $1,457,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2016 . (c) Includes unrecognized basis difference of $259,000 which is reflected as an increase of our investment in unconsolidated ventures at year-end 2016 . This difference between estimated fair value of the equity investment and our capital account within the respective ventures at closing will be accreted as income or expense over the life of the investment and included in our share of earnings (loss) from the respective ventures. (d) Our share of venture earnings in 2016 includes reallocation of prior year cumulative losses incurred by the venture as a result of equity contribution by the venture partner in 2016. In 2016 , we invested $6,089,000 in these ventures and received $13,419,000 in distributions; in 2015 , we invested $26,349,000 in these ventures and received $24,909,000 in distributions; and in 2014 , we invested $14,692,000 in these ventures and received $7,518,000 in distributions. Distributions include both return of investments and distributions of earnings. We provide construction and development services for some of these ventures for which we receive fees. Fees for these services were $2,466,000 in 2016 , $1,856,000 in 2015 and $2,275,000 in 2014 , and are included in real estate revenues.

Goodwill and Other Intangible A

Goodwill and Other Intangible Assets	12 Months Ended
	Dec. 31, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Other Intangible Assets	Goodwill and Other Intangible Assets Carrying value of goodwill and other intangible assets follows: Year-End 2016 2015 (In thousands) Goodwill $ 37,900 $ 41,774 Identified intangibles, net — 1,681 $ 37,900 $ 43,455 Goodwill related to our mineral interests was $37,900,000 at year-end 2016 and 2015 . Goodwill associated with our water resources initiatives was $0 and $3,874,000 at year-end 2016 and 2015 . In 2016, we recognized a goodwill non-cash impairment charge of $3,874,000 related to interests in groundwater leases in central Texas as result of entering into an agreement to sell these assets. Impairment charges are included in cost of other on our consolidated statements of income (loss) and comprehensive income (loss). Identified intangibles include $1,681,000 in indefinite lived groundwater leases associated with our water resources initiatives and is included in assets held for sale at year-end 2016 .

Held for Sale

Held for Sale	12 Months Ended
	Dec. 31, 2016
Discontinued Operations and Disposal Groups [Abstract]
Held for Sale	Held for Sale At year-end 2016, assets held for sale includes approximately 19,000 acres of timberland and undeveloped land and the related timber, a multifamily site in Austin, our owned mineral interest assets and central Texas groundwater assets. The major classes of assets and liabilities of the properties held for sale at year-end 2016 are as follows: At Year-End 2016 Assets Held for Sale: (In thousands) Real estate $ 19,931 Timber 1,682 Other intangible assets 1,681 Oil and gas properties and equipment, net 782 Property and equipment, net 6,301 $ 30,377 Liabilities Held for Sale: Other liabilities 103 $ 103

Discontinued Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2016
Discontinued Operations and Disposal Groups [Abstract]
Discontinued Operations	Discontinued Operations At year-end 2016, we have divested substantially all of our oil and gas working interest properties. As a result of this significant change in our operations, we have reported the results of operations and financial position of these assets as discontinued operations within the consolidated statements of income (loss) and comprehensive income (loss) and consolidated balance sheets for all periods presented. In addition, in second quarter 2016, we changed the name of the oil and gas segment to mineral resources to reflect the strategic shift from oil and gas working interest investments to owned mineral interests. Summarized results from discontinued operations were as follows: For the Year 2016 2015 2014 Revenues $ 5,862 $ 43,845 $ 68,610 Cost of oil and gas producing activities (6,578 ) (221,402 ) (94,581 ) Other operating expenses (7,754 ) (10,363 ) (14,357 ) Loss from discontinued operations before income taxes $ (8,470 ) $ (187,920 ) $ (40,328 ) Gain (loss) on sale of assets before income taxes (13,664 ) (706 ) 8,526 Income tax benefit 5,269 2,496 12,193 Loss from discontinued operations, net of taxes $ (16,865 ) $ (186,130 ) $ (19,609 ) In 2016, we recorded a net loss of $13,664,000 on the sale of 199,263 net mineral acres leased from others and 379 gross ( 95 net) producing oil and gas working interest wells in Nebraska, Kansas, Oklahoma and North Dakota for total net proceeds of $80,374,000 , which includes $3,269,000 in reimbursement of capital costs incurred on in-progress wells that were assumed by the buyer. Other operating expenses in 2016 include loss contingency charges of $2,990,000 related to litigation and $1,155,000 related to potential environmental liabilities to plug and abandon certain oil and gas wells in Wyoming. Please read Note 14—Litigation and Environmental Contingencies for additional information about these items. In 2015, we recorded a net loss of $706,000 on the sale of 109,000 net mineral acres leased from others and the disposition of 39 gross ( 7 net) producing oil and gas wells in Nebraska, Texas, Colorado, North Dakota and Oklahoma for total net proceeds of $17,800,000 . In 2014, we recorded a net gain of $8,526,000 on the sale of 650 net mineral acres leased from others and 124 gross ( 18 net) producing oil and gas working interest wells in Nebraska, Kansas, Oklahoma and North Dakota for total net proceeds of $17,660,000 . Cost of sales includes non-cash impairment charges of $612,000 in 2016 , $163,029,000 in 2015 and $32,665,000 in 2014 related to our proved properties and unproved leasehold oil and gas working interests. The major classes of assets and liabilities of discontinued operations at year-end 2016 and 2015 are as follows: At Year-End 2016 2015 (In thousands) Assets of Discontinued Operations: Receivables, net of allowance for bad debt $ 6 $ 4,632 Oil and gas properties and equipment, net — 79,733 Goodwill and other intangible assets — 19,673 Prepaid expenses 8 96 Other assets — 833 $ 14 $ 104,967 Liabilities of Discontinued Operations: Accounts payable $ 67 $ 342 Accrued property taxes — 259 Other accrued expenses 5,228 8,924 Other liabilities — 1,667 $ 5,295 $ 11,192 Significant operating activities and investing activities of discontinued operations are as follows: For the Year 2016 2015 2014 (In thousands) Operating activities: Asset impairments $ 612 $ 105,337 $ 15,535 Dry hole and unproved leasehold impairment charges — 67,639 29,528 Loss (gain) on sale of assets 13,664 706 (8,526 ) Depreciation, depletion and amortization 2,202 28,391 28,758 $ 16,478 $ 202,073 $ 65,295 Investing activities: Oil and gas properties and equipment $ (579 ) $ (49,717 ) $ (101,145 ) Acquisition of oil and gas properties — — (1,100 ) Proceeds from sales of assets 77,105 17,800 17,660 $ 76,526 $ (31,917 ) $ (84,585 )

Receivables

Receivables	12 Months Ended
	Dec. 31, 2016
Receivables [Abstract]
Receivables	Receivables Receivables consist of: At Year-End 2016 2015 (In thousands) Funds held by qualified intermediary for potential 1031 like-kind exchange $ — $ 14,703 Other receivables and accrued interest 1,505 2,218 Other loans secured by real estate, average interest rate of 5.86% at year-end 2016 and 11.31% at year-end 2015 7,452 2,130 8,957 19,051 Allowance for bad debts (26 ) (26 ) $ 8,931 $ 19,025 In 2016, we received funds previously held by qualified intermediary because we did not complete an intended like-kind exchange related to a sale of 6,915 acres of undeveloped land. Other loans secured by real estate generally are secured by a deed of trust and due within three to five years .

Debt

Debt	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Debt	Debt Debt consists of: At Year-End 2016 2015 (In thousands) 8.50% senior secured notes due 2022 5,200 224,647 3.75% convertible senior notes due 2020, net of discount 104,673 104,719 6.00% tangible equity units, net — 8,666 Secured promissory notes — average interest rates of 3.42% at year-end 2015 — 15,400 Other indebtedness due through 2018 at variable and fixed interest rates ranging from 5.0% to 5.50% 485 28,083 $ 110,358 $ 381,515 In 2016 , we reduced the revolving commitment provided by our senior secured credit facility, which matures on May 15, 2017 (with two one -year extension options), from $300,000,000 to $125,000,000 , none of which was drawn at year-end 2016. The revolving line of credit may be prepaid at any time without penalty. The revolving line of credit includes a $100,000,000 sublimit for letters of credit, of which $14,850,000 was outstanding at year-end 2016 . Total borrowings under our senior secured credit facility (including the face amount of letters of credit) may not exceed a borrowing base formula. At year-end 2016 , we had $71,262,000 in net unused borrowing capacity under our senior credit facility. Under the terms of our senior secured credit facility, at our option, we can borrow at LIBOR plus 4.0 percent or at the alternate base rate plus 3.0 percent . The alternate base rate is the highest of (i) KeyBank National Association’s base rate, (ii) the federal funds effective rate plus 0.5 percent or (iii) 30 day LIBOR plus 1 percent . Borrowings under the senior secured credit facility are or may be secured by (a) mortgages on the timberland, high value timberland and portions of raw entitled land, as well as pledges of other rights including certain oil and gas operating properties, (b) assignments of current and future leases, rents and contracts, (c) a security interest in our primary operating account, (d) a pledge of the equity interests in current and future material operating subsidiaries and most of our majority-owned joint venture interests, or if such pledge is not permitted, a pledge of the right to distributions from such entities, and (e) a pledge of certain reimbursements payable to us from special improvement district tax collections in connection with our Cibolo Canyons project. The senior secured credit facility provides for releases of real estate and other collateral provided that borrowing base compliance is maintained. Our debt agreements contain financial covenants customary for such agreements including minimum levels of interest coverage and limitations on coverage. At year-end 2016, our tangible net worth requirement was $426,312,000 computed as: $379,044,000 plus 85 percent of the aggregate net proceeds received by us from any equity offering, plus 75 percent of all positive net income, on a cumulative basis since third quarter 2015. At year-end 2016, we were in compliance with the financial covenants of these agreements. We may elect to make distributions to stockholders so long as the total leverage ratio is less than 40 percent , the interest coverage ratio is greater than 3.0 :1.0 and available liquidity is not less than $125,000,000 , all of which were satisfied at year-end 2016. Regardless of whether the foregoing conditions are satisfied, we may make distributions in an aggregate amount not to exceed $50,000,000 to be funded from up to 65% of the net proceeds from sales of multifamily properties and non-core assets, such as the Radisson Hotel & Suites in Austin, and any oil and gas properties. In 2014, we issued $250,000,000 aggregate principal of 8.5% Senior Secured Notes due 2022 (Notes). The Notes will mature on June 1, 2022 and interest on the Notes is payable semiannually at a rate of 8.5 percent per annum in arrears. In 2016, we completed a cash tender offer for our Notes, pursuant to which we purchased $215,495,000 principal amount (representing approximately 97.6% outstanding) of the Notes. Total consideration paid was $245,604,000 , which included $29,091,000 in premium at 113.5% and $1,018,000 in accrued and unpaid interest. In addition, we received consent from holders of the Notes to eliminate or modify certain covenants, events of default and other provisions contained in the indenture governing the Notes, and to release the subsidiary guarantees and collateral securing the Notes. We also purchased $9,750,000 principal amount of the Notes between 99% and 99.95% of face value in open market transactions. The 2016 tender offer and open market purchases resulted in a $35,681,000 loss on extinguishment of debt, which includes the premium paid to repurchase the Notes, write-off of unamortized debt issuance costs of $5,416,000 and $1,301,000 in other costs related to tender offer advisory services. In 2015, we purchased $19,440,000 principal amount of Notes at 97% of face value, resulting in a gain of $589,000 on the early extinguishment of the retired Notes, offset by the write-off of unamortized debt issuance costs of $506,000 allocated to the retired Notes. In 2013, we issued $125,000,000 aggregate principal amount of 3.75% convertible senior notes due 2020 (Convertible Notes). Interest on the Convertible Notes is payable semiannually at a rate of 3.75 percent per annum and they mature on March 1, 2020 . The Convertible Notes have an initial conversion rate of 40.8351 per $1,000 principal amount. The initial conversion rate is subject to adjustment upon the occurrence of certain events. Prior to November 1, 2019, the Convertible Notes are convertible only upon certain circumstances, and thereafter are convertible at any time prior to the close of business on the second scheduled trading day prior to maturity. If converted, holders will receive cash, shares of our common stock or a combination thereof at our election. We intend to settle the principal amount of the Convertible Notes in cash upon conversion, with any excess conversion value to be settled in shares of our common stock. At year-end 2016 , unamortized debt discount of our Convertible Notes was $13,809,000 . In 2016, we purchased $5,000,000 of 3.75% Convertible Senior Notes due 2020 at 93.25% of face value in open market transactions for $4,663,000 and we allocated $4,452,000 to extinguish the debt and $211,000 to reacquire the equity component within the convertible notes based on the fair value of the debt component. We recognized a $110,000 loss on extinguishment of debt based on the difference between the fair value of the debt component prior to conversion and the carrying value of the debt component. Total loss on extinguishment of debt including write-off of debt issuance costs allocated to the repurchased notes was $183,000 . In 2013, we issued $150,000,000 aggregate principal amount of 6.00% tangible equity units (Units). The total offering was 6,000,000 Units, including 600,000 exercised by the underwriters, each with a stated amount of $25.00 . Each Unit is comprised of (i) a prepaid stock purchase contract to be settled by delivery of a number of shares of our common stock, par value $1.00 per share to be determined pursuant to a purchase contract agreement, and (ii) a senior amortizing note due December 15, 2016 that has an initial principal amount of $4.2522 , bears interest at a rate of 4.50% per annum and has a final installment payment date of December 15, 2016. On December 15, 2016, we made the final installment payment of principal and accrued interest and issued 7,857,000 shares upon settlement of the stock purchase contract based on the applicable market value, as defined in the purchase contract agreement associated with issuance of the Units. In 2016 , a secured promissory note of $15,400,000 was paid in full in connection with sale of the Radisson Hotel & Suites, for $130,000,000 . In 2016 , other indebtedness decreased principally as a result of selling Eleven, a 257 -unit multifamily project in Austin, for $60,150,000 and paying in full the associated debt of $23,936,000 . At year-end 2016 and 2015 , we have $1,633,000 and $8,267,000 in unamortized deferred fees which were deducted from our debt. In addition, at year-end 2016 and 2015 , unamortized deferred financing fees related to our senior credit facility included in other assets were $314,000 and $2,768,000 . Amortization of deferred financing fees was $3,598,000 in 2016 , $4,002,000 in 2015 and $3,845,000 in 2014 and is included in interest expense. Debt maturities during the next five years are: 2017 — $0 ; 2018 — $485,000 ; 2019 — $0 ; 2020 — $104,673,000 ; 2021 — $0 and thereafter — $5,200,000 .

Fair Value

Fair Value	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Fair Value	Fair Value Fair value is the exchange price that would be the amount received for an asset or paid to transfer a liability in an orderly transaction between market participants. In arriving at a fair value measurement, we use a fair value hierarchy based on three levels of inputs, of which the first two are considered observable and the last unobservable. The three levels of inputs used to establish fair value are the following: • Level 1 — Quoted prices in active markets for identical assets or liabilities; • Level 2 — Inputs other than Level 1 that are observable, either directly or indirectly, such as quoted prices for similar assets or liabilities; quoted prices in markets that are not active; or other inputs that are observable or can be corroborated by observable market data for substantially the full term of the assets or liabilities; and • Level 3 — Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. We elected not to use the fair value option for cash and cash equivalents, accounts receivable, other current assets, variable debt, accounts payable and other current liabilities. The carrying amounts of these financial instruments approximate their fair values due to their short-term nature or variable interest rates. We determine the fair value of fixed rate financial instruments using quoted prices for similar instruments in active markets. Information about our fixed rate financial instruments not measured at fair value follows: Year-End 2016 Year-End 2015 Carrying Amount Fair Value Carrying Amount Fair Value Valuation Technique (In thousands) Fixed rate debt $ (111,506 ) $ (109,789 ) $ (346,090 ) $ (321,653 ) Level 2 Non-financial assets measured at fair value on a non-recurring basis principally include real estate assets, oil and gas properties, assets held for sale, goodwill and intangible assets, which are measured for impairment. In 2016, we recognized non-cash impairment charges of $56,453,000 related to six non-core community development projects and two multifamily sites as a result of the review of our entire portfolio of assets and marketing these properties for sale, of which four non-core community development projects and one multifamily site were sold in 2016. We based our valuations primarily on executed purchase and sale agreements, current negotiations and letters of intent with expected buyers and third party broker price opinions. In 2016, we recognized non-cash impairment charges of $612,000 related to non-core oil and gas working interest properties that were sold in 2016. In 2015, we recognized non-cash impairment charges of $107,140,000 related to non-core oil and gas working interest assets classified as discontinued operations in 2016. These properties were primarily located in North Dakota, Nebraska and Kansas and were impaired primarily due to a significant decline in oil and gas prices and the likelihood these assets will be sold. The fair value of these properties was determined using Level 3 inputs and income valuation method based on estimated future commodity prices and our various operational assumptions. In instances where a third party bid was received for a combination of proved and unproved properties, an estimate of the allocation of bid prices was performed and fair value was adjusted accordingly. Included in proved oil and gas non-cash impairments were impairments associated with properties that were sold in fourth quarter 2015. In addition, in 2015 we recognized impairments of $57,691,000 for unproved leasehold interests as a result of continued decline in oil prices and our current plans to only allocate capital to these non-core assets to preserve values and optionality for ultimate sale. Fair value of certain unproved leasehold interests that were impaired were based on market comparables or where a third party bid was received for a combination of proved and unproved properties, an estimate of the allocation of fair value was performed which reduced the carrying value of these leasehold interests. In 2015, certain real estate assets were remeasured and reported at fair value due to events or circumstances that indicated the carrying value may not be recoverable. We determined estimated fair value based on the present value of future probability weighted cash flows expected from the sale of the long-lived asset or based on a third party appraisal of current value. As a result, we recognized non-cash asset impairment charges of $1,044,000 in 2015 associated with a residential development with golf course and country club property near Fort Worth which was sold in April 2015, one owned project near Atlanta where the remaining lots were sold in August 2015 and one owned entitled project in Atlanta. Non-financial assets measured at fair value on a non-recurring basis are as follows: Year-End 2016 Year-End 2015 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (In thousands) Non-financial Assets and Liabilities: Real estate $ — $ — $ — $ — $ — $ — $ 641 $ 641 Assets of discontinued operations $ — $ — $ — $ — $ — $ — $ 57,219 $ 57,219

Capital Stock

Capital Stock	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Capital Stock	Capital Stock In 2015, we accelerated the expiration date of our shareholder rights plan from December 11, 2017 to March 13, 2015, resulting in termination of the plan. Please read Note 12 — Net Income (Loss) per Share for information about shares of common stock that could be issued under our 3.75% convertible senior notes due 2020. Please read Note 17 — Share-Based and Long-Term Incentive Compensation for information about additional shares of common stock that could be issued under terms of our share-based compensation plans. Please read Note 21 — Subsequent Events for information about preferred stock purchase rights pursuant to our tax benefits preservation plan. At year-end 2016 , personnel of former affiliates held options to purchase 234,764 shares of our common stock. The options have a weighted average exercise price of $30.56 and will expire in February 2017. At year-end 2016 , the options have an aggregate intrinsic value of $0 . On December 15, 2016 , we issued 7,857,000 shares of our common stock upon settlement of the stock purchase contract related to the 6.00% tangible equity units. In 2016 , we repurchased 283,976 shares of our common stock for $3,537,000 . In 2014 , we repurchased 1,491,187 shares of our common stock for $24,595,000 . We have repurchased 3,777,308 shares of our common stock for $57,696,000 since we announced our 2009 strategic initiative of repurchasing up to 20 percent or up to 7,000,000 shares of our common stock.

Net Income (Loss) per Share

Net Income (Loss) per Share	12 Months Ended
	Dec. 31, 2016
Earnings Per Share [Abstract]
Net Income (Loss) per Share	Net Income (Loss) per Share Basic and diluted earnings (loss) per share are computed using the two-class method. The two-class method is an earnings allocation formula that determines net income per share for each class of common stock and participating security. We have determined that our 6.00% tangible equity units are participating securities. Per share amounts are computed by dividing earnings available to common shareholders by the weighted average shares outstanding during each period. In periods with a net loss, no such adjustment is made to earnings as the holders of the participating securities have no obligation to fund losses. The computations of basic and diluted earnings (loss) per share are as follows: For the Year 2016 2015 2014 (In thousands) Numerator: Continuing operations Net income (loss) from continuing operations $ 77,044 $ (26,241 ) $ 36,697 Less: Net (income) attributable to noncontrolling interest (1,531 ) (676 ) (505 ) Earnings (loss) available for diluted earnings per share $ 75,513 $ (26,917 ) $ 36,192 Less: Undistributed net income from continuing operations allocated to participating securities (13,493 ) — (6,586 ) Earnings (loss) from continuing operations available to common shareholders for basic earnings per share $ 62,020 $ (26,917 ) $ 29,606 Discontinued operations Net income (loss) from discontinued operations available for diluted earnings per share (16,865 ) (186,130 ) (19,609 ) Less: Undistributed net income from discontinued operations allocated to participating securities 3,014 — 3,569 Earnings (loss) from discontinued operations available to common shareholders for basic earnings per share (13,851 ) (186,130 ) (16,040 ) Denominator: Weighted average common shares outstanding — basic 34,546 34,266 35,317 Weighted average common shares upon conversion of participating securities (a) 7,515 — 7,857 Dilutive effect of stock options, restricted stock and equity-settled awards 273 — 422 Total weighted average shares outstanding — diluted 42,334 34,266 43,596 Anti-dilutive awards excluded from diluted weighted average shares outstanding 2,102 10,864 2,238 _____________________ (a) Our earnings per share calculation reflects the weighted average shares issuable upon settlement of the prepaid stock purchase contract component of our 6.00% tangible equity units, issued in 2013. On December 15, 2016, we issued 7,857,000 shares of our common stock upon settlement of the stock purchase contract related to the 6.00% tangible equity units. We intend to settle the principal amount of the Convertible Notes in cash upon conversion with any excess conversion value to be settled in shares of our common stock. Therefore, only the amount in excess of the par value of the Convertible Notes will be included in our calculation of diluted net income per share using the treasury stock method. As such, the Convertible Notes have no impact on diluted net income per share until the price of our common stock exceeds the conversion price of the Convertible Notes of $24.49 . The average price of our common stock in 2016 did not exceed the conversion price which resulted in no additional diluted outstanding shares.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes Income tax (expense) benefit from continuing operations consists of: For the Year 2016 2015 2014 (In thousands) Current tax provision: U.S. Federal $ (15,089 ) $ 6,740 $ (18,905 ) State and other (1,520 ) (418 ) (2,182 ) (16,609 ) 6,322 (21,087 ) Deferred tax provision: U.S. Federal 1,382 (38,262 ) 184 State and other (75 ) (3,191 ) 53 1,307 (41,453 ) 237 Income tax (expense) benefit $ (15,302 ) $ (35,131 ) $ (20,850 ) A reconciliation of the federal statutory rate to the effective income tax rate on continuing operations follows: For the Year 2016 2015 2014 Federal statutory rate (benefit) 35 % 35 % 35 % State, net of federal benefit — 10 2 Valuation allowance (19 ) 348 Noncontrolling interests (1 ) (3 ) — Installment sale ace adjustment 2 — — Stock based compensation — 5 — Charitable contributions — — (1 ) Oil and gas percentage depletion — (1 ) — Other — 1 — Effective tax rate 17 % 395 % 36 % Our 2016 effective tax rate includes a 19 percent benefit from a valuation allowance decrease due to a decrease in our deferred tax assets. Our 2015 effective tax rate includes a 348 percent detriment from the recording of a valuation allowance. Significant components of deferred taxes are: At Year-End 2016 2015 (In thousands) Deferred Tax Assets: Real estate $ 50,759 $ 69,594 Employee benefits 13,185 15,752 Net operating loss carryforwards 2,804 13,827 Oil and gas properties 1,672 5,510 AMT credits 5,900 3,620 Income producing properties 2,055 — Oil and gas percentage depletion carryforwards 3,478 3,616 Accruals not deductible until paid 552 911 Other assets — 139 Gross deferred tax assets 80,405 112,969 Valuation allowance (73,405 ) (97,068 ) Deferred tax asset net of valuation allowance 7,000 15,901 Deferred Tax Liabilities: Undeveloped land (1,359 ) (7,588 ) Convertible debt (5,035 ) (6,516 ) Income producing properties — (2,257 ) Timber (283 ) (577 ) Gross deferred tax liabilities (6,677 ) (16,938 ) Net Deferred Tax Asset (Liability) $ 323 $ (1,037 ) At year-end 2016, we had approximately $7,500,000 and $64,200,000 of federal and state net operating loss carryforwards. Approximately $7,500,000 of the federal and $2,400,000 of the state net operating loss carryforwards were from our acquisition of Credo at third quarter 2012 and are subject to certain limitations. If not utilized, the federal carryforwards will expire in 2031 and the state carryforwards will expire in 2017 to 2036 . We had approximately $9,200,000 of oil and gas percentage depletion carryforwards of which approximately $9,200,000 were a result of our acquisition of Credo and are subject to certain limitations. We had approximately $5,900,000 of AMT credit carryforwards. The percentage depletion and AMT credit carryforwards do not expire. Goodwill associated with our oil and gas and mineral resources enterprise are not deductible for income tax purposes. At year-end 2016 and 2015, we have provided a valuation allowance for our deferred tax asset of $73,405,000 and $97,068,000 respectively for the portion of the deferred tax asset that is more likely than not to be unrealizable. The decrease in the valuation allowance for the year was $23,663,000 . In determining our valuation allowance, we assessed available positive and negative evidence to estimate whether sufficient future taxable income would be generated to permit use of the existing deferred tax asset. A significant piece of objective evidence was the cumulative loss incurred over the three-year period ended December 31, 2016, principally driven by impairments of oil and gas and real estate assets. Such evidence limited our ability to consider other subjective evidence, such as our projected future taxable income. The amount of deferred tax asset considered realizable could be adjusted if negative evidence in the form of cumulative losses is no longer present and additional weight is given to subjective evidence, such as our projected future taxable income. We file income tax returns in the U.S. federal jurisdiction and in various state jurisdictions. We are no longer subject to U.S. federal and state income tax examinations for years before 2012. At year-end 2016, our unrecognized tax benefit for book purposes was $2,499,000 as a result of tax positions taken in the current year. We did not have any unrecognized tax benefits for the years 2015 and 2014. If the total amount of unrecognized tax benefits were recognized, it would result in a deferred tax asset and a corresponding increase in our valuation allowance. Therefore, such tax benefit would not affect the effective tax rate if recognized in the current year. We recognize interest accrued related to unrecognized tax benefits in income tax expense. In 2016 , 2015 and 2014 , we recognized no interest expense. At year-end 2016 and 2015 , we have no accrued interest or penalties.

Litigation and Environmental Co

Litigation and Environmental Contingencies	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Litigation and Environmental Contingencies	Litigation and Environmental Contingencies Litigation We are involved in various legal proceedings that arise from time to time in the ordinary course of doing business and believe that adequate reserves have been established for any probable losses. We do not believe that the outcome of any of these proceedings should have a significant adverse effect on our financial position, long-term results of operations or cash flows. It is possible, however, that charges related to these matters could be significant to our results or cash flows in any one accounting period. On October 4, 2014, James Huffman, a former director and CEO of CREDO Petroleum Corporation (Credo), which we acquired in 2012 and is now known as Forestar Petroleum Corporation, filed Huffman vs. Forestar Petroleum Corporation , Case Number 14CV33811, Civ. Div., Dist. Ct., City and County of Denver, Colorado, claiming entitlement to certain overriding royalty interests under a Credo compensation program. In third quarter 2016, we settled a portion of the case for $150,000 and accrued an additional $1,100,000 following an adverse jury verdict in Huffman's favor in regard to the portion of his claim related to past damages. In fourth quarter 2016, following additional rulings by the court, we accrued an additional $1,890,000 representing our estimate of future damages to which Huffman is entitled plus interest and costs, resulting in a total accrual of $2,990,000 at year-end 2016. The case was settled for the amount of accrual. Environmental Environmental remediation liabilities arise from time to time in the ordinary course of doing business, and we believe we have established adequate reserves for any probable losses that we can reasonably estimate. In 2016, we sold all but 25 of our 289 acres near Antioch, California, approximately 80 acres of which had not yet received a certificate of completion under the voluntary remediation program in which we were participating. The buyer of the former paper manufacturing sites assumed responsibility for environmental, remediation and monitoring activities, subject to limited exclusions, and obtained a $20,000,000 , ten year pollution legal liability insurance policy naming us as an additional insured. We have asset retirement obligations related to the abandonment and site restoration requirements that result from the acquisition, construction and development of oil and gas properties. We record the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. Accretion expense related to the asset retirement obligation and depletion expense related to capitalized asset retirement cost are included in cost of mineral resources and cost of oil and gas producing activities in discontinued operations on our consolidated statements of income (loss) and comprehensive income (loss). At year-end 2016 , our asset retirement obligation was $103,000 , which is included in liabilities held for sale. In addition, at year-end 2016, we have accrued $1,155,000 related to potential environmental liabilities to plug and abandon certain oil and gas wells in Wyoming which is included in liabilities of discontinued operations.

Commitments and Other Contingen

Commitments and Other Contingencies	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Other Contingencies	Commitments and Other Contingencies We lease facilities and equipment under non-cancelable long-term operating lease agreements. In addition, we have various obligations under other office space and equipment leases of less than one year. Rent expense on facilities and equipment was $1,923,000 in 2016 , $3,872,000 in 2015 and $2,617,000 in 2014 . Future minimum rental commitments under non-cancelable operating leases having a remaining term in excess of one year are: 2017 — $2,267,000 ; 2018 — $1,593,000 ; 2019 — $298,000 ; 2020 — $182,000 ; 2021 — $62,000 ; and thereafter — $0 . We have one year remaining on groundwater leases of about 20,000 acres. At year-end 2016 , the remaining contractual obligation for these groundwater leases is $494,000 . We lease approximately 22,000 square feet of office space in Austin, Texas, which we occupy as our corporate headquarters. The remaining contractual obligation for this lease is $1,983,000 . We also lease office space in other locations in support of our business operations. The total remaining contractual obligations for these leases is $1,925,000 . We may provide performance bonds and letters of credit on behalf of certain ventures that would be drawn on due to failure to satisfy construction obligations as general contractor or for failure to timely deliver streets and utilities in accordance with local codes and ordinances. Unallocated Severance-related Costs In connection with the departures of our former CEO and CFO in September 2015, we recorded severance-related charges of $3,314,000 which are included in general and administrative expense on our consolidated statements of income (loss) and comprehensive income (loss). We paid $2,732,000 of these severance-related charges in fourth quarter 2015 with the remainder paid in 2016. Non-core Assets Restructuring Costs In connection with key initiatives to reduce costs across our entire organization and divest non-core assets, in 2016, we incurred and paid severance costs related to workforce reductions of $1,422,000 in our real estate segment, $164,000 in our other segment and $486,000 in unallocated general and administrative expenses. In addition, we offered retention bonuses to certain key personnel provided they remained our employees through completion of sale transactions. We expensed retention bonus costs over the estimated retention periods. These restructuring costs are included in other operating expense. The following table summarizes activity related to liabilities associated with our restructuring activities in 2016: Employee-Related Costs Retention Bonuses Total (In thousands) Balance at year-end 2015 $ (1,049 ) $ — $ (1,049 ) Additions (2,072 ) (832 ) (2,904 ) Payments 3,121 832 3,953 Balance at year-end 2016 $ — $ — $ —

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Segment Information	Segment Information We manage our operations through three business segments: real estate, mineral resources and other. Real estate secures entitlements and develops infrastructure on our lands for single-family residential and mixed-use communities, and manages our undeveloped land, commercial and income producing properties, which consist of three projects and one multifamily site. Mineral resources manages our owned mineral interests. Other manages our timber, recreational leases and water resource initiatives. At year-end 2016 we have divested substantially all of our oil and gas working interest properties. As a result of this significant change in our operations, we have reported the results of operations and financial position of these assets as discontinued operations for all periods presented. In addition, we changed the name of the oil and gas segment to mineral resources to reflect the strategic shift from oil and gas working interest investments to owned mineral interests. We also changed the name of the other natural resources segment to other. We evaluate performance based on segment earnings (loss) before unallocated items and income taxes. Segment earnings (loss) consist of operating income, equity in earnings (loss) of unconsolidated ventures, gain on sales of assets, interest income on loans secured by real estate and net (income) loss attributable to noncontrolling interests. Items not allocated to our business segments consist of general and administrative expense, share-based and long-term incentive compensation, gain on sale of strategic timberland, interest expense, loss on extinguishment of debt and other corporate non-operating income and expense. The accounting policies of the segments are the same as those described in Note 1 — Summary of Significant Accounting Policies . Our revenues are derived from our U.S. operations and all of our assets are located in the U.S. In 2016 , 2015 and 2014 , no single customer accounted for more than 10 percent of our total revenues, other than the customer associated with the sale of our Midtown Cedar Hill multifamily project in 2015. Real Estate Mineral Resources Other Items Not Allocated to Segments Total (In thousands) For the year or at year-end 2016 Revenues $ 190,273 $ 5,076 $ 1,965 $ — $ 197,314 Depreciation, depletion and amortization 976 145 352 7,772 9,245 Equity in earnings of unconsolidated ventures 5,778 173 172 — 6,123 Income (loss) before taxes from continuing operations attributable to Forestar Group Inc. 121,420 3,327 (4,625 ) (29,307 ) (a) 90,815 Total assets (b) 403,062 38,907 11,531 279,694 733,194 Investment in unconsolidated ventures 77,611 — — — 77,611 Capital expenditures 5,783 — 299 56 6,138 For the year or at year-end 2015 Revenues $ 202,830 $ 9,094 $ 6,652 $ — $ 218,576 Depreciation, depletion and amortization 7,605 383 540 8,166 16,694 Equity in earnings of unconsolidated ventures 15,582 275 151 — 16,008 Income (loss) before taxes from continuing operations attributable to Forestar Group Inc. 67,678 4,230 (608 ) (63,086 ) (a) 8,214 Total assets (b) 691,238 39,469 19,106 117,466 867,279 Investment in unconsolidated ventures 82,453 — — — 82,453 Capital expenditures 13,644 59 745 242 14,690 For the year or at year-end 2014 Revenues $ 213,112 $ 15,690 $ 9,362 $ — $ 238,164 Depreciation, depletion and amortization 3,741 684 497 8,035 12,957 Equity in earnings of unconsolidated ventures 8,068 586 31 — 8,685 Income (loss) before taxes from continuing operations attributable to Forestar Group Inc. 96,906 9,116 5,499 (54,479 ) (a) 57,042 Investment in unconsolidated ventures 65,005 — — — 65,005 Capital expenditures 28,980 2,240 5,817 616 37,653 _____________________ (a) Items not allocated to segments consist of: For the Year 2016 2015 2014 (In thousands) General and administrative expense $ (18,274 ) $ (24,802 ) $ (21,229 ) Share-based and long-term incentive compensation expense (4,425 ) (4,474 ) (3,417 ) Gain on sale of assets 48,891 — — Interest expense (19,985 ) (34,066 ) (30,286 ) Loss on extinguishment of debt, net (35,864 ) — — Other corporate non-operating income 350 256 453 $ (29,307 ) $ (63,086 ) $ (54,479 ) (b) Total assets excludes assets of discontinued operations of $14 and $104,967 in 2016 and 2015.

Share-Based and Long-Term Incen

Share-Based and Long-Term Incentive Compensation	12 Months Ended
	Dec. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share-Based and LongTerm incentive Compensation	Share-Based and Long-Term Incentive Compensation Share-based and long-term incentive compensation expense consists of: For the Year 2016 2015 2014 (In thousands) Cash-settled awards $ 717 $ (3,127 ) $ (3,710 ) Equity-settled awards 2,444 5,026 5,168 Restricted stock 22 (8 ) (25 ) Stock options 854 2,355 1,984 Total share-based compensation $ 4,037 $ 4,246 $ 3,417 Deferred cash 388 228 — $ 4,425 $ 4,474 $ 3,417 Share-based and long-term incentive compensation expense is included in: For the Year 2016 2015 2014 (In thousands) General and administrative $ 3,323 $ 2,451 $ 1,001 Other operating 1,102 2,023 2,416 $ 4,425 $ 4,474 $ 3,417 Excluded from share-based compensation expense in the table above are fees earned by directors in the amount of $725,000 for 2016, $1,203,000 for 2015 and $906,000 for 2014 for which they elected to defer payment until retirement in the form of share-settled units. These expenses are included in general and administrative expense on our consolidated statements of income (loss) and comprehensive income (loss). Share-Based Compensation The fair value of awards granted to retirement-eligible employees and expensed at the date of grant was $600,000 in 2016 , $517,000 in 2015 and $760,000 in 2014 . Unrecognized share-based compensation expense related to non-vested equity-settled awards and stock options was $1,878,000 at year-end 2016 . The weighted average period over which this amount will be recognized is estimated to be one year. We did not capitalize any share-based compensation in 2016 , 2015 or 2014 . In 2016 and 2015 , we issued 300,491 and 288,089 shares out of our treasury stock associated with vesting of stock-based awards or exercise of stock options, net of 25,082 and 51,521 shares withheld having a value of $222,000 and $762,000 for payroll taxes in connection with vesting of stock-based awards or exercise of stock options which are reflected in financing activities in our consolidated statements of cash flows. A summary of awards granted under our 2007 Stock Incentive Plan follows: Cash-settled awards Cash-settled awards granted to our employees in the form of restricted stock units or stock appreciation rights generally vest over three to four years from the date of grant and generally provide for accelerated vesting upon death, disability or if there is a change in control. Cash-settled stock appreciation rights have a ten -year term, generally become exercisable ratably over four years and provide for accelerated or continued vesting upon retirement, death, disability or if there is a change in control. Stock appreciation rights were granted with an exercise price equal to the market value of our stock on the date of grant. Cash-settled awards granted to our directors in the form of restricted stock units are fully vested at the time of grant and payable upon retirement. The following table summarizes the activity of cash-settled restricted stock unit awards in 2016 : Equivalent Units Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 117 $16.00 Granted — — Vested (41 ) 18.84 Forfeited (34 ) 13.83 Non-vested at end of period 42 14.98 The weighted average grant date fair value of cash-settled restricted stock unit awards was $13.26 per unit for 2015 and $18.96 per unit for 2014. The fair value of cash-settled restricted stock unit awards settled was $1,195,000 in 2016, $2,469,000 in 2015, and $2,286,000 in 2014. The aggregate current value of non-vested awards is $555,000 at year-end 2016 based on a year-end stock price of $13.30 . The following table summarizes the activity of cash-settled stock appreciation rights in 2016 : Rights Outstanding Weighted Average Exercise Price Weighted Average Remaining Contractual Term Aggregate Intrinsic Value (Current Value Less Exercise Price) (In thousands) (Per share) (In years) (In thousands) Balance at beginning of period 487 $12.97 4 $404 Granted — — Exercised (52 ) 9.29 Forfeited (61 ) 16.12 Balance at end of period 374 12.97 3 773 Exercisable at end of period 345 12.87 3 773 The intrinsic value of cash-settled stock appreciation rights settled was $154,000 in 2016 , $206,000 in 2015 and $1,181,000 in 2014 . The fair value of accrued cash-settled awards at year-end 2016 and year-end 2015 were $1,758,000 and $3,757,000 and is included in other liabilities in our consolidated balance sheets. Equity-settled awards Equity-settled awards granted to our employees include restricted stock units (RSU), which vest after three years from the date of grant, market-leveraged stock units (MSU), which vest after three years from date of grant and performance stock units (PSU), which generally vest after three years from the date of grant if certain performance goals are met. Equity settled awards in the form of restricted stock units granted to our directors are fully vested at time of grant and settled upon retirement. The following table summarizes the activity of equity-settled awards in 2016 : Equivalent Units Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 631 $ 18.25 Granted 313 9.04 Vested (281 ) 15.12 Forfeited (108 ) 17.91 Non-vested at end of period 555 14.70 In 2016, we granted 313,000 RSU awards at market value of the stock on the date of the grant. In 2015 and 2014, we granted 234,000 and 86,000 MSU awards. These awards will be settled in common stock based upon our stock price performance over three years from the date of grant. The number of shares to be issued could range from a high of 351,000 shares if our stock price increases by 50 percent or more, to 117,000 shares if our stock price decreases by 50 percent , or could be zero if our stock price decreases by more than 50 percent , the minimum threshold performance. We estimate the grant date fair value of MSU awards using a Monte Carlo simulation pricing model and the following assumptions: For the Year 2015 2014 Expected stock price volatility 32.9 % 42.2 % Risk-free interest rate 1.0 % 0.7 % Expected dividend yield — % — % Weighted average grant date fair value of MSU awards (per unit) $ 15.11 $ 20.38 The weighted average grant date fair value of equity-settled awards (RSU, MSU and PSU) per unit in 2016, 2015 and 2014 was $9.04 , $12.99 and $19.18 . The fair value of equity-settled awards settled was $2,884,478 , $4,451,000 and $3,119,000 in 2016, 2015 and 2014. Unrecognized share-based compensation expense related to non-vested equity-settled awards is $1,106,000 at year-end 2016 . The weighted average period over which this amount will be recognized is estimated to be one year . Restricted stock awards Restricted stock awards generally vest over three years , typically if we achieve a minimum one percent annualized return on assets over such three -year period. The following table summarizes the activity of restricted stock awards in 2016 : Restricted Shares Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 4 $ 20.55 Granted — — Vested (4 ) 20.55 Forfeited — — Non-vested at end of period — — The fair value of our restricted stock awards settled in 2016, 2015 and 2014 was $44,000 , $88,000 and $341,000 . Stock options Stock options have a ten -year term, generally become exercisable ratably over four years and provide for accelerated or continued vesting upon retirement, death, disability or if there is a change in control. In 2016 and 2015, options were granted with an exercise price equal to the market value of our stock on the date of grant. In the first quarter of 2016, stock options were issued to each of two new directors to acquire 20,000 shares of common stock of which 6,500 shares vest on the first and second anniversary of the date of grant and the remaining 7,000 shares vest on the third anniversary of the date of grant. Expense associated with annual restricted stock units and non-qualified stock options to our board of directors is included in share-based compensation expense. The following table summarizes the activity of stock option awards in 2016 : Options Outstanding Weighted Average Exercise Price Weighted Average Remaining Contractual Term Aggregate Intrinsic Value (Current Value Less Exercise Price) (In thousands) (Per share) (In years) (In thousands) Balance at beginning of period 2,171 $ 19.56 5 $ 156 Granted 53 9.98 Exercised (35 ) 9.29 Forfeited (353 ) 20.03 Balance at end of period 1,836 19.39 5 449 Exercisable at end of period 1,597 20.25 4 261 We estimate the grant date fair value of stock options that do not have a market condition using the Black-Scholes option pricing model and the following assumptions: For the Year 2016 2015 Expected stock price volatility 39.5 % 45.6 % Risk-free interest rate 1.5 % 1.8 % Expected life of options (years) 6 6 Expected dividend yield — % — % Weighted average grant date fair value of options (per share) $ 8.60 $ 6.51 We determine the expected life using the simplified method which utilizes the midpoint between the vesting period and the contractual life of the awards. The expected stock price volatility assumption was determined using a blend of historical and implied volatility. Stock option awards granted in third quarter 2015 in connection with management promotions have a ten -year term, vest ratably over three years and are exercisable only when our stock price exceeds $17.50 per share. We estimated the fair value of these options with market conditions using Monte Carlo simulation pricing model and the following assumptions: Expected stock price volatility 61.4 % Risk-free interest rate 2.2 % Expected dividend yield — % Weighted average grant date fair value of options (per share) $ 7.87 The fair value of vested stock options was $0 in 2016 , $0 in 2015 and $21,000 in 2014 . The intrinsic value of options exercised was $61,000 in 2016 , $0 in 2015 and $568,000 in 2014 . Unrecognized share-based compensation expense related to non-vested stock options is $772,000 at year-end 2016 . The weighted average period over which this amount will be recognized is estimated to be two years . Pre-Spin Awards Certain of our employees participated in Temple-Inland’s share-based compensation plans. In conjunction with our 2007 spin-off, these awards were equitably adjusted into separate awards of the common stock of Temple-Inland and the spin-off entities. No pre-spin awards were exercised in 2016. The intrinsic value of pre-spin awards exercised was $0 in 2016, $24,000 in 2015 and $352,000 in 2014. Pre-spin stock option awards to our employees to purchase our common stock have a ten -year term, generally become exercisable ratably over four years and provide for accelerated or continued vesting upon retirement, death, disability or if there is a change in control. At year-end 2016 , there were 17,000 pre-spin awards outstanding and exercisable on our stock with a weighted average exercise price of $30.56 and weighted average remaining term of less than one year . Long-Term Incentive Compensation In 2016, we granted $620,000 of long-term incentive compensation in the form of deferred cash compensation. The 2016 deferred cash awards vest annually over two years, and the 2015 deferred cash awards vest after three years. Both awards provide for accelerated vesting upon retirement, disability, death, or if there is a change in control. Expense associated with deferred cash awards is recognized ratably over the vesting period or earlier based on retirement eligibility. The accrued liability was $539,000 at year-end 2016 and is included in other liabilities.

Retirement Plans

Retirement Plans	12 Months Ended
	Dec. 31, 2016
Compensation and Retirement Disclosure [Abstract]
Retirement Plans	Retirement Plans Our defined contribution retirement plans include a 401(k) plan, which is funded, and a supplemental plan for certain employees, which is unfunded. The expense of our defined contribution retirement plans was $978,000 in 2016 , $1,060,000 in 2015 and $1,338,000 in 2014 . The unfunded liability for our supplemental plan was $334,000 at year-end 2016 and $802,000 at year-end 2015 and is included in other liabilities.

Supplemental Oil and Gas Disclo

Supplemental Oil and Gas Disclosures (Unaudited)	12 Months Ended
	Dec. 31, 2016
Extractive Industries [Abstract]
Supplemental Oil and Gas Disclosures (Unaudited)	Supplemental Oil and Gas Disclosures (Unaudited) The following unaudited information regarding our oil and gas reserves has been prepared and is presented pursuant to requirements of the Securities and Exchange Commission (SEC) and the Financial Accounting Standards Board (FASB). As of year-end 2016, we have divested substantially all of our oil and gas working interest properties. As a result of this significant change in our operations, we have reported the results of operations and financial position of these assets as discontinued operations within our consolidated statements of income (loss) and comprehensive income (loss) and consolidated balance sheets for all periods presented. However, all information presented in this unaudited supplemental oil and gas disclosures footnote includes all oil and gas reserve estimates and results of operations. We lease our mineral interests, principally in Texas and Louisiana, to third-party entities for the exploration and production of oil and gas. When we lease our mineral interests, we may negotiate a lease bonus payment and we retain a royalty interest and may take an additional participation in production, including a working interest in which we pay a share of the costs to drill, complete and operate a well and receive a proportionate share of the production revenues. We engaged independent petroleum engineers, Netherland, Sewell & Associates, Inc., to assist in preparing estimates of our proved oil and gas reserves, all of which are located in the U.S., and future net cash flows as of year-end 2016 , 2015 and 2014 . These estimates were based on the economic and operating conditions existing at year-end 2016 , 2015 and 2014 . Proved developed reserves are those quantities of petroleum from existing wells and facilities, which by analysis of geosciences and engineering data, can be estimated with reasonable certainty to be commercially recoverable, from a given date forward for known reservoirs and under defined economic conditions, operating methods and government regulations. SEC rules require disclosure of proved reserves using the twelve-month average beginning-of-month price (which we refer to as the average price) for the year. These same average prices also are used in calculating the amount of (and changes in) future net cash inflows related to the standardized measure of discounted future net cash flows. For 2016 , 2015 and 2014 , the average spot price per barrel of oil based on the West Texas Intermediate price is $42.75 , $50.28 and $94.99 and the average price per MMBTU of gas based on the Henry Hub spot is $2.48 , $2.59 and $4.35 . All prices were then adjusted for quality, transportation fees and differentials. The process of estimating proved reserves and future net cash flows is complex involving decisions and assumptions in evaluating the available engineering and geologic data and prices for oil and gas and the cost to produce these reserves and other factors, many of which are beyond our control. As a result, these estimates are imprecise and should be expected to change as future information becomes available. These changes could be significant. In addition, this information should not be construed as being the current fair market value of our proved reserves. Estimated Quantities of Proved Oil and 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 2013 5,824 13,630 Revisions of previous estimates 608 293 Extensions and discoveries 2,191 774 Acquisitions 85 31 Sales (105 ) (218 ) Production (931 ) (1,861 ) 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 Our share of ventures accounted for using the equity method: Year-end 2013 — 2,332 Revisions of previous estimates — (382 ) Production — (199 ) 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 Total consolidated and our share of equity method ventures: Year-end 2014 Proved developed reserves 5,269 12,599 Proved undeveloped reserves 2,403 1,801 Total Year-end 2014 7,672 14,400 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 _____________________ (a) Includes natural gas liquids (NGLs). We do not have any estimated reserves of synthetic oil, synthetic gas or products of other non-renewable natural resources that are intended to be upgraded into synthetic oil and gas. At year-end 2016, estimated quantities of proved oil and gas reserves are related to our owned mineral interests which are classified as assets held for sale. In 2016, we sold oil and gas wells located primarily in Oklahoma, Kansas, Nebraska and North Dakota. Our net reserves for those properties as of year-end 2015 less our share of 2016 production were 4,155,000 barrels of oil, 305,000 barrels of NGL, and 3,756,000 Mcf of gas. Oklahoma properties sold were mainly mature gas wells. Kansas and Nebraska produce oil from the Lansing/Kansas City formation. The North Dakota oil wells produce from the Bakken/Three Forks formation. In 2015, oil and gas properties having reserves consisting of approximately 704,000 barrels of oil and 1,223,000 Mcf of gas located primarily in the Texas Panhandle and Bakken/Three Forks formations were sold. Due to the significant decline in oil and gas prices during 2015, net negative revisions of previous estimates were 855,000 barrels of oil and 1,995,000 Mcf of gas. At year-end 2015, we had no barrels of oil equivalent (BOE) of proved undeveloped (PUD) reserves based on our plan to exit non-core oil and gas working interest assets compared with 2,703,000 BOE of PUD reserves at year-end 2014. In 2014, increases in extensions and discoveries of 2,191,000 barrels were primarily associated with new reserves in the Bakken/Three Forks formations. An estimated 694,000 barrels of these extensions and discoveries were associated with new producing wells while a further 913,000 barrels of proved undeveloped reserves were added during 2014. Approximately 105,000 barrels of oil and 218,000 Mcf of gas reserves located primarily in Oklahoma were sold during the year. We realized a net positive revision of previous estimates of 608,000 barrels which is primarily driven by improved drilling results in the Bakken/Three Forks formation yielding higher average estimated ultimate recoverable quantities of proved reserves per well. In 2015 and 2014 , reserve additions from new wells drilled and completed during the year are shown for both consolidated entities and ventures accounted for using the equity method under extensions and discoveries. There were no new well additions in 2016 , 36 new well additions in 2015 and 106 new well additions in 2014 . Capitalized Costs Relating to Oil and Gas Producing Activities 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 2016 2015 (In thousands) Consolidated entities: Unproved oil and gas properties $ 374 $ 19,441 Proved oil and gas properties 5,159 119,414 Total costs 5,533 138,855 Less accumulated depreciation, depletion and amortization (4,751 ) (58,242 ) $ 782 $ 80,613 We have not capitalized any costs for our share in ventures accounted for using the equity method. Costs Incurred in Oil and Gas Property Acquisition, Exploration and Development Costs incurred in oil and gas property acquisition, exploration and development activities, whether capitalized or expensed, follows: For the Year 2016 2015 2014 (In thousands) Consolidated entities: Acquisition costs Proved properties $ — $ — $ 2,001 Unproved properties 15 4,832 25,666 Exploration costs 21 17,922 39,399 Development costs 537 27,609 40,277 $ 573 $ 50,363 $ 107,343 We have not incurred any costs for our share in ventures accounted for using the equity method. In 2015, acquisition of leasehold interests, exploration expenses, and development costs have decreased as a result of our increased focus on exiting and selling our leasehold working interests. Standardized Measure of Discounted Future Net Cash Flows 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 2016 2015 2014 (In thousands) Consolidated entities: Future cash inflows $ 24,304 $ 216,588 $ 665,657 Future production and development costs (2,988 ) (93,623 ) (271,735 ) Future income tax expenses (3,926 ) (22,218 ) (106,002 ) Future net cash flows 17,390 100,747 287,920 10% annual discount for estimated timing of cash flows (7,077 ) (33,951 ) (124,079 ) Standardized measure of discounted future net cash flows $ 10,313 $ 66,796 $ 163,841 Our share in ventures accounted for using the equity method: Future cash inflows $ 2,010 $ 2,283 $ 6,186 Future production and development costs (216 ) (245 ) (664 ) Future income tax expenses (537 ) (774 ) (2,098 ) Future net cash flows 1,257 1,264 3,424 10% annual discount for estimated timing of cash flows (585 ) (562 ) (1,649 ) Standardized measure of discounted future net cash flows $ 672 $ 702 $ 1,775 Total consolidated and our share of equity method ventures $ 10,985 $ 67,498 $ 165,616 Future net cash flows were computed using prices used in estimating proved oil and gas reserves, year-end costs, and statutory tax rates (adjusted for tax deductions) that relate to proved oil and gas reserves. 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 2013 $ 135,553 $ 1,300 $ 136,853 Changes resulting from: Net change in sales prices and production costs (1,064 ) 1,571 507 Net change in future development costs 1,308 — 1,308 Sales of oil and gas, net of production costs (63,192 ) (787 ) (63,979 ) Net change due to extensions and discoveries 58,228 — 58,228 Net change due to acquisition of reserves 2,778 — 2,778 Net change due to divestitures of reserves (5,804 ) — (5,804 ) Net change due to revisions of quantity estimates 15,303 (343 ) 14,960 Previously estimated development costs incurred 15,497 — 15,497 Accretion of discount 18,067 210 18,277 Net change in timing and other 4,198 115 4,313 Net change in income taxes (17,031 ) (291 ) (17,322 ) Aggregate change for the year 28,288 475 28,763 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 Results of Operations for Oil and Gas Producing Activities Our royalty interests are contractually defined and based on a percentage of production at prevailing market prices. We receive our percentage of production in cash. Similarly, for operating properties our working interests and the associated net revenue interests are contractually defined and we pay our proportionate share of the capital and operating costs to develop and operate the well and we market our share of the production. Our revenues fluctuate based on changes in the market prices for oil and gas, the decline in production from existing wells, and other factors affecting oil and gas exploration and production activities, including the cost of development and production. Information about the results of operations of our oil and gas interests follows: For the Year 2016 2015 2014 (In thousands) Consolidated entities Revenues $ 10,111 $ 51,553 $ 82,919 Production costs (4,392 ) (19,820 ) (19,727 ) Exploration costs (124 ) (11,864 ) (17,416 ) Depreciation, depletion, amortization (2,157 ) (28,774 ) (29,442 ) Non-cash impairment of proved oil and gas properties and unproved leasehold interests (612 ) (164,831 ) (32,665 ) Oil and gas administrative expenses (8,700 ) (11,700 ) (17,000 ) Accretion expense (56 ) (144 ) (121 ) Income tax (expense) benefit (20 ) 14,717 13,398 Results of operations (5,950 ) (170,863 ) (20,054 ) Our share in ventures accounted for using the equity method: Revenues $ 284 $ 428 $ 786 Production costs (76 ) (102 ) (105 ) Oil and gas administrative expenses (35 ) (51 ) (95 ) Income tax (expense) benefit — 21 (235 ) Results of operations $ 173 $ 296 $ 351 Total results of operations $ (5,777 ) $ (170,567 ) $ (19,703 ) Production costs represent our share of oil and gas production severance taxes, and lease operating expenses. Exploration costs principally represent exploratory dry hole costs, geological and geophysical and seismic study costs.

Summary of Quarterly Results of

Summary of Quarterly Results of Operations (Unaudited)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Summary of Quarterly Results of Operations (Unaudited)	Summary of Quarterly Results of Operations (Unaudited) Summarized quarterly financial results for 2016 and 2015 follows: First Quarter (a) Second Quarter (a) Third Quarter (a) Fourth Quarter (a) (In thousands, except per share amounts) 2016 Total revenues $ 37,618 $ 47,992 $ 47,207 $ 64,497 Gross profit (loss) 18,579 (24,953 ) 17,403 17,352 Operating income (loss) 13,590 69,528 6,256 50,980 Equity in earnings of unconsolidated ventures 47 188 3,637 2,251 Income from continuing operations before taxes attributable to Forestar Group Inc. 5,992 26,591 7,163 51,069 Income (loss) from discontinued operations, net of taxes (8,216 ) (2,048 ) (7,164 ) 563 Net income (loss) attributable to Forestar Group Inc. (4,376 ) 9,614 9,665 43,745 Net income (loss) per share — basic Continuing operations $ 0.11 $ 0.28 $ 0.40 $ 1.03 Discontinued operations $ (0.24 ) $ (0.05 ) $ (0.17 ) $ 0.01 Net income (loss) per share — basic $ (0.13 ) $ 0.23 $ 0.23 $ 1.04 Net income (loss) per share — diluted Continuing operations $ 0.09 0.28 0.40 $ 1.02 Discontinued operations $ (0.19 ) (0.05 ) (0.17 ) $ 0.01 Net income (loss) per share — diluted $ (0.10 ) 0.23 0.23 $ 1.03 2015 Total revenues $ 37,374 $ 43,625 $ 32,185 $ 105,392 Gross profit (loss) 18,012 21,060 12,879 46,655 Operating income (loss) (3,424 ) 5,919 (8,482 ) 29,929 Equity in earnings of unconsolidated ventures 3,045 5,584 2,909 4,470 Income from continuing operations before taxes attributable to Forestar Group Inc. (8,204 ) 3,382 (13,711 ) 26,747 Income (loss) from discontinued operations, net of taxes (2,719 ) (36,992 ) (106,937 ) (39,482 ) Net loss attributable to Forestar Group Inc. (8,158 ) (34,507 ) (164,216 ) (6,166 ) Net income (loss) per share — basic Continuing operations $ (0.16 ) $ 0.07 $ (1.67 ) $ 0.97 Discontinued operations $ (0.08 ) $ (1.08 ) $ (3.12 ) $ (1.15 ) Net income (loss) per share — basic $ (0.24 ) $ (1.01 ) $ (4.79 ) $ (0.18 ) Net income (loss) per share — diluted Continuing operations $ (0.16 ) $ 0.06 $ (1.67 ) $ 0.79 Discontinued operations $ (0.08 ) $ (0.87 ) $ (3.12 ) $ (0.93 ) Net income (loss) per share — diluted $ (0.24 ) $ (0.81 ) $ (4.79 ) $ (0.14 ) _____________________ (a) Non-cash impairment charges related to real estate, water assets and unproved leasehold interests and proved oil and gas properties included in our quarterly financial results are as follows: First Quarter Second Quarter Third Fourth (In thousands) 2016 Continuing operations $ — $ 48,826 $ 7,627 $ 3,874 Discontinued operations $ — $ 612 $ — $ — 2015 Continuing operations $ 504 $ 225 $ — $ 315 Discontinued operations $ 7 $ 45,938 $ 81,240 $ 37,646

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2016
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events On January 5, 2017, we entered into a tax benefits preservation plan (the “Plan”) with Computershare Trust Company, N.A., as rights agent, and our Board of Directors declared a dividend distribution of one right (a “Right”) for each outstanding share of common stock, par value $1.00 per share, to stockholders of record at the close of business on January 17, 2017. Each Right is governed by the terms of the Plan and entitles the registered holder to purchase from the Company a unit consisting of one one-thousandth of a share of Series B Junior Participating Preferred Stock, par value $0.01 per share, at a purchase price of $50 per unit, subject to adjustment. The Plan is intended to help protect our tax attributes, such as built in losses and other tax attributes, by deterring any person from becoming a “5-percent shareholder” (as defined in Section 382 of the Internal Revenue Code of 1986, as amended, and the Treasury Regulations promulgated thereunder). On February 17, 2017, we entered into a Purchase and Sale Agreement with Mineral Resource Partners, LLC, whereby we sold substantially all of our remaining oil and gas assets for $85,600,000 , of which $75,000,000 was received at closing. The balance of the purchase price is being held in a third-party escrow account pending completion of (a) title review, and (b) transfer of certain mineral interests owned by a venture in which the Company is a member (Venture Minerals). Prorations of operating revenues and expenses will be made utilizing an effective date of January 1, 2017. This agreement also contains representations, warranties and indemnities customary for oil and gas industry entity and asset sale and purchase transactions, and includes purchase price adjustment provisions, within certain parameters, relating to title and failure or inability to transfer the Venture Minerals. In first quarter 2017, we expect to recognize a gain on sale of approximately $82,400,000 , of which $10,600,000 will be deferred until verification of title for non-producing fee minerals in Texas and Louisiana, transfer of certain mineral interests owned by a venture in which the Company is a member and release of the escrowed funds. In addition, the Company expects to incur a non-cash charge of $37,900,000 related to oil and gas enterprise goodwill that is impaired due to the sale of substantially all of the Company's remaining oil and gas assets.

Consolidated Real Estate and Ac

Consolidated Real Estate and Accumulated Depreciation	12 Months Ended
	Dec. 31, 2016
SEC Schedule III, Real Estate and Accumulated Depreciation Disclosure [Abstract]
Consolidated Real Estate and Accumulated Depreciation	Forestar Group Inc. Schedule III — Consolidated Real Estate and Accumulated Depreciation Year-End 2016 (In thousands) Initial Cost to Company Costs Capitalized Subsequent to Acquisition Gross Amount Carried at End of Period Description Encumbrances Land Buildings & Improvements Improvements less Cost of Sales and Other Carrying Costs (a) Land & Land Improvements Buildings & Improvements Total Accumulated Depreciation Date of Construction Date Acquired Entitled, Developed, and Under Development Projects: ARIZONA Pima County Dove Mountain $ 5,860 $ 3 $ 5,863 $ 5,863 2015 CALIFORNIA Contra Costa County San Joaquin River 12,225 (10,558 ) 1,667 1,667 (b) COLORADO Douglas County Pinery West 7,308 3,791 11,099 11,099 2006 2006 Cielo 3,933 2,645 6,578 6,578 2016 Weld County Buffalo Highlands 3,001 (295 ) 2,706 2,706 2006 2005 Johnstown Farms 2,749 4,189 $ 100 7,038 7,038 2002 2002 Stonebraker 3,878 (1,786 ) 2,092 2,092 2005 2005 GEORGIA Cobb County West Oaks 1,669 1,543 3,212 3,212 2015 2015 Paulding County Harris Place 265 (111 ) 154 154 2012 Seven Hills 2,964 1,162 13 4,139 4,139 2012 NORTH CAROLINA Cabbarrus County Moss Creek 1,254 101 1,355 1,355 2016 Mecklenburg County Walden 12,085 2,279 87 14,451 14,451 2016 2015 SOUTH CAROLINA Lancaster County Ansley Park 5,089 1,594 6,683 6,683 2015 York County Habersham 3,877 1,128 421 5,426 5,426 2014 2013 Initial Cost to Company Costs Capitalized Subsequent to Acquisition Gross Amount Carried at End of Period Description Encumbrances Land Buildings & Improvements Improvements less Cost of Sales and Other Carrying Costs (a) Land & Land Improvements Buildings & Improvements Total Accumulated Depreciation Date of Construction Date Acquired TENNESEE Williamson County Morgan Farms $ 6,841 $ (1,808 ) $ 88 $ 5,121 $ 5,121 2013 2013 Scales Farmstead 3,575 9,319 389 13,283 13,283 2015 Weatherford Estates 856 374 138 1,368 1,368 2015 2014 Wilson County Beckwith Crossing 1,294 2,397 161 3,852 3,852 2015 2014 TEXAS Bastrop County Hunter’s Crossing 3,613 5,226 8,839 8,839 2001 2001 Bexar County Cibolo Canyons 17,305 26,397 1,203 44,905 44,905 2004 1986 Calhoun County Caracol 8,603 (8,025 ) 578 578 2006 2006 Collin County Lakes of Prosper 8,951 (3,005 ) 348 6,294 6,294 2012 Parkside 2,177 (4 ) 183 2,356 2,356 2014 2013 Timber Creek 7,282 9,862 17,144 17,144 2007 2007 Village Park 4,772 (4,720 ) 52 52 2012 Comal County Oak Creek Estates 1,921 685 22 2,628 2,628 2006 2005 Dallas County Stoney Creek 12,822 327 443 13,592 13,592 2007 2007 Denton County Lantana 27,673 (11,242 ) 529 16,960 16,960 2000 1999 River's Edge 1,227 436 1,663 1,663 2014 The Preserve at Pecan Creek 5,855 (1,387 ) 47 4,515 4,515 2006 2005 Fort Bend County Summer Lakes 4,269 374 78 4,721 4,721 2013 2012 Summer Park 4,804 (2,557 ) 17 2,264 2,264 2013 2012 Willow Creek Farms 486 3,479 (1,187 ) 2,292 2,292 2012 2012 Harris County Barrington 8,950 (7,483 ) 1,467 1,467 2011 City Park 3,946 (2,243 ) 229 1,932 1,932 2002 2001 Imperial Forest 5,345 (957 ) 4 4,392 4,392 2015 2014 Initial Cost to Company Costs Capitalized Subsequent to Acquisition Gross Amount Carried at End of Period Description Encumbrances Land Buildings & Improvements Improvements less Cost of Sales and Other Carrying Costs (a) Land & Land Improvements Buildings & Improvements Total Accumulated Depreciation Date of Construction Date Acquired Hays County Arrowhead Ranch $ 12,856 $ 9,204 $ 233 $ 22,293 $ 22,293 2015 2007 Tarrant County Summer Creek Ranch 2,887 (1,377 ) 1,510 1,510 2012 The Bar C Ranch 1,365 842 197 2,404 2,404 2012 Other 5,222 (276 ) 25 4,971 4,971 Total Entitled, Developed, and Under Development Projects $ 486 $ 234,047 $ — $ 24,857 $ 4,955 $ 263,859 $ — $ 263,859 $ — Undeveloped Land and land in entitlement: CALIFORNIA Los Angeles County Land In Entitlement Process $ 3,950 $ 20,838 $ 24,788 $ 24,788 1997 GEORGIA Cherokee County Undeveloped Land 80 80 80 (b) TEXAS Bexar County Undeveloped Land 2,548 2,548 2,548 (b) Montgomery County Undeveloped Land 5 5 5 (b) Other Undeveloped Land 1,723 1,723 1,723 (b) Total Undeveloped Land and Land in Entitlement $ — $ 4,030 $ — $ 25,114 $ — $ 29,144 $ — $ 29,144 $ — Total $ 486 $ 238,077 $ — $ 49,971 $ 4,955 $ 293,003 $ — $ 293,003 $ — ____________________ (a) We do not capitalize carrying costs until development begins. (b) The acquisition date is not available. Reconciliation of real estate: 2016 2015 2014 (In thousands) Balance at beginning of year $ 618,844 $ 607,133 $ 547,530 Amounts capitalized 89,780 124,633 214,184 Amounts retired or adjusted (415,621 ) (112,922 ) (154,581 ) Balance at close of period $ 293,003 $ 618,844 $ 607,133 Reconciliation of accumulated depreciation: 2016 2015 2014 (In thousands) Balance at beginning of year $ (32,129 ) $ (31,377 ) $ (28,066 ) Depreciation expense (816 ) (6,810 ) (3,319 ) Amounts retired or adjusted 32,945 6,058 8 Balance at close of period $ — $ (32,129 ) $ (31,377 )

Summary of Significant Accoun29

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation Our consolidated financial statements include the accounts of Forestar Group Inc., all subsidiaries, ventures and other entities in which we have a controlling interest. We account for our investment in other entities in which we have significant influence over operations and financial policies using the equity method (we recognize our share of the entities’ income or loss and any preferential returns and treat distributions as a reduction of our investment). We eliminate all material intercompany accounts and transactions. Noncontrolling interests in consolidated pass-through entities are recognized before income taxes. We prepare our financial statements in accordance with generally accepted accounting principles in the United States, which require us to make estimates and assumptions about future events. Actual results can, and probably will, differ from those we currently estimate. Examples of significant estimates include those related to allocating costs to real estate, measuring long-lived assets for impairment, oil and gas revenue accruals, capital expenditure and lease operating expense accruals associated with our oil and gas production activities, oil and gas reserves and depletion of our oil and gas properties. At year-end 2016, we have divested substantially all of our oil and gas working interest properties. As a result of this significant change in our operations, we have reported the results of operations and financial position of these assets as discontinued operations within the consolidated statements of income (loss) and comprehensive income (loss) and consolidated balance sheets for all periods presented. In addition, in second quarter 2016, we changed the name of the oil and gas segment to mineral resources to reflect the strategic shift from oil and gas working interest investments to owned mineral interests. We also changed the name of the other natural resources segment to other.
Cash and Cash Equivalents	Cash and Cash Equivalents Cash and cash equivalents include cash and other short-term instruments with original maturities of three months or less. At year-end 2016 and 2015 , restricted cash was $275,000 and $200,000 and is included in other assets.
Cash Flows	Cash Flows The consolidated statements of cash flows for 2016, 2015 and 2014 reflect cash flows from both continuing and discontinued operations. Expenditures for the acquisition and development of single-family and multifamily real estate that we intend to develop for sale are classified as operating activities. Expenditures for the acquisition and development of properties to be held and operated, investment in oil and gas properties and equipment, and business acquisitions are classified as investing activities. Our accrued capital expenditures for unproved leasehold acquisitions and drilling and completion costs at year-end 2016 and 2015 were $834,000 and $7,033,000 and are included in liabilities of discontinued operations in our consolidated balance sheets. These oil and gas property additions will be reflected as cash used for investing activities in the period the accrued payables are settled.
Capitalized Software	Capitalized Software We capitalize purchased software costs as well as the direct internal and external costs associated with software we develop for our own use. We amortize these capitalized costs using the straight-line method over estimated useful lives generally ranging from three to five years . The carrying value of capitalized software was $52,000 at year-end 2016 and $237,000 at year-end 2015 and is included in other assets. The amortization of these capitalized costs was $155,000 in 2016 , $996,000 in 2015 and $1,067,000 in 2014 and is included in general and administrative and operating expenses.
Environmental and Asset Retirement Obligations	Environmental and Asset Retirement Obligations We recognize environmental remediation liabilities on an undiscounted basis when environmental assessments or remediation are probable and we can reasonably estimate the cost. We adjust these liabilities as further information is obtained or circumstances change. Our asset retirement obligations are related to the abandonment and site restoration requirements that result from the acquisition, construction and development of oil and gas working interest properties, which we have divested substantially all at year-end 2016. We record the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. Accretion expense related to the asset retirement obligation and depletion expense related to capitalized asset retirement costs are included in cost of mineral resources and in discontinued operations on our consolidated statements of income (loss) and comprehensive income (loss). Our asset retirement obligations are recorded in liabilities held for sale at year-end 2016 and in other liabilities and liabilities of discontinued operations at year-end 2015.
Fair Value Measurements	Fair Value Measurements Financial instruments for which we did not elect the fair value option include cash and cash equivalents, accounts and notes receivables, other assets, long-term debt, accounts payable and other liabilities. With the exception of long-term notes receivable and debt, the carrying amounts of these financial instruments approximate their fair values due to their short-term nature or variable interest rates.
Goodwill and Other Intangible Assets	Goodwill and Other Intangible Assets We record goodwill when the purchase price of a business acquisition exceeds the estimated fair value of net identified tangible and intangible assets acquired. We do not amortize goodwill or other indefinite lived intangible assets. Instead, we measure these assets for impairment based on the estimated fair values at least annually or more frequently if impairment indicators exist. We perform the annual impairment measurement in the fourth quarter of each year. Intangible assets with finite useful lives are amortized over their estimated useful lives. In 2016 , we performed our annual goodwill impairment evaluation and concluded that goodwill related to our mineral interest assets was not impaired at year-end 2016 as the estimated fair value exceeded the carrying value. On February 17, 2017, we sold substantially all of the Company's remaining oil and gas assets for $85,600,000 . Please read Note 21—Subsequent Events for additional information about these items. In addition, we performed our annual goodwill impairment evaluation and concluded that goodwill related to our central Texas water assets was impaired at year-end 2016 as the estimated fair value exceeded the carrying value. We recorded a $3,874,000 non-cash impairment charge as a result of entering into an agreement to sell these assets. At year-end 2016, our central Texas water assets are classified as held for sale.
Income Taxes	Income Taxes We provide deferred income taxes using current tax rates for temporary differences between the financial accounting carrying value of assets and liabilities and their tax accounting carrying values. We recognize and value income tax exposures for the various taxing jurisdictions where we operate based on laws, elections, commonly accepted tax positions, and management estimates. We include tax penalties and interest in income tax expense. We provide a valuation allowance for any deferred tax asset that is not likely to be recoverable in future periods. When we believe a tax position is supportable but the outcome uncertain, we include the item in our tax return but do not recognize the related benefit in our provision for taxes. Instead, we record a reserve for unrecognized tax benefits, which represents our expectation of the most likely outcome considering the technical merits and specific facts of the position. Changes to liabilities are only made when an event occurs that changes the most likely outcome, such as settlement with the relevant tax authority, expiration of statutes of limitations, changes in tax law, or recent court rulings.
Owned Mineral Interests	Owned Mineral Interests When we lease our mineral interests to third-party exploration and production entities, we retain a royalty interest and may take an additional participation in production, including a working interest. At year-end 2016, mineral interests and any remaining oil and gas working interests are included in assets held for sale.
Oil and Gas Properties (Discontinued Operations)	Oil and Gas Properties (Discontinued Operations) We use the successful efforts method of accounting for our oil and gas producing activities. Costs to acquire mineral interests leased, costs to drill and complete development of oil and gas wells and related asset retirement costs are capitalized. Costs to drill exploratory wells are capitalized pending determination of whether the wells have proved reserves and if determined incapable of producing commercial quantities of oil and gas these costs are expensed as dry hole costs. At year-end 2016 , we have no capitalized exploratory well costs pending determination of proved reserves. Exploration costs include dry hole costs, geological and geophysical costs, expired unproved leasehold costs and seismic studies, and are expensed as incurred. Production costs incurred to maintain wells and related equipment are charged to expense as incurred. Depreciation and depletion of producing oil and gas properties is calculated using the units-of-production method. Proved developed reserves are used to compute unit rates for unamortized tangible and intangible drilling and completion costs. Proved reserves are used to compute unit rates for unamortized acquisition of proved leasehold costs. Unit-of-production amortization rates are revised whenever there is an indication of the need for revision but at least once a year and those revisions are accounted for prospectively as changes in accounting estimates. Impairment of Oil and Gas Properties We evaluate our oil and gas properties, including facilities and equipment, for impairment whenever events or changes in circumstances indicate that the carrying value of an asset may not be recoverable. We estimate the expected undiscounted future cash flows of our oil and gas properties and compare such undiscounted future cash flows to the carrying amount of the oil and gas properties to determine if the carrying amount is recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, we will adjust the carrying amount of the oil and gas properties to fair value. The factors used to determine fair value are subject to our judgment and expertise and include, but are not limited to, recent sales prices of comparable properties, the present value of future cash flows, net of estimated operating and development costs using estimates of proved reserves, future commodity pricing, future production estimates, anticipated capital expenditures, and various discount rates commensurate with the risk and current market conditions associated with realizing the expected cash flows projected. Because of the uncertainty inherent in these factors, we cannot predict when or if future impairment charges for proved properties will be recorded. The assessment of unproved leasehold properties to determine any possible impairment requires significant judgment. We assess our unproved leasehold properties periodically for impairment on a property-by-property basis based on remaining lease terms, drilling results or future plans to develop acreage. Impairment expense for proved and unproved oil and gas properties are included in cost of mineral resources and cost of oil and gas producing activities in discontinued operations.
Operating Leases	Operating Leases We occupy office space in various locations under operating leases. The lease agreements may contain rent escalation clauses, construction allowances and/or contingent rent provisions. We expense operating leases ratably over the shorter of the useful life or the lease term. For scheduled rent escalation clauses, we recognize the base rent expense on a straight-line basis and record the difference between the recognized rent expense and the amounts payable under the lease as deferred lease credits included in other liabilities in the consolidated balance sheets. Deferred lease credits are amortized over the lease term. For construction allowances, we record leasehold improvement assets included in property and equipment in the consolidated balance sheets amortized over the shorter of their economic lives or the lease term. The related deferred lease credits are amortized as a reduction of rent expense over the lease term.
Property and Equipment	Property and Equipment We carry property and equipment at cost less accumulated depreciation. We capitalize the cost of significant additions and improvements, and we expense the cost of repairs and maintenance. We capitalize interest costs incurred on major construction projects. We depreciate these assets using the straight-line method over their estimated useful lives
Real Estate	Real Estate We carry real estate at the lower of cost or fair value less cost to sell. We capitalize interest costs once development begins, and we continue to capitalize throughout the development period. We also capitalize infrastructure, improvements, amenities, and other development costs incurred during the development period. We determine the cost of real estate sold using the relative sales value method. When we sell real estate from projects that are not finished, we include in the cost of real estate sold estimates of future development costs through completion, allocated based on relative sales values. These estimates of future development costs are reevaluated at least annually, with any adjustments being allocated prospectively to the remaining units available for sale. We receive cash deposits from home builders for purchases of vacant developed lots from community development projects. These earnest money deposits are released to the home builders as lots are developed and sold. Income producing properties are carried at cost less accumulated depreciation computed using the straight-line method over their estimated useful lives. We have agreements with utility or improvement districts, principally in Texas, whereby we agree to convey to the districts water, sewer and other infrastructure-related assets we have constructed in connection with projects within their jurisdiction. The reimbursement for these assets ranges from 70 to 90 percent of allowable cost as defined by the district. The transfer is consummated and we receive payment when the districts have a sufficient tax base to support funding of their bonds. The cost we incur in constructing these assets is included in capitalized development costs, and upon collection, we remove the assets from capitalized development costs. We provide an allowance to reflect our past experiences related to claimed allowable development costs. Impairment of Real Estate Long-Lived Assets We review real estate long-lived assets held for use for impairment when events or circumstances indicate that their carrying value may not be recoverable. Impairment exists if the carrying amount of the long-lived asset is not recoverable from the undiscounted cash flows expected from its use and eventual disposition. We determine the amount of the impairment loss by comparing the carrying value of the long-lived asset to its estimated fair value. In the absence of quoted market prices, we determine estimated fair value generally based on the present value of future probability weighted cash flows expected from the sale of the long-lived asset. Non-cash impairment charges related to our owned and consolidated real estate assets are included in cost of real estate sales and other.
Revenue	Revenue Real Estate We recognize revenue from sales of real estate when a sale is consummated, the buyer’s initial investment is adequate, any receivables are probable of collection, the usual risks and rewards of ownership have been transferred to the buyer, and we do not have significant continuing involvement with the real estate sold. If we determine that the earnings process is not complete, we defer recognition of any gain until earned. We recognize revenue from hotel room sales and other guest services when rooms are occupied and other guest services have been rendered. We recognize rental revenues from our multifamily properties when earned in accordance with the terms of the respective leases on a straight-line basis for the period of occupancy. We recognize construction revenues on multifamily projects that we develop as a general contractor. Construction revenues are recognized as costs are incurred plus fixed fee earned. We are reimbursed for costs paid to subcontractors plus we may earn a development and construction management fee on multifamily projects we develop, both of which are included in commercial and income producing properties revenue. On multifamily projects where our fee is based on a fixed fee plus guaranteed maximum price contract, any cost overruns incurred during construction, as compared to the original budget, will reduce the net fee generated on these projects. Any excess cost overruns estimated over the net fee generated are recognized in the period in which they become evident. At year-end 2016, we were not a general contractor on any of the multifamily projects currently under construction and we do not anticipate to be a general contractor on any new multifamily projects as we determined multifamily was non-core and we would not be making any new investments in this business. We exclude from revenue amounts we collect from utility or improvement districts related to the conveyance of water, sewer and other infrastructure related assets. We also exclude from revenue amounts we collect for timber sold on land being developed. These proceeds reduce capitalized development costs. We exclude from revenue amounts we collect from customers that represent sales tax or other taxes that are based on the sale. These amounts are included in other accrued expenses until paid. Oil and Gas Working Interest Revenues (Discontinued Operations) We recognize revenue as oil and gas is produced and sold. There are a significant amount of oil and gas properties which we do not operate and, therefore, revenue is typically recorded in the month of production based on an estimate of our share of volumes produced and prices realized. We obtain the most current available production data from the operators and price indices for each well to estimate the accrual of revenue. Obtaining production data on a timely basis for some wells is not feasible; therefore we utilize past production receipts and estimated sales price information to estimate accrual of working interest revenue on all other non-operated wells each month. Revisions to such estimates are recorded as actual results become known. We review accounts receivable periodically and reduce the carrying amount by a valuation allowance that reflects our best estimate of the amount that may not be collectible. A majority of our sales are made under contractual arrangements with terms that are considered to be usual and customary in the oil and gas industry. The contracts are for periods of up to five years with prices determined upon a percentage of pre-determined and published monthly index price. The terms of these contracts have not had an effect on how we recognize revenue. Mineral Resources We recognize revenue from mineral bonus payments when we have received an executed agreement with the exploration company transferring the rights to any oil or gas it may find and requiring drilling be done within a specified period, the payment has been collected, and we have no obligation to refund the payment. We recognize revenue from delay rentals received if drilling has not started within the specified period and when the payment has been collected. We recognize revenue from mineral royalties and non-working interests when the minerals have been delivered to the buyer, the value is determinable, and we are reasonably sure of collection. Other We recognize revenue from timber sales upon passage of title, which occurs at delivery; when the price is fixed and determinable; and we are reasonably sure of collection. We recognize revenue from recreational leases on the straight-line basis over the lease term. We recognize revenue from the sale of water rights or groundwater reservation agreements upon receipt of an executed agreement and payment has been collected and all conditions to the agreement have been met and we have no further performance obligations to meet. The water delivery revenues will be recognized as water is being delivered and metered at the delivery point.
Share-Based Compensation	Share-Based Compensation We use the Black-Scholes option pricing model for stock options, Monte Carlo simulation pricing model for market-leveraged stock units and for stock options with market conditions, grant date fair value for equity-settled awards and period-end fair value for cash-settled awards. We expense share-based awards ratably over the vesting period or earlier based on retirement eligibility.
Timber	Timber We carry timber at cost less the cost of timber cut. We expense the cost of timber cut based on the relationship of the timber carrying value to the estimated volume of recoverable timber multiplied by the amount of timber cut. We include the cost of timber cut in cost of other. We determine the estimated volume of recoverable timber using statistical information and other data related to growth rates and yields gathered from physical observations, models and other information gathering techniques. Changes in yields are generally due to adjustments in growth rates and similar matters and are accounted for prospectively as changes in estimates. We capitalize reforestation costs incurred in developing viable seedling plantations (up to two years from planting), such as site preparation, seedlings, planting, fertilization, insect and wildlife control, and herbicide application. We expense all other costs, such as property taxes and costs of forest management personnel, as incurred. Once the seedling plantation is viable, we expense all costs to maintain the viable plantations, such as fertilization, herbicide application, insect and wildlife control, and thinning, as incurred. We own about 19,000 acres of non-core timberland and undeveloped land, in Georgia and Texas. The non-cash cost of timber cut and sold is $63,000 in 2016 , $250,000 in 2015 and $371,000 in 2014 and is included in depreciation, depletion and amortization in our consolidated statements of cash flows.

New and Pending Accounting Pr30

New and Pending Accounting Pronouncements (Policies)	12 Months Ended
	Dec. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
New and Pending Accounting Pronouncements	New and Pending Accounting Pronouncements Adoption of New Accounting Standards In April 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2015-03, Interest – Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs, as part of its initiative to reduce complexity in accounting standards. To simplify presentation of debt issuance costs, the amendments in this update require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. In August 2015, the FASB issued ASU 2015-15, Interest-Imputation of Interest (Subtopic 835-30), Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements - Amendments to SEC Paragraphs Pursuant to Staff Announcement at June 18, 2015 EITF Meeting (SEC Update), which allows an entity to defer and present debt issuance costs as an asset and subsequently amortize the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. The updated standards are effective for financial statements issued for annual and interim periods beginning after December 15, 2015. We adopted ASU 2015-03 in first quarter 2016 and prior period amounts have been reclassified to conform to the current period presentation. As of December 31, 2015, $8,267,000 of debt issuance costs were reclassified in the consolidated balance sheets from other assets to debt. The adoption did not impact our consolidated financial position, results of operations or cash flows. As permitted under this guidance, we will continue to present debt issuance costs associated with revolving-debt agreements as other assets. In February 2015, the FASB issued ASU 2015-02, Consolidation: Amendments to the Consolidation Analysis (Topic 810) , requiring entities to evaluate whether they should consolidate certain legal entities. All legal entities are subject to reevaluation under the revised consolidation model. The revised consolidation model: (1) modifies the evaluation of whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities, (2) eliminates the presumption that a general partner should consolidate a limited partnership, (3) affects the consolidation analysis of reporting entities that are involved with VIEs, and (4) provides a scope exception from consolidation guidance for reporting entities with interests in certain legal entities. The updated standard is effective for financial statements issued for annual and interim periods beginning after December 15, 2015. The adoption of this guidance, which was applied retrospectively, had no impact to our consolidated financial statements. In January 2015, the FASB issued ASU 2015-01, Income Statement - Extraordinary and Unusual Items (Subtopic 225-20), which eliminates the concept of extraordinary items from U.S. GAAP. The updated standard is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015. Early adoption is permitted, provided that the guidance is applied from the beginning of the fiscal year of adoption. The adoption of this guidance had no impact on our financial statements and related disclosures. Pending Accounting Standards In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , requiring an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The updated standard will replace most existing revenue recognition guidance in U.S. GAAP when it becomes effective and permits the use of either the retrospective or cumulative effect transition method. Early adoption is not permitted. The updated standard becomes effective for annual and interim periods beginning after December 15, 2017. The guidance permits two methods of adoption: retrospectively to each prior reporting period presented (full retrospective method), or retrospectively with the cumulative effect initially applying the guidance recognized at the date of initial application (the cumulative catch-up transition method). We currently anticipate adopting the standard using the cumulative catch-up transition method. We anticipate this standard will not have a material impact on our consolidated financial statements. While we are continuing to assess all potential impacts of the standard, we expect revenue related to lot and tract sales to remain substantially unchanged. Due to the complexity of certain of our real estate sale transactions, the revenue recognition treatment required under the standard will be dependent on contract-specific terms, and may vary in some instances from recognition at the time of the sale closing. In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842). This ASU requires lessees to put most leases on their balance sheets but recognize expenses on their income statements in a manner that is similar to today's accounting. This guidance also eliminates today's real estate-specific provisions for all entities. For lessors, the guidance modifies the classification criteria and the accounting for sales-type and direct financing leases. This guidance is effective in 2019, and interim periods within that year. Early adoption is permitted. The new leases standard requires a modified retrospective transition approach for all leases existing at, or entered into after, the date of initial application, with an option to use certain transition relief. We are currently evaluating the effect the updated standard will have on our financial position and disclosures. In March 2016, the FASB issued ASU 2016-09, Compensation-Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting , as part of its simplification initiative. The areas for simplification in this update involve several aspects of the accounting for share-based payment transactions, including income tax consequences, classification of awards as either equity or liabilities, and the classification on the statement of cash flows. The updated standard becomes effective for annual and interim periods beginning after December 31, 2016. We are currently evaluating the effect that the updated standard will have on our earnings, financial position and disclosures, but we do not expect it to have a material impact on our consolidated financial statements. In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230) , in order to address eight specific cash flow issues with the objective of reducing the existing diversity in practice. The updated standard is effective for financial statements issued for annual periods beginning after December 15, 2017 and interim periods within those fiscal years with early adoption permitted. We are currently evaluating the effect that the updated standard will have on our earnings, financial position and disclosures, but we do not expect it to have a material effect on our consolidated financial statements. In November, 2016, the FASB issued ASU 2016-18, Statement of Cash Flows (Topic 230). This ASU requires that a statement of cash flow explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash investments. This standard is effective for fiscal years beginning after December 15, 2017. The adoption of ASU 2016-18 will modify our current disclosures and reclassifications relating to the consolidated statements of cash flows, but we do not expect it to have a material effect on our consolidated financial statements.

Summary of Significant Accoun31

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Schedule of Change in Asset Retirement Obligation	The following summarizes the changes in asset retirement obligations: Year-End 2016 2015 (In thousands) Beginning balance $ 1,758 $ 1,807 Additions 6 65 Oil and gas working interest property dispositions (1,610 ) (119 ) Liabilities settled (107 ) (139 ) Accretion expense 56 144 $ 103 $ 1,758
Schedule of Property, Plant and Equipment	We depreciate these assets using the straight-line method over their estimated useful lives as follows: Estimated Year-End Useful Lives 2016 2015 (In thousands) Buildings and building improvements 10 to 40 years $ 2,700 $ 4,044 Property and equipment 2 to 10 years 4,957 12,230 7,657 16,274 Less: accumulated depreciation (4,541 ) (5,542 ) $ 3,116 $ 10,732

Real Estate (Tables)

Real Estate (Tables)	12 Months Ended
	Dec. 31, 2016
Real Estate [Abstract]
Real Estate	Real estate consists of: Year-End 2016 Year-End 2015 Carrying Value Accumulated Depreciation Net Carrying Value Carrying Value Accumulated Depreciation Net Carrying Value (In thousands) Entitled, developed and under development projects $ 263,859 $ — $ 263,859 $ 352,141 $ — $ 352,141 Undeveloped land (includes land in entitlement) 29,144 — 29,144 98,181 — 98,181 Commercial Radisson Hotel & Suites (a) — — — 62,889 (29,268 ) 33,621 Income producing properties Eleven (a) — — — 53,896 (2,861 ) 51,035 Dillon (a) — — — 19,987 — 19,987 Music Row (a) — — — 9,947 — 9,947 Downtown Edge (a) — — — 12,706 — 12,706 West Austin (b) — — — 9,097 — 9,097 $ 293,003 $ — $ 293,003 $ 618,844 $ (32,129 ) $ 586,715 _________________________ (a) Sold in 2016. (b) Classified as assets held for sale at year-end 2016.

Investment in Unconsolidated 33

Investment in Unconsolidated Ventures (Tables)	12 Months Ended
	Dec. 31, 2016
Equity Method Investments and Joint Ventures [Abstract]
Summarized Balance Sheet Information	Combined summarized balance sheet information for our ventures accounted for using the equity method follows: Venture Assets Venture Borrowings (a) Venture Equity Our Investment At Year-End 2016 2015 2016 2015 2016 2015 2016 2015 (In thousands) 242, LLC (b) $ 26,503 $ 26,687 $ 1,107 $ — $ 23,136 $ 24,877 $ 10,934 $ 11,766 CL Ashton Woods, LP (c) 2,653 7,654 — — 2,198 6,084 1,107 3,615 CL Realty, LLC 8,048 7,872 — — 7,899 7,662 3,950 3,831 CREA FMF Nashville LLC (b) 56,081 57,820 37,446 50,845 17,091 4,291 4,923 3,820 Elan 99, LLC 49,652 34,192 36,238 14,587 13,100 15,838 11,790 14,255 FMF Littleton LLC 70,282 52,376 44,446 22,347 23,798 24,370 6,128 6,270 FMF Peakview LLC — 48,869 — 30,485 — 16,828 — 3,447 FOR/SR Forsyth LLC 10,672 6,500 1,568 — 8,990 6,500 8,091 5,850 HM Stonewall Estates, Ltd (c) 852 2,842 — — 852 2,842 477 1,294 LM Land Holdings, LP (c) 25,538 31,984 3,477 7,728 20,945 22,751 9,685 9,664 MRECV DT Holdings LLC 4,155 4,215 — — 4,144 4,215 3,729 3,807 MRECV Edelweiss LLC 3,484 2,237 — — 3,484 2,237 3,358 2,029 MRECV Juniper Ridge LLC 4,156 3,006 — — 4,156 3,006 3,741 2,730 MRECV Meadow Crossing II LLC 2,492 728 — — 2,491 728 2,242 655 Miramonte Boulder Pass, LLC 10,738 12,627 4,006 5,869 5,265 5,474 5,330 5,349 Temco Associates, LLC 4,368 5,284 — — 4,253 5,113 2,126 2,557 Other ventures (d) — 4,174 — 2,242 — 1,922 — 1,514 $ 279,674 $ 309,067 $ 128,288 $ 134,103 $ 141,802 $ 154,738 $ 77,611 $ 82,453
Summarized Income Statement Information	Combined summarized income statement information for our ventures accounted for using the equity method follows: Revenues Earnings (Loss) Our Share of Earnings (Loss) For the Year 2016 2015 2014 2016 2015 2014 2016 2015 2014 (In thousands) 242, LLC (b) $ 5,835 $ 20,995 $ 5,612 $ 1,259 $ 9,588 $ 2,951 $ 668 $ 4,919 $ 1,514 CL Ashton Woods, LP (c) 2,870 9,820 5,431 914 3,881 1,748 1,332 5,000 2,471 CL Realty, LLC 567 856 1,573 237 424 1,068 119 212 534 CREA FMF Nashville LLC (b) (d) 4,955 1,227 — (1,420 ) (1,696 ) (163 ) 1,103 (1,696 ) (163 ) Elan 99, LLC 1,392 — — (2,739 ) (49 ) (87 ) (2,465 ) (44 ) (78 ) FMF Littleton LLC 3,116 120 — (571 ) (367 ) (239 ) (143 ) (92 ) (60 ) FMF Peakview LLC 939 2,057 4 (248 ) (1,116 ) (410 ) (50 ) (223 ) (83 ) FOR/SR Forsyth LLC — — (65 ) — (58 ) — HM Stonewall Estates, Ltd. (c) 2,112 3,990 1,728 832 1,881 613 361 952 248 LM Land Holdings, LP (c) 10,001 10,956 21,980 7,288 8,251 15,520 2,458 3,342 4,827 MRECV DT Holdings LLC 495 — 477 167 429 — MRECV Edelweiss LLC 416 — 409 151 368 137 MRECV Juniper Ridge LLC 379 — 380 106 342 — MRECV Meadow Crossing II LLC 267 — — 220 — — 198 — — Miramonte Boulder Pass, LLC 4,923 — (399 ) (250 ) (200 ) (125 ) PSW Communities, LP — 29,986 — — 2,688 (86 ) — 1,169 (76 ) TEMCO Associates, LLC 1,344 9,485 2,155 440 2,358 494 220 1,179 247 Other ventures 6,519 36,237 3,960 2,105 33,303 3,879 1,441 1,278 (696 ) $ 46,130 $ 125,729 $ 42,443 $ 9,119 $ 59,320 $ 25,288 $ 6,123 $ 16,008 $ 8,685 _____________________ (a) Total includes current maturities of $89,756,000 at year-end 2016 , of which $78,557,000 is non-recourse to us, and $39,590,000 at year-end 2015 , of which $29,691,000 is non-recourse to us. (b) Includes unamortized deferred gains on real estate contributed by us to ventures. We recognize deferred gains as income as real estate is sold to third parties. Deferred gains of $1,457,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2016 . (c) Includes unrecognized basis difference of $259,000 which is reflected as an increase of our investment in unconsolidated ventures at year-end 2016 . This difference between estimated fair value of the equity investment and our capital account within the respective ventures at closing will be accreted as income or expense over the life of the investment and included in our share of earnings (loss) from the respective ventures. (d) Our share of venture earnings in 2016 includes reallocation of prior year cumulative losses incurred by the venture as a result of equity contribution by the venture partner in 2016.

Goodwill and Other Intangible34

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Carrying Value of Goodwill and Other Intangible Assets	Carrying value of goodwill and other intangible assets follows: Year-End 2016 2015 (In thousands) Goodwill $ 37,900 $ 41,774 Identified intangibles, net — 1,681 $ 37,900 $ 43,455

Held for Sale (Tables)

Held for Sale (Tables)	12 Months Ended
	Dec. 31, 2016
Discontinued Operations and Disposal Groups [Abstract]
Assets and Liabilities of Properties Held for Sale	The major classes of assets and liabilities of the properties held for sale at year-end 2016 are as follows: At Year-End 2016 Assets Held for Sale: (In thousands) Real estate $ 19,931 Timber 1,682 Other intangible assets 1,681 Oil and gas properties and equipment, net 782 Property and equipment, net 6,301 $ 30,377 Liabilities Held for Sale: Other liabilities 103 $ 103

Discontinued Operations (Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2016
Discontinued Operations and Disposal Groups [Abstract]
Summarized Results from Discontinued Operations	Summarized results from discontinued operations were as follows: For the Year 2016 2015 2014 Revenues $ 5,862 $ 43,845 $ 68,610 Cost of oil and gas producing activities (6,578 ) (221,402 ) (94,581 ) Other operating expenses (7,754 ) (10,363 ) (14,357 ) Loss from discontinued operations before income taxes $ (8,470 ) $ (187,920 ) $ (40,328 ) Gain (loss) on sale of assets before income taxes (13,664 ) (706 ) 8,526 Income tax benefit 5,269 2,496 12,193 Loss from discontinued operations, net of taxes $ (16,865 ) $ (186,130 ) $ (19,609 )
Disposal Groups, Including Discontinued Operations	The major classes of assets and liabilities of discontinued operations at year-end 2016 and 2015 are as follows: At Year-End 2016 2015 (In thousands) Assets of Discontinued Operations: Receivables, net of allowance for bad debt $ 6 $ 4,632 Oil and gas properties and equipment, net — 79,733 Goodwill and other intangible assets — 19,673 Prepaid expenses 8 96 Other assets — 833 $ 14 $ 104,967 Liabilities of Discontinued Operations: Accounts payable $ 67 $ 342 Accrued property taxes — 259 Other accrued expenses 5,228 8,924 Other liabilities — 1,667 $ 5,295 $ 11,192
Significant Operation and Investing Activities of DIscontinued Operations	Significant operating activities and investing activities of discontinued operations are as follows: For the Year 2016 2015 2014 (In thousands) Operating activities: Asset impairments $ 612 $ 105,337 $ 15,535 Dry hole and unproved leasehold impairment charges — 67,639 29,528 Loss (gain) on sale of assets 13,664 706 (8,526 ) Depreciation, depletion and amortization 2,202 28,391 28,758 $ 16,478 $ 202,073 $ 65,295 Investing activities: Oil and gas properties and equipment $ (579 ) $ (49,717 ) $ (101,145 ) Acquisition of oil and gas properties — — (1,100 ) Proceeds from sales of assets 77,105 17,800 17,660 $ 76,526 $ (31,917 ) $ (84,585 )

Receivables (Tables)

Receivables (Tables)	12 Months Ended
	Dec. 31, 2016
Receivables [Abstract]
Receivables	Receivables consist of: At Year-End 2016 2015 (In thousands) Funds held by qualified intermediary for potential 1031 like-kind exchange $ — $ 14,703 Other receivables and accrued interest 1,505 2,218 Other loans secured by real estate, average interest rate of 5.86% at year-end 2016 and 11.31% at year-end 2015 7,452 2,130 8,957 19,051 Allowance for bad debts (26 ) (26 ) $ 8,931 $ 19,025

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Debt	Debt consists of: At Year-End 2016 2015 (In thousands) 8.50% senior secured notes due 2022 5,200 224,647 3.75% convertible senior notes due 2020, net of discount 104,673 104,719 6.00% tangible equity units, net — 8,666 Secured promissory notes — average interest rates of 3.42% at year-end 2015 — 15,400 Other indebtedness due through 2018 at variable and fixed interest rates ranging from 5.0% to 5.50% 485 28,083 $ 110,358 $ 381,515

Fair Value (Tables)

Fair Value (Tables)	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Information About Our Fixed Rate Financial Instruments Not Measured at Fair Value	Information about our fixed rate financial instruments not measured at fair value follows: Year-End 2016 Year-End 2015 Carrying Amount Fair Value Carrying Amount Fair Value Valuation Technique (In thousands) Fixed rate debt $ (111,506 ) $ (109,789 ) $ (346,090 ) $ (321,653 ) Level 2
Carrying Value of Assets	Non-financial assets measured at fair value on a non-recurring basis are as follows: Year-End 2016 Year-End 2015 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (In thousands) Non-financial Assets and Liabilities: Real estate $ — $ — $ — $ — $ — $ — $ 641 $ 641 Assets of discontinued operations $ — $ — $ — $ — $ — $ — $ 57,219 $ 57,219

Net Income (Loss) per Share (Ta

Net Income (Loss) per Share (Tables)	12 Months Ended
	Dec. 31, 2016
Earnings Per Share [Abstract]
Earnings Attributable to Common Shareholders and Weighted Average Common Shares Outstanding	The computations of basic and diluted earnings (loss) per share are as follows: For the Year 2016 2015 2014 (In thousands) Numerator: Continuing operations Net income (loss) from continuing operations $ 77,044 $ (26,241 ) $ 36,697 Less: Net (income) attributable to noncontrolling interest (1,531 ) (676 ) (505 ) Earnings (loss) available for diluted earnings per share $ 75,513 $ (26,917 ) $ 36,192 Less: Undistributed net income from continuing operations allocated to participating securities (13,493 ) — (6,586 ) Earnings (loss) from continuing operations available to common shareholders for basic earnings per share $ 62,020 $ (26,917 ) $ 29,606 Discontinued operations Net income (loss) from discontinued operations available for diluted earnings per share (16,865 ) (186,130 ) (19,609 ) Less: Undistributed net income from discontinued operations allocated to participating securities 3,014 — 3,569 Earnings (loss) from discontinued operations available to common shareholders for basic earnings per share (13,851 ) (186,130 ) (16,040 ) Denominator: Weighted average common shares outstanding — basic 34,546 34,266 35,317 Weighted average common shares upon conversion of participating securities (a) 7,515 — 7,857 Dilutive effect of stock options, restricted stock and equity-settled awards 273 — 422 Total weighted average shares outstanding — diluted 42,334 34,266 43,596 Anti-dilutive awards excluded from diluted weighted average shares outstanding 2,102 10,864 2,238 _____________________ (a) Our earnings per share calculation reflects the weighted average shares issuable upon settlement of the prepaid stock purchase contract component of our 6.00% tangible equity units, issued in 2013.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Income Tax Expense	Income tax (expense) benefit from continuing operations consists of: For the Year 2016 2015 2014 (In thousands) Current tax provision: U.S. Federal $ (15,089 ) $ 6,740 $ (18,905 ) State and other (1,520 ) (418 ) (2,182 ) (16,609 ) 6,322 (21,087 ) Deferred tax provision: U.S. Federal 1,382 (38,262 ) 184 State and other (75 ) (3,191 ) 53 1,307 (41,453 ) 237 Income tax (expense) benefit $ (15,302 ) $ (35,131 ) $ (20,850 )
Reconciliation of Federal Statutory Rate to Effective Income Tax Rate on Continuing Operations	A reconciliation of the federal statutory rate to the effective income tax rate on continuing operations follows: For the Year 2016 2015 2014 Federal statutory rate (benefit) 35 % 35 % 35 % State, net of federal benefit — 10 2 Valuation allowance (19 ) 348 Noncontrolling interests (1 ) (3 ) — Installment sale ace adjustment 2 — — Stock based compensation — 5 — Charitable contributions — — (1 ) Oil and gas percentage depletion — (1 ) — Other — 1 — Effective tax rate 17 % 395 % 36 %
Significant Components of Deferred Taxes	Significant components of deferred taxes are: At Year-End 2016 2015 (In thousands) Deferred Tax Assets: Real estate $ 50,759 $ 69,594 Employee benefits 13,185 15,752 Net operating loss carryforwards 2,804 13,827 Oil and gas properties 1,672 5,510 AMT credits 5,900 3,620 Income producing properties 2,055 — Oil and gas percentage depletion carryforwards 3,478 3,616 Accruals not deductible until paid 552 911 Other assets — 139 Gross deferred tax assets 80,405 112,969 Valuation allowance (73,405 ) (97,068 ) Deferred tax asset net of valuation allowance 7,000 15,901 Deferred Tax Liabilities: Undeveloped land (1,359 ) (7,588 ) Convertible debt (5,035 ) (6,516 ) Income producing properties — (2,257 ) Timber (283 ) (577 ) Gross deferred tax liabilities (6,677 ) (16,938 ) Net Deferred Tax Asset (Liability) $ 323 $ (1,037 )

Commitments and Other Conting42

Commitments and Other Contingencies (Tables)	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Restructuring and related costs	The following table summarizes activity related to liabilities associated with our restructuring activities in 2016: Employee-Related Costs Retention Bonuses Total (In thousands) Balance at year-end 2015 $ (1,049 ) $ — $ (1,049 ) Additions (2,072 ) (832 ) (2,904 ) Payments 3,121 832 3,953 Balance at year-end 2016 $ — $ — $ —

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Segment Revenues and Earnings	Real Estate Mineral Resources Other Items Not Allocated to Segments Total (In thousands) For the year or at year-end 2016 Revenues $ 190,273 $ 5,076 $ 1,965 $ — $ 197,314 Depreciation, depletion and amortization 976 145 352 7,772 9,245 Equity in earnings of unconsolidated ventures 5,778 173 172 — 6,123 Income (loss) before taxes from continuing operations attributable to Forestar Group Inc. 121,420 3,327 (4,625 ) (29,307 ) (a) 90,815 Total assets (b) 403,062 38,907 11,531 279,694 733,194 Investment in unconsolidated ventures 77,611 — — — 77,611 Capital expenditures 5,783 — 299 56 6,138 For the year or at year-end 2015 Revenues $ 202,830 $ 9,094 $ 6,652 $ — $ 218,576 Depreciation, depletion and amortization 7,605 383 540 8,166 16,694 Equity in earnings of unconsolidated ventures 15,582 275 151 — 16,008 Income (loss) before taxes from continuing operations attributable to Forestar Group Inc. 67,678 4,230 (608 ) (63,086 ) (a) 8,214 Total assets (b) 691,238 39,469 19,106 117,466 867,279 Investment in unconsolidated ventures 82,453 — — — 82,453 Capital expenditures 13,644 59 745 242 14,690 For the year or at year-end 2014 Revenues $ 213,112 $ 15,690 $ 9,362 $ — $ 238,164 Depreciation, depletion and amortization 3,741 684 497 8,035 12,957 Equity in earnings of unconsolidated ventures 8,068 586 31 — 8,685 Income (loss) before taxes from continuing operations attributable to Forestar Group Inc. 96,906 9,116 5,499 (54,479 ) (a) 57,042 Investment in unconsolidated ventures 65,005 — — — 65,005 Capital expenditures 28,980 2,240 5,817 616 37,653 _____________________ (a) Items not allocated to segments consist of: For the Year 2016 2015 2014 (In thousands) General and administrative expense $ (18,274 ) $ (24,802 ) $ (21,229 ) Share-based and long-term incentive compensation expense (4,425 ) (4,474 ) (3,417 ) Gain on sale of assets 48,891 — — Interest expense (19,985 ) (34,066 ) (30,286 ) Loss on extinguishment of debt, net (35,864 ) — — Other corporate non-operating income 350 256 453 $ (29,307 ) $ (63,086 ) $ (54,479 ) (b) Total assets excludes assets of discontinued operations of $14 and $104,967 in 2016 and 2015.

Share-Based Compensation (Table

Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Components of Share-Based Compensation Expense (Income)	Share-based and long-term incentive compensation expense consists of: For the Year 2016 2015 2014 (In thousands) Cash-settled awards $ 717 $ (3,127 ) $ (3,710 ) Equity-settled awards 2,444 5,026 5,168 Restricted stock 22 (8 ) (25 ) Stock options 854 2,355 1,984 Total share-based compensation $ 4,037 $ 4,246 $ 3,417 Deferred cash 388 228 — $ 4,425 $ 4,474 $ 3,417
Share-Based Compensation Expense (Income) Included in Operating Expense	Share-based and long-term incentive compensation expense is included in: For the Year 2016 2015 2014 (In thousands) General and administrative $ 3,323 $ 2,451 $ 1,001 Other operating 1,102 2,023 2,416 $ 4,425 $ 4,474 $ 3,417
Summarized Activity of Cash-Settled Restricted Stock Unit Awards	The following table summarizes the activity of cash-settled restricted stock unit awards in 2016 : Equivalent Units Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 117 $16.00 Granted — — Vested (41 ) 18.84 Forfeited (34 ) 13.83 Non-vested at end of period 42 14.98
Summarized Activity of Cash-Settled Stock Appreciation Rights	The following table summarizes the activity of cash-settled stock appreciation rights in 2016 : Rights Outstanding Weighted Average Exercise Price Weighted Average Remaining Contractual Term Aggregate Intrinsic Value (Current Value Less Exercise Price) (In thousands) (Per share) (In years) (In thousands) Balance at beginning of period 487 $12.97 4 $404 Granted — — Exercised (52 ) 9.29 Forfeited (61 ) 16.12 Balance at end of period 374 12.97 3 773 Exercisable at end of period 345 12.87 3 773
Summarized Activity of Equity-Settled Awards	The following table summarizes the activity of equity-settled awards in 2016 : Equivalent Units Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 631 $ 18.25 Granted 313 9.04 Vested (281 ) 15.12 Forfeited (108 ) 17.91 Non-vested at end of period 555 14.70
Schedule of Fair Value Assumptions of MSU Awards	We estimate the grant date fair value of MSU awards using a Monte Carlo simulation pricing model and the following assumptions: For the Year 2015 2014 Expected stock price volatility 32.9 % 42.2 % Risk-free interest rate 1.0 % 0.7 % Expected dividend yield — % — % Weighted average grant date fair value of MSU awards (per unit) $ 15.11 $ 20.38
Summarized Activity of Restricted Stock Awards	The following table summarizes the activity of restricted stock awards in 2016 : Restricted Shares Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 4 $ 20.55 Granted — — Vested (4 ) 20.55 Forfeited — — Non-vested at end of period — —
Summarized Activity of Stock Option Awards	The following table summarizes the activity of stock option awards in 2016 : Options Outstanding Weighted Average Exercise Price Weighted Average Remaining Contractual Term Aggregate Intrinsic Value (Current Value Less Exercise Price) (In thousands) (Per share) (In years) (In thousands) Balance at beginning of period 2,171 $ 19.56 5 $ 156 Granted 53 9.98 Exercised (35 ) 9.29 Forfeited (353 ) 20.03 Balance at end of period 1,836 19.39 5 449 Exercisable at end of period 1,597 20.25 4 261
Schedule of Fair Value Assumptions of Stock Options	We estimate the grant date fair value of stock options that do not have a market condition using the Black-Scholes option pricing model and the following assumptions: For the Year 2016 2015 Expected stock price volatility 39.5 % 45.6 % Risk-free interest rate 1.5 % 1.8 % Expected life of options (years) 6 6 Expected dividend yield — % — % Weighted average grant date fair value of options (per share) $ 8.60 $ 6.51 We estimated the fair value of these options with market conditions using Monte Carlo simulation pricing model and the following assumptions: Expected stock price volatility 61.4 % Risk-free interest rate 2.2 % Expected dividend yield — % Weighted average grant date fair value of options (per share) $ 7.87

Supplemental Oil and Gas Disc45

Supplemental Oil and Gas Disclosures (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2016
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 2013 5,824 13,630 Revisions of previous estimates 608 293 Extensions and discoveries 2,191 774 Acquisitions 85 31 Sales (105 ) (218 ) Production (931 ) (1,861 ) 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 Our share of ventures accounted for using the equity method: Year-end 2013 — 2,332 Revisions of previous estimates — (382 ) Production — (199 ) 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 Total consolidated and our share of equity method ventures: Year-end 2014 Proved developed reserves 5,269 12,599 Proved undeveloped reserves 2,403 1,801 Total Year-end 2014 7,672 14,400 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 _____________________ (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 2016 2015 2014 (In thousands) Consolidated entities: Acquisition costs Proved properties $ — $ — $ 2,001 Unproved properties 15 4,832 25,666 Exploration costs 21 17,922 39,399 Development costs 537 27,609 40,277 $ 573 $ 50,363 $ 107,343
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 2016 2015 2014 (In thousands) Consolidated entities: Future cash inflows $ 24,304 $ 216,588 $ 665,657 Future production and development costs (2,988 ) (93,623 ) (271,735 ) Future income tax expenses (3,926 ) (22,218 ) (106,002 ) Future net cash flows 17,390 100,747 287,920 10% annual discount for estimated timing of cash flows (7,077 ) (33,951 ) (124,079 ) Standardized measure of discounted future net cash flows $ 10,313 $ 66,796 $ 163,841 Our share in ventures accounted for using the equity method: Future cash inflows $ 2,010 $ 2,283 $ 6,186 Future production and development costs (216 ) (245 ) (664 ) Future income tax expenses (537 ) (774 ) (2,098 ) Future net cash flows 1,257 1,264 3,424 10% annual discount for estimated timing of cash flows (585 ) (562 ) (1,649 ) Standardized measure of discounted future net cash flows $ 672 $ 702 $ 1,775 Total consolidated and our share of equity method ventures $ 10,985 $ 67,498 $ 165,616
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 2013 $ 135,553 $ 1,300 $ 136,853 Changes resulting from: Net change in sales prices and production costs (1,064 ) 1,571 507 Net change in future development costs 1,308 — 1,308 Sales of oil and gas, net of production costs (63,192 ) (787 ) (63,979 ) Net change due to extensions and discoveries 58,228 — 58,228 Net change due to acquisition of reserves 2,778 — 2,778 Net change due to divestitures of reserves (5,804 ) — (5,804 ) Net change due to revisions of quantity estimates 15,303 (343 ) 14,960 Previously estimated development costs incurred 15,497 — 15,497 Accretion of discount 18,067 210 18,277 Net change in timing and other 4,198 115 4,313 Net change in income taxes (17,031 ) (291 ) (17,322 ) Aggregate change for the year 28,288 475 28,763 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
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 2016 2015 2014 (In thousands) Consolidated entities Revenues $ 10,111 $ 51,553 $ 82,919 Production costs (4,392 ) (19,820 ) (19,727 ) Exploration costs (124 ) (11,864 ) (17,416 ) Depreciation, depletion, amortization (2,157 ) (28,774 ) (29,442 ) Non-cash impairment of proved oil and gas properties and unproved leasehold interests (612 ) (164,831 ) (32,665 ) Oil and gas administrative expenses (8,700 ) (11,700 ) (17,000 ) Accretion expense (56 ) (144 ) (121 ) Income tax (expense) benefit (20 ) 14,717 13,398 Results of operations (5,950 ) (170,863 ) (20,054 ) Our share in ventures accounted for using the equity method: Revenues $ 284 $ 428 $ 786 Production costs (76 ) (102 ) (105 ) Oil and gas administrative expenses (35 ) (51 ) (95 ) Income tax (expense) benefit — 21 (235 ) Results of operations $ 173 $ 296 $ 351 Total results of operations $ (5,777 ) $ (170,567 ) $ (19,703 )
Consolidated Entities
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 2016 2015 (In thousands) Consolidated entities: Unproved oil and gas properties $ 374 $ 19,441 Proved oil and gas properties 5,159 119,414 Total costs 5,533 138,855 Less accumulated depreciation, depletion and amortization (4,751 ) (58,242 ) $ 782 $ 80,613

Summary of Quarterly Results 46

Summary of Quarterly Results of Operations (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Summary of Quarterly Results of Operations	Summarized quarterly financial results for 2016 and 2015 follows: First Quarter (a) Second Quarter (a) Third Quarter (a) Fourth Quarter (a) (In thousands, except per share amounts) 2016 Total revenues $ 37,618 $ 47,992 $ 47,207 $ 64,497 Gross profit (loss) 18,579 (24,953 ) 17,403 17,352 Operating income (loss) 13,590 69,528 6,256 50,980 Equity in earnings of unconsolidated ventures 47 188 3,637 2,251 Income from continuing operations before taxes attributable to Forestar Group Inc. 5,992 26,591 7,163 51,069 Income (loss) from discontinued operations, net of taxes (8,216 ) (2,048 ) (7,164 ) 563 Net income (loss) attributable to Forestar Group Inc. (4,376 ) 9,614 9,665 43,745 Net income (loss) per share — basic Continuing operations $ 0.11 $ 0.28 $ 0.40 $ 1.03 Discontinued operations $ (0.24 ) $ (0.05 ) $ (0.17 ) $ 0.01 Net income (loss) per share — basic $ (0.13 ) $ 0.23 $ 0.23 $ 1.04 Net income (loss) per share — diluted Continuing operations $ 0.09 0.28 0.40 $ 1.02 Discontinued operations $ (0.19 ) (0.05 ) (0.17 ) $ 0.01 Net income (loss) per share — diluted $ (0.10 ) 0.23 0.23 $ 1.03 2015 Total revenues $ 37,374 $ 43,625 $ 32,185 $ 105,392 Gross profit (loss) 18,012 21,060 12,879 46,655 Operating income (loss) (3,424 ) 5,919 (8,482 ) 29,929 Equity in earnings of unconsolidated ventures 3,045 5,584 2,909 4,470 Income from continuing operations before taxes attributable to Forestar Group Inc. (8,204 ) 3,382 (13,711 ) 26,747 Income (loss) from discontinued operations, net of taxes (2,719 ) (36,992 ) (106,937 ) (39,482 ) Net loss attributable to Forestar Group Inc. (8,158 ) (34,507 ) (164,216 ) (6,166 ) Net income (loss) per share — basic Continuing operations $ (0.16 ) $ 0.07 $ (1.67 ) $ 0.97 Discontinued operations $ (0.08 ) $ (1.08 ) $ (3.12 ) $ (1.15 ) Net income (loss) per share — basic $ (0.24 ) $ (1.01 ) $ (4.79 ) $ (0.18 ) Net income (loss) per share — diluted Continuing operations $ (0.16 ) $ 0.06 $ (1.67 ) $ 0.79 Discontinued operations $ (0.08 ) $ (0.87 ) $ (3.12 ) $ (0.93 ) Net income (loss) per share — diluted $ (0.24 ) $ (0.81 ) $ (4.79 ) $ (0.14 ) _____________________ (a) Non-cash impairment charges related to real estate, water assets and unproved leasehold interests and proved oil and gas properties included in our quarterly financial results are as follows: First Quarter Second Quarter Third Fourth (In thousands) 2016 Continuing operations $ — $ 48,826 $ 7,627 $ 3,874 Discontinued operations $ — $ 612 $ — $ — 2015 Continuing operations $ 504 $ 225 $ — $ 315 Discontinued operations $ 7 $ 45,938 $ 81,240 $ 37,646

Summary of Significant Accoun47

Summary of Significant Accounting Policies - Additional Information (Detail) a in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)acommunity_development_projectmultifamily_site	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Feb. 17, 2017USD ($)
Significant Accounting Policies [Line Items]
Restricted cash and cash equivalents	$ 275,000	$ 200,000
Capital expenditures incurred but not yet paid	834,000	7,033,000
Non-cash impairment charges	60,939,000	108,184,000	$ 15,934,000
Capitalized exploratory well costs	0
Non-Oil And Gas Properties
Significant Accounting Policies [Line Items]
Depreciation expense of property and equipment	$ 889,000	1,067,000	903,000
Minimum
Significant Accounting Policies [Line Items]
Reimbursement range on water, sewer and other infrastructure-related assets	70.00%
Maximum
Significant Accounting Policies [Line Items]
Reimbursement range on water, sewer and other infrastructure-related assets	90.00%
Capitalize reforestation costs	2 years
Computer Software, Intangible Asset
Significant Accounting Policies [Line Items]
Carrying value of capitalized software	$ 52,000	237,000
Capitalized software amortization	$ 155,000	996,000	1,067,000
Computer Software, Intangible Asset | Minimum
Significant Accounting Policies [Line Items]
Useful life range	3 years
Computer Software, Intangible Asset | Maximum
Significant Accounting Policies [Line Items]
Useful life range	5 years
Georgia
Significant Accounting Policies [Line Items]
Timber owned directly or through ventures | a	19
Depletion	$ 63,000	$ 250,000	$ 371,000
Real Estate Impairment Charges
Significant Accounting Policies [Line Items]
Non-cash impairment charges	$ 56,453,000
Community Development Project
Significant Accounting Policies [Line Items]
Number of properties impaired | community_development_project	6
Multifamily Site
Significant Accounting Policies [Line Items]
Number of properties impaired | multifamily_site	2
Water Resources Company | Texas
Significant Accounting Policies [Line Items]
Non-cash impairment charges	$ 3,874,000
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Community Development Project
Significant Accounting Policies [Line Items]
Number of properties impaired | community_development_project	4
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Multifamily Site
Significant Accounting Policies [Line Items]
Number of properties impaired | multifamily_site	1
Disposal Group, Disposed of by Sale, Not Discontinued Operations | The Mineral Companies | Subsequent Event
Significant Accounting Policies [Line Items]
Purchase price of properties sold				$ 85,600,000

Summary of Significant Accoun48

Summary of Significant Accounting Policies - Schedule of Change in Asset Retirement Obligation (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligation [Roll Forward]
Beginning balance	$ 1,758	$ 1,807
Additions	6	65
Oil and gas working interest property dispositions	(1,610)	(119)
Liabilities settled	(107)	(139)
Accretion expense	56	144
Ending balance	$ 103	$ 1,758

Summary of Significant Accoun49

Summary of Significant Accounting Policies - Estimated Useful Lives of Property Plant and Equipment (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Property plant and equipment, gross	$ 7,657	$ 16,274
Less: accumulated depreciation	(4,541)	(5,542)
Property Plant And Equipment, Net	3,116	10,732
Building and Building Improvements
Property, Plant and Equipment [Line Items]
Property plant and equipment, gross	2,700	4,044
Property and Equipment
Property, Plant and Equipment [Line Items]
Property plant and equipment, gross	$ 4,957	$ 12,230
Minimum | Building and Building Improvements
Property, Plant and Equipment [Line Items]
Property plant and equipment, useful life	10 years
Minimum | Property and Equipment
Property, Plant and Equipment [Line Items]
Property plant and equipment, useful life	2 years
Maximum | Building and Building Improvements
Property, Plant and Equipment [Line Items]
Property plant and equipment, useful life	40 years
Maximum | Property and Equipment
Property, Plant and Equipment [Line Items]
Property plant and equipment, useful life	10 years

New and Pending Accounting Pr50

New and Pending Accounting Pronouncements - Narrative (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Deferred finance costs, net	$ (1,633)	$ (8,267)
Accounting Standards Update 2015-03 | Long-term Debt
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Deferred finance costs, net		(8,267)
Accounting Standards Update 2015-03 | Other Assets
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Deferred finance costs, net		$ 8,267

Real Estate - Real Estate (Deta

Real Estate - Real Estate (Detail) - USD ($) $ in Thousands		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Real Estate Properties [Line Items]
Carrying value		$ 293,003	$ 618,844
Accumulated depreciation		0	(32,129)	$ (31,377)	$ (28,066)
Net carrying value		293,003	586,715
Entitled, developed and under development projects
Real Estate Properties [Line Items]
Carrying value		263,859	352,141
Accumulated depreciation		0
Net carrying value		263,859	352,141
Undeveloped land (includes land in entitlement)
Real Estate Properties [Line Items]
Carrying value		29,144	98,181
Accumulated depreciation		0
Net carrying value		29,144	98,181
Radisson Hotel & Suites
Real Estate Properties [Line Items]
Carrying value		0	62,889
Accumulated depreciation		0	(29,268)
Net carrying value	[1]	0	33,621
Eleven
Real Estate Properties [Line Items]
Carrying value		0	53,896
Accumulated depreciation		0	(2,861)
Net carrying value	[1]	0	51,035
Dillon
Real Estate Properties [Line Items]
Carrying value		0	19,987
Accumulated depreciation		0
Net carrying value	[1]	0	19,987
Music Row
Real Estate Properties [Line Items]
Carrying value		0	9,947
Accumulated depreciation		0
Net carrying value	[1]	0	9,947
Downtown Edge
Real Estate Properties [Line Items]
Carrying value		0	12,706
Accumulated depreciation		0
Net carrying value	[1]	0	12,706
West Austin
Real Estate Properties [Line Items]
Carrying value		0	9,097
Accumulated depreciation		0
Net carrying value	[2]	$ 0	$ 9,097
[1]	Sold in 2016.
[2]	Classified as assets held for sale at year-end 2016.

Real Estate - Additional Inform

Real Estate - Additional Information (Detail)	12 Months Ended			120 Months Ended
	Dec. 31, 2016USD ($)apropertyroomtransactioncommunity_development_projectmultifamily_site	Dec. 31, 2015USD ($)property	Dec. 31, 2014USD ($)	Dec. 31, 2016USD ($)apropertyroom
Real Estate Properties [Line Items]
Non-cash impairment charges	$ 60,939,000	$ 108,184,000	$ 15,934,000
Payment of debt	315,229,000	58,220,000	225,481,000
Gain of sale of assets	166,747,000	1,585,000	29,512,000
General contractor costs	392,000	1,543,000	5,111,000
Recovery of direct costs	(27,107,000)	(15,176,000)	(66,047,000)
Income Producing Properties | Land, Buildings and Improvements
Real Estate Properties [Line Items]
Depreciation expense, related to commercial and income producing properties	816,000	6,810,000	3,319,000
Utility and Improvement District
Real Estate Properties [Line Items]
Cost of asset in developed and under development projects	45,157,000	67,554,000		$ 45,157,000
Cibolo Canyons Project | San Antonio, Texas
Real Estate Properties [Line Items]
Gain of sale of assets	1,219,000	1,160,000	6,577,000
Cost of asset in developed and under development projects	14,749,000	22,302,000		14,749,000
Recovery of direct costs				45,132,000
Costs relate to water, sewer and other infrastructure assets				54,376,000
Consolidated Properties
Real Estate Properties [Line Items]
Recovery of direct costs	26,606,000
Bonds | Cibolo Canyons Project | San Antonio, Texas
Real Estate Properties [Line Items]
Payments received from special improvement district	501,000	425,000	50,550,000
Debt instrument, face amount			48,900,000
Letters of credit outstanding, amount			$ 6,846,000
Surety bond for bond trustee	$ 6,631,000			$ 6,631,000
Radisson Hotel & Suites, Austin | Austin, Texas
Real Estate Properties [Line Items]
Number of hotel rooms | room	413			413
Sales price	$ 130,000,000			$ 130,000,000
Net proceeds	128,764,000
Payment of debt	15,400,000
Gain of sale of assets	95,336,000
Eleven | Multi Family Property | Austin, Texas
Real Estate Properties [Line Items]
Sales price	60,150,000			$ 60,150,000
Net proceeds	59,719,000
Payment of debt	23,936,000
Gain of sale of assets	$ 9,116,000
Number of units of multifamily project | property	257			257
Dillon | Charlotte, North Carolina
Real Estate Properties [Line Items]
Sales price	$ 25,979,000			$ 25,979,000
Net proceeds	25,428,000
Gain of sale of assets	$ 1,223,000
Number of units of multifamily project | property	379			379
Music Row | Nashville, Tennessee
Real Estate Properties [Line Items]
Sales price	$ 15,025,000			$ 15,025,000
Net proceeds	14,703,000
Gain of sale of assets	$ 3,968,000
Number of units of multifamily project | property	230			230
Downtown Edge | Austin, Texas
Real Estate Properties [Line Items]
Sales price	$ 5,000,000			$ 5,000,000
Net proceeds	4,975,000
Gain of sale of assets	(3,870,000)
Midtown
Real Estate Properties [Line Items]
Net proceeds		$ 42,639,000
Number of units of multifamily project | property		354
Real estate property sale price		$ 42,880,000
Segment earnings from sale of multifamily property		9,265,000
Repayments of debt		$ 24,166,000
Real Estate Impairment Charges
Real Estate Properties [Line Items]
Non-cash impairment charges	$ 56,453,000
Community Development Project
Real Estate Properties [Line Items]
Number of properties impaired | community_development_project	6
Multifamily Site
Real Estate Properties [Line Items]
Number of properties impaired | multifamily_site	2
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Georgia and Alabama
Real Estate Properties [Line Items]
Sales price	$ 104,172,000			$ 104,172,000
Net proceeds	103,238,000
Gain of sale of assets	$ 48,891,000
Area of land (in acres) | a	58,300			58,300
Number of transactions | transaction	3
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Community Development Project
Real Estate Properties [Line Items]
Number of properties impaired | community_development_project	4
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Multifamily Site
Real Estate Properties [Line Items]
Number of properties impaired | multifamily_site	1

Investment In Unconsolidated 53

Investment In Unconsolidated Ventures - Additional Information (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)propertyventure	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Number of ventures under ownership interest using equity method | venture	16
Gain of sale of assets	$ 166,747	$ 1,585	$ 29,512
Distributions	13,419	24,909	7,518
Investment in unconsolidated ventures	6,089	26,349	14,692
Fees for services	$ 2,466	$ 1,856	$ 2,275
Variable Interest Entity, Primary Beneficiary
Number of ventures that are a VIE | venture	0
FMF Peakview
Net proceeds	$ 13,917
Gain of sale of assets	$ 10,363
FMF Peakview | Multi Family Property
Number of units of multifamily project | property	304

Investment In Unconsolidated 54

Investment In Unconsolidated Ventures - Summarized Balance Sheet Information (Detail) - USD ($) $ in Thousands		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of Equity Method Investments [Line Items]
Venture Assets		$ 279,674	$ 309,067
Venture Borrowings	[1]	128,288	134,103
Venture Equity		141,802	154,738
Investment in unconsolidated ventures		77,611	82,453	$ 65,005
242, LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets	[2]	26,503	26,687
Venture Borrowings	[2]	1,107	0
Venture Equity	[2]	23,136	24,877
Investment in unconsolidated ventures	[2]	10,934	11,766
CL Ashton Woods
Schedule of Equity Method Investments [Line Items]
Venture Assets	[3]	2,653	7,654
Venture Borrowings	[3]	0	0
Venture Equity	[3]	2,198	6,084
Investment in unconsolidated ventures	[3]	1,107	3,615
CL Realty
Schedule of Equity Method Investments [Line Items]
Venture Assets		8,048	7,872
Venture Borrowings		0	0
Venture Equity		7,899	7,662
Investment in unconsolidated ventures		3,950	3,831
CREA FMF
Schedule of Equity Method Investments [Line Items]
Venture Assets	[2]	56,081	57,820
Venture Borrowings	[2]		50,845
Venture Equity	[2]	17,091	4,291
Investment in unconsolidated ventures	[2]	4,923	3,820
Elan 99 LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets		49,652	34,192
Venture Borrowings			14,587
Venture Equity		13,100	15,838
Investment in unconsolidated ventures		11,790	14,255
FMF Littleton
Schedule of Equity Method Investments [Line Items]
Venture Assets		70,282	52,376
Venture Borrowings		44,446	22,347
Venture Equity		23,798	24,370
Investment in unconsolidated ventures		6,128	6,270
FMF Peakview
Schedule of Equity Method Investments [Line Items]
Venture Assets		0	48,869
Venture Borrowings		0	30,485
Venture Equity		0	16,828
Investment in unconsolidated ventures		0	3,447
FOR/SR Forsyth LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets		10,672	6,500
Venture Borrowings		1,568	0
Venture Equity		8,990	6,500
Investment in unconsolidated ventures		8,091	5,850
HM Stonewall Estates
Schedule of Equity Method Investments [Line Items]
Venture Assets	[3]	852	2,842
Venture Borrowings	[3]	0	0
Venture Equity	[3]	852	2,842
Investment in unconsolidated ventures	[3]	477	1,294
LM Land Holdings
Schedule of Equity Method Investments [Line Items]
Venture Assets	[3]	25,538	31,984
Venture Borrowings	[3]	3,477	7,728
Venture Equity	[3]	20,945	22,751
Investment in unconsolidated ventures	[3]	9,685	9,664
MRECV DT Holdings LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets		4,155	4,215
Venture Borrowings		0	0
Venture Equity		4,144	4,215
Investment in unconsolidated ventures		3,729	3,807
MRECV Edelweiss LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets		3,484	2,237
Venture Borrowings		0	0
Venture Equity		3,484	2,237
Investment in unconsolidated ventures		3,358	2,029
MRECV Juniper Ridge LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets		4,156	3,006
Venture Borrowings		0	0
Venture Equity		4,156	3,006
Investment in unconsolidated ventures		3,741	2,730
MRECV Meadow Crossing II LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets		2,492	728
Venture Borrowings		0	0
Venture Equity		2,491	728
Investment in unconsolidated ventures		2,242	655
Miramonte Boulder Pass, LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets		10,738	12,627
Venture Borrowings		4,006	5,869
Venture Equity		5,265	5,474
Investment in unconsolidated ventures		5,330	5,349
Temco
Schedule of Equity Method Investments [Line Items]
Venture Assets		4,368	5,284
Venture Borrowings		0	0
Venture Equity		4,253	5,113
Investment in unconsolidated ventures		2,126	2,557
Other Ventures
Schedule of Equity Method Investments [Line Items]
Venture Assets	[4]	0	4,174
Venture Borrowings	[4]	0	2,242
Venture Equity	[4]	0	1,922
Investment in unconsolidated ventures	[4]	0	$ 1,514
Nashville, Tennessee | Construction Loans | CREA FMF
Schedule of Equity Method Investments [Line Items]
Venture Borrowings	[2]	37,446
Houston, Texas | Construction Loans | Elan 99 LLC
Schedule of Equity Method Investments [Line Items]
Venture Borrowings		$ 36,238
[1]	Total includes current maturities of $89,756,000 at year-end 2016, of which $78,557,000 is non-recourse to us, and $39,590,000 at year-end 2015, of which $29,691,000 is non-recourse to us.
[2]	Includes unamortized deferred gains on real estate contributed by us to ventures. We recognize deferred gains as income as real estate is sold to third parties. Deferred gains of $1,457,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2016.
[3]	Includes unrecognized basis difference of $259,000 which is reflected as an increase of our investment in unconsolidated ventures at year-end 2016. This difference between estimated fair value of the equity investment and our capital account within the respective ventures at closing will be accreted as income or expense over the life of the investment and included in our share of earnings (loss) from the respective ventures.
[4]	Our share of venture earnings in 2016 includes reallocation of prior year cumulative losses incurred by the venture as a result of equity contribution by the venture partner in 2016.

Investment In Unconsolidated 55

Investment In Unconsolidated Ventures - Summarized Income Statement Information (Detail) - USD ($) $ in Thousands		3 Months Ended								12 Months Ended
		Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of Equity Method Investments [Line Items]
Revenues										$ 46,130	$ 125,729	$ 42,443
Earnings (Loss)										9,119	59,320	25,288
Our share of earnings (loss)		$ 2,251	$ 3,637	$ 188	$ 47	$ 4,470	$ 2,909	$ 5,584	$ 3,045	6,123	16,008	8,685
242, LLC
Schedule of Equity Method Investments [Line Items]
Revenues	[1]									5,835	20,995	5,612
Earnings (Loss)	[1]									1,259	9,588	2,951
Our share of earnings (loss)	[1]									668	4,919	1,514
CL Ashton Woods
Schedule of Equity Method Investments [Line Items]
Revenues	[2]									2,870	9,820	5,431
Earnings (Loss)	[2]									914	3,881	1,748
Our share of earnings (loss)	[2]									1,332	5,000	2,471
CL Realty
Schedule of Equity Method Investments [Line Items]
Revenues										567	856	1,573
Earnings (Loss)										237	424	1,068
Our share of earnings (loss)										119	212	534
CREA FMF
Schedule of Equity Method Investments [Line Items]
Revenues	[1],[2]									4,955	1,227	0
Earnings (Loss)	[1],[2]									(1,420)	(1,696)	(163)
Our share of earnings (loss)	[1],[2]									1,103	(1,696)	(163)
Elan 99 LLC
Schedule of Equity Method Investments [Line Items]
Revenues										1,392	0	0
Earnings (Loss)										(2,739)	(49)	(87)
Our share of earnings (loss)										(2,465)	(44)	(78)
FMF Littleton
Schedule of Equity Method Investments [Line Items]
Revenues										3,116	120	0
Earnings (Loss)										(571)	(367)	(239)
Our share of earnings (loss)										(143)	(92)	(60)
FMF Peakview
Schedule of Equity Method Investments [Line Items]
Revenues										939	2,057	4
Earnings (Loss)										(248)	(1,116)	(410)
Our share of earnings (loss)										(50)	(223)	(83)
FOR/SR Forsyth LLC
Schedule of Equity Method Investments [Line Items]
Revenues										0	0
Earnings (Loss)										(65)	0
Our share of earnings (loss)										(58)	0
HM Stonewall Estates
Schedule of Equity Method Investments [Line Items]
Revenues	[3]									2,112	3,990	1,728
Earnings (Loss)	[3]									832	1,881	613
Our share of earnings (loss)	[3]									361	952	248
LM Land Holdings
Schedule of Equity Method Investments [Line Items]
Revenues	[3]									10,001	10,956	21,980
Earnings (Loss)	[3]									7,288	8,251	15,520
Our share of earnings (loss)	[3]									2,458	3,342	4,827
MRECV DT Holdings LLC
Schedule of Equity Method Investments [Line Items]
Revenues										495	0
Earnings (Loss)										477	167
Our share of earnings (loss)										429	0
MRECV Edelweiss LLC
Schedule of Equity Method Investments [Line Items]
Revenues										416	0
Earnings (Loss)										409	151
Our share of earnings (loss)										368	137
MRECV Juniper Ridge LLC
Schedule of Equity Method Investments [Line Items]
Revenues										379	0
Earnings (Loss)										380	106
Our share of earnings (loss)										342	0
MRECV Meadow Crossing II LLC
Schedule of Equity Method Investments [Line Items]
Revenues										267	0	0
Earnings (Loss)										220	0	0
Our share of earnings (loss)										198	0	0
Miramonte Boulder Pass, LLC
Schedule of Equity Method Investments [Line Items]
Revenues										4,923	0
Earnings (Loss)										(399)	(250)
Our share of earnings (loss)										(200)	(125)
PSW Communities
Schedule of Equity Method Investments [Line Items]
Revenues										0	29,986	0
Earnings (Loss)										0	2,688	(86)
Our share of earnings (loss)										0	1,169	(76)
Temco
Schedule of Equity Method Investments [Line Items]
Revenues										1,344	9,485	2,155
Earnings (Loss)										440	2,358	494
Our share of earnings (loss)										220	1,179	247
Other Ventures
Schedule of Equity Method Investments [Line Items]
Revenues										6,519	36,237	3,960
Earnings (Loss)										2,105	33,303	3,879
Our share of earnings (loss)										$ 1,441	$ 1,278	$ (696)
[1]	Includes unamortized deferred gains on real estate contributed by us to ventures. We recognize deferred gains as income as real estate is sold to third parties. Deferred gains of $1,457,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2016.
[2]	Our share of venture earnings in 2016 includes reallocation of prior year cumulative losses incurred by the venture as a result of equity contribution by the venture partner in 2016.
[3]	Includes unrecognized basis difference of $259,000 which is reflected as an increase of our investment in unconsolidated ventures at year-end 2016. This difference between estimated fair value of the equity investment and our capital account within the respective ventures at closing will be accreted as income or expense over the life of the investment and included in our share of earnings (loss) from the respective ventures.

Investment In Unconsolidated 56

Investment In Unconsolidated Ventures - Summarized Income Statement Information (Footnotes) (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Reduction in investment	$ 259
242, LLC
Schedule of Equity Method Investments [Line Items]
Reduction in investment	1,457
Equity Method Investments
Schedule of Equity Method Investments [Line Items]
Long-term debt, current maturities	89,756	$ 39,590
Equity Method Investments | Non-recourse Debt
Schedule of Equity Method Investments [Line Items]
Long-term debt, current maturities	$ 78,557	$ 29,691

Goodwill and Other Intangible57

Goodwill and Other Intangible Assets - Carrying Value of Goodwill and Other Intangible Assets (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	$ 37,900	$ 41,774
Identified intangibles, net	0	1,681
Total	$ 37,900	$ 43,455

Goodwill and Other Intangible58

Goodwill and Other Intangible Assets - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Goodwill acquired on acquisition	$ 37,900,000	$ 41,774,000
Non-cash impairment charges	60,939,000	108,184,000	$ 15,934,000
Unproved leasehold interests
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Goodwill acquired on acquisition	37,900,000	37,900,000
Water Resources Company
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Goodwill acquired on acquisition	0	$ 3,874,000
Water Resources Company | Groundwater Leases
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Identified intangible assets	1,681,000
Texas | Water Resources Company
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Non-cash impairment charges	$ 3,874,000

Held for Sale (Additional Infor

Held for Sale (Additional Information) (Details)	Dec. 31, 2016a
Disposal Group, Held-for-sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Area of land (in acres)	19,000

Held for Sale (Assets and Liabi

Held for Sale (Assets and Liabilities of Properties Held for Sale) (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Assets Held for Sale [Abstract]
Property and equipment	$ 0	$ 79,733
Assets	14	104,967
Liabilities Held for Sale [Abstract]
Other liabilities	0	1,667
Liabiltiies	5,295	$ 11,192
Disposal Group, Held-for-sale, Not Discontinued Operations
Assets Held for Sale [Abstract]
Property and equipment	6,301
Other intangible assets	1,681
Assets	30,377
Liabilities Held for Sale [Abstract]
Other liabilities	103
Liabiltiies	103
Disposal Group, Held-for-sale, Not Discontinued Operations | Real Estate
Assets Held for Sale [Abstract]
Property and equipment	19,931
Disposal Group, Held-for-sale, Not Discontinued Operations | Timber
Assets Held for Sale [Abstract]
Property and equipment	1,682
Disposal Group, Held-for-sale, Not Discontinued Operations | Oil and Gas Properties
Assets Held for Sale [Abstract]
Property and equipment	$ 782

Discontinued Operations (Summar

Discontinued Operations (Summarized Results from Discontinued Operations) (Detail) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Discontinued Operations and Disposal Groups [Abstract]
Revenues									$ 5,862	$ 43,845	$ 68,610
Cost of oil and gas producing activities									(6,578)	(221,402)	(94,581)
Other operating expenses									(7,754)	(10,363)	(14,357)
Loss from discontinued operations before income taxes									(8,470)	(187,920)	(40,328)
Gain (loss) on sale of assets before income taxes									(13,664)	(706)	8,526
Income tax benefit									5,269	2,496	12,193
Net income (loss) from discontinued operations available for diluted earnings per share	$ 563	$ (7,164)	$ (2,048)	$ (8,216)	$ (39,482)	$ (106,937)	$ (36,992)	$ (2,719)	$ (16,865)	$ (186,130)	$ (19,609)

Discontinued Operations (Additi

Discontinued Operations (Additional Information) (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)awell	Dec. 31, 2015USD ($)awell	Dec. 31, 2014USD ($)awell
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
(Loss) gain on disposition of proved property	$ (13,664)	$ (706)	$ 8,526
Net mineral acres leased from others sold | a	199,263
Gross producing oil and gas wells sold | well	379
Net producing oil and gas wells sold | well	95
Proceeds from sale of oil and gas property and equipment	$ 80,374	17,800	17,660
Reimbursement of capital costs related to sale of in progress wells	3,269
Non-cash impairment charges	60,939	$ 108,184	$ 15,934
Pending Litigation | Huffman vs. Forestar Petroleum Corporation
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Accrual for damages	2,990
Wyoming
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Environmental liability	1,155
Transaction
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gas and oil area, undeveloped, net | a		109,000	650
Productive oil wells, number of wells, gross | well		39	124
Productive oil wells, number of wells, net | well		7	18
Cost of Sales
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Non-cash impairment charges	$ 612	$ 163,029	$ 32,665

Discontinued Operations (Assets

Discontinued Operations (Assets and Liabilities of Discontinued Operations) (Detail) (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Assets of Discontinued Operations:
Receivables, net of allowance for bad debt	$ 6	$ 4,632
Oil and gas properties and equipment, net	0	79,733
Goodwill and other intangible assets	0	19,673
Prepaid expenses	8	96
Other assets	0	833
Assets	14	104,967
Liabilities of Discontinued Operations:
Accounts payable	67	342
Accrued property taxes	0	259
Other accrued expenses	5,228	8,924
Other liabilities	0	1,667
Liabiltiies	$ 5,295	$ 11,192

Discontinued Operations (Signif

Discontinued Operations (Significant Operating and Investing Activities of Discontinued Operations) (Detail) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Net Cash Provided by (Used in) Operating Activities, Discontinuing Operations [Abstract]
Asset impairments	$ 60,939	$ 108,184	$ 15,934
Dry hole and unproved leasehold impairment costs	0	67,639	29,528
Loss (gain) on sale of assets	13,664	706	(8,526)
Depreciation, depletion and amortization	11,447	45,085	41,715
Cash provided by (used in) operating activities, discontinued operations	16,478	202,073	65,295
Net Cash Provided by (Used in) Investing Activities, Discontinuing Operations [Abstract] [Abstract]
Oil and gas properties and equipment	(579)	(49,717)	(101,145)
Acquisition of oil and gas properties	0	0	(1,100)
Cash provided by (used in) investing activities, discontinued operations	76,526	(31,917)	(84,585)
Discontinued Operations
Net Cash Provided by (Used in) Operating Activities, Discontinuing Operations [Abstract]
Asset impairments	612	105,337	15,535
Dry hole and unproved leasehold impairment costs	0	67,639	29,528
Loss (gain) on sale of assets	13,664	706	(8,526)
Depreciation, depletion and amortization	2,202	28,391	28,758
Net Cash Provided by (Used in) Investing Activities, Discontinuing Operations [Abstract] [Abstract]
Oil and gas properties and equipment	(579)	(49,717)	(101,145)
Acquisition of oil and gas properties	0	0	(1,100)
Proceeds from sales of assets	$ 77,105	$ 17,800	$ 17,660

Receivables - Receivables (Deta

Receivables - Receivables (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	$ 8,957	$ 19,051
Allowance for bad debts	(26)	(26)
Receivables, net	8,931	19,025
Funds held by qualified intermediary
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	0	14,703
Other receivables and accrued interest
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	1,505	2,218
Other loans secured by real estate
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	$ 7,452	$ 2,130
Average interest rates	5.86%	11.31%

Receivables - Additional Inform

Receivables - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2016a
Funds held by qualified intermediary
Accounts, Notes, Loans and Financing Receivable [Line Items]
Area of land (in acres)	6,915
Minimum
Accounts, Notes, Loans and Financing Receivable [Line Items]
Due period of notes receivable as secured by deed of trust	3 years
Maximum
Accounts, Notes, Loans and Financing Receivable [Line Items]
Due period of notes receivable as secured by deed of trust	5 years

Debt - Schedule of Debt (Detail

Debt - Schedule of Debt (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Line of Credit Facility [Line Items]
Debt	$ 110,358	$ 381,515
6% Tangible Equity Units
Line of Credit Facility [Line Items]
Debt	0	8,666
Senior Notes
Line of Credit Facility [Line Items]
Debt	5,200	224,647
Convertible Debt
Line of Credit Facility [Line Items]
Debt	104,673	104,719
Secured Promissory Notes
Line of Credit Facility [Line Items]
Debt	0	15,400
Other Indebtedness
Line of Credit Facility [Line Items]
Debt	$ 485	$ 28,083

Debt - Debt (Detail)

Debt - Debt (Detail)	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2013	Nov. 27, 2013	Feb. 26, 2013
Convertible Debt
Line of Credit Facility [Line Items]
Average interest rate	3.75%	3.75%
Variable and fixed interest rates ranging, minimum	3.75%		3.75%		3.75%
6% Tangible Equity Units
Line of Credit Facility [Line Items]
Average interest rate	6.00%	6.00%
Secured Promissory Notes
Line of Credit Facility [Line Items]
Average interest rate		3.42%
Senior Secured Credit Facility | Revolving Credit Facility
Line of Credit Facility [Line Items]
Average interest rate	8.50%	8.50%
6% Tangible Equity Units
Line of Credit Facility [Line Items]
Variable and fixed interest rates ranging, minimum			6.00%	6.00%
Minimum | Other Indebtedness
Line of Credit Facility [Line Items]
Variable and fixed interest rates ranging, minimum	5.00%
Maximum | Other Indebtedness
Line of Credit Facility [Line Items]
Variable and fixed interest rates ranging, minimum	5.50%

Debt - Additional Information (

Debt - Additional Information (Detail)	Dec. 15, 2016shares	Dec. 31, 2016USD ($)propertyextension$ / shares	Dec. 31, 2015USD ($)$ / shares	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)unit$ / shares$ / Unit	Dec. 30, 2016USD ($)	Nov. 27, 2013	Feb. 26, 2013
Line of Credit Facility [Line Items]
Extinguishment of debt, amount		$ 315,229,000	$ 58,220,000	$ 225,481,000
Accrued interest		1,585,000	3,267,000
Loss on extinguishment of debt, net		$ 35,864,000	$ 0	0
Common stock, par value | $ / shares		$ 1	$ 1
Debt		$ 110,358,000	$ 381,515,000
Deferred finance costs, net		1,633,000	8,267,000
Amortization of deferred financing fees		3,598,000	4,002,000	$ 3,845,000
Debt maturities, 2017		0
Debt maturities, 2018		485,000
Debt maturities, 2019		0
Debt maturities, 2020		104,673,000
Debt maturities, 2021		0
Debt maturities, thereafter		5,200,000
6% Tangible Equity Units
Line of Credit Facility [Line Items]
Interest rate percentage					6.00%		6.00%
Principal amount of debt					$ 150,000,000
Units issued | unit					6,000,000
Exercise price of unit | $ / Unit					25
Common stock, par value | $ / shares					$ 1
Issuance of common stock (in shares) | shares	7,857,000
Debt		0	$ 8,666,000
Revolving Line of Credit | Sublimit For Letters Of Credit
Line of Credit Facility [Line Items]
Sublimit for letters of credit under line of credit facility		100,000,000
Letter of Credit
Line of Credit Facility [Line Items]
Sublimit for letters of credit outstanding		14,850,000
Senior Notes
Line of Credit Facility [Line Items]
Interest rate percentage				8.50%
Percentage of principal amount redeemed			97.00%
Principal amount of debt				$ 250,000,000
Loss on extinguishment of debt, net		35,681,000
Write off of deferred debt issuance cost		5,416,000	$ 506,000
Tender offer advisory services		1,301,000
Principal amount of notes			19,440,000
Gain on early extinguishment of debt			(589,000)
Debt		$ 5,200,000	224,647,000
Senior Notes | 6% Tangible Equity Units
Line of Credit Facility [Line Items]
Interest rate percentage					4.50%
Face amount per unit, debt | $ / Unit					4.2522
Convertible Debt
Line of Credit Facility [Line Items]
Interest rate percentage		3.75%			3.75%			3.75%
Extinguishment of debt, amount		$ 5,000,000
Extinguishment of debt, amount		$ 4,452,000
Percentage of principal amount redeemed		93.25%
Principal amount of debt					$ 125,000,000
Loss on extinguishment of debt, net		$ 183,000
Gain on early extinguishment of debt		110,000
Maturity date					Mar. 1, 2020
Initial conversion rate					40.8351
Principal amount of initial conversion rate					$ 1,000
Unamortized debt discount		13,809,000
Repayments of long-term debt, including payments for repurchase of equity		4,663,000
Carrying amount of equity component		211,000
Debt		104,673,000	104,719,000
Secured Promissory Notes
Line of Credit Facility [Line Items]
Debt		$ 0	15,400,000
Senior Secured Credit Facility
Line of Credit Facility [Line Items]
Expiration date		May 15, 2017
Number of extensions | extension		2
Length of extensions		1 year
Maximum borrowing capacity under term loan facility		$ 125,000,000				$ 300,000,000
Amount drawn on		0
Net unused borrowing capacity		$ 71,262,000
Percentage of spread on federal funds effective rate		0.50%
Minimum net worth required for compliance		$ 426,312,000
Minimum net worth required for compliance, computed as		$ 379,044,000
Positive net income requirement for net worth compliance (as a percent)		85.00%
Minimum net worth required for compliance (as a percentage)		75.00%
Minimum effective leverage ratio exceeded (less than)		40.00%
Stockholders distribution covenant, interest coverage ratio		3
Minimum liquidity required (less than)		$ 125,000,000
Payments of capital distribution		$ 50,000,000
Percentage from sales of properties and non-core assets (up to)		65.00%
Deferred finance costs, net		$ 314,000	$ 2,768,000
Over-Allotment Option | 6% Tangible Equity Units
Line of Credit Facility [Line Items]
Units issued | unit					600,000
London Interbank Offered Rate (LIBOR) | Senior Secured Credit Facility
Line of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate		4.00%
Base Rate | Senior Secured Credit Facility
Line of Credit Facility [Line Items]
Percentage of variable spread on base rate		3.00%
Thirty Day LIBOR Rate | Senior Secured Credit Facility
Line of Credit Facility [Line Items]
Debt instrument, basis spread on variable rate		1.00%
Radisson Hotel & Suites, Austin | Austin, Texas
Line of Credit Facility [Line Items]
Extinguishment of debt, amount		$ 15,400,000
Purchase price of properties sold		130,000,000
Radisson Hotel & Suites, Austin | Secured Promissory Notes | Austin, Texas
Line of Credit Facility [Line Items]
Debt		15,400,000
Eleven | Multi Family Property | Austin, Texas
Line of Credit Facility [Line Items]
Extinguishment of debt, amount		23,936,000
Purchase price of properties sold		$ 60,150,000
Number of units of multifamily project | property		257
Tender Offer | Senior Notes
Line of Credit Facility [Line Items]
Extinguishment of debt, amount		$ 215,495,000
Redemption price, (as a percent)		97.60%
Extinguishment of debt, amount		$ 245,604,000
Unamortized premium		$ 29,091,000
Percentage of principal amount redeemed		113.50%
Accrued interest		$ 1,018,000
Open Market Transaction | Senior Notes
Line of Credit Facility [Line Items]
Principal amount of debt		$ 9,750,000
Minimum | Open Market Transaction | Senior Notes
Line of Credit Facility [Line Items]
Percentage of principal amount redeemed		99.00%
Maximum | Open Market Transaction | Senior Notes
Line of Credit Facility [Line Items]
Percentage of principal amount redeemed		99.95%

Fair Value - Information About

Fair Value - Information About our Fixed Rate Financial instruments not Measured at Fair Value (Detail) - Level 2 - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Reported Value Measurement
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fixed rate debt	$ (111,506)	$ (346,090)
Estimate of Fair Value Measurement
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fixed rate debt	$ (109,789)	$ (321,653)

Fair Value - Additional Informa

Fair Value - Additional Information (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)community_development_projectmultifamily_site	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset impairments	$ 60,939	$ 108,184	$ 15,934
Impairment of oil and gas properties		107,140
Impairment of leasehold		57,691
Real Estate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset impairments		$ 1,044
Real Estate Impairment Charges
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset impairments	$ 56,453
Community Development Project
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Number of properties impaired | community_development_project	6
Multifamily Site
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Number of properties impaired | multifamily_site	2
Oil and Gas Properties
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of assets to be disposed of	$ 612
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Community Development Project
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Number of properties impaired | community_development_project	4
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Multifamily Site
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Number of properties impaired | multifamily_site	1

Fair Value - Carrying Value of

Fair Value - Carrying Value of Assets (Detail) - Non-recurring - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Real estate
Non-Financial Assets and Liabilities:
Assets, fair value disclosure, nonrecurring	$ 0	$ 641
Real estate | Level 1
Non-Financial Assets and Liabilities:
Assets, fair value disclosure, nonrecurring	0	0
Real estate | Level 2
Non-Financial Assets and Liabilities:
Assets, fair value disclosure, nonrecurring	0	0
Real estate | Level 3
Non-Financial Assets and Liabilities:
Assets, fair value disclosure, nonrecurring	0	641
Discontinued Operations
Non-Financial Assets and Liabilities:
Assets, fair value disclosure, nonrecurring	0	57,219
Discontinued Operations | Level 1
Non-Financial Assets and Liabilities:
Assets, fair value disclosure, nonrecurring	0	0
Discontinued Operations | Level 2
Non-Financial Assets and Liabilities:
Assets, fair value disclosure, nonrecurring	0	0
Discontinued Operations | Level 3
Non-Financial Assets and Liabilities:
Assets, fair value disclosure, nonrecurring	$ 0	$ 57,219

Capital Stock - (Detail)

Capital Stock - (Detail) - USD ($) $ / shares in Units, $ in Thousands	Dec. 15, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Nov. 27, 2013	Feb. 26, 2013
Class of Stock [Line Items]
Settlement of tangible equity units, Shares	7,857,000
Number of shares repurchased		283,976		1,491,187
Value of share repurchased		$ 3,537		$ 24,595
Common stock repurchased since announcement of strategic initiative		3,777,308
Value of common stock repurchased since announcement of strategic initiative		$ 57,696
Maximum percentage of shares repurchased under strategic initiative		20.00%
Maximum number of shares repurchased under strategic initiative		7,000,000
Former Affiliated Entity | Pre Spin Stock Option Awards
Class of Stock [Line Items]
Options to purchase shares of common stock		234,764
Weighted average exercise price		$ 30.56
Aggregate intrinsic value		$ 0
6% Tangible Equity Units
Class of Stock [Line Items]
Interest rate percentage					6.00%	6.00%
Convertible Debt
Class of Stock [Line Items]
Interest rate percentage		3.75%			3.75%		3.75%
Preferred Stock
Class of Stock [Line Items]
Expiry date of rights			Dec. 11, 2017

Net Income (Loss) per Share - E

Net Income (Loss) per Share - Earnings Attributable to Common Shareholders and Weighted Average Common Shares Outstanding (Detail) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Continuing operations
Consolidated net income (loss)									$ 77,044	$ (26,241)	$ 36,697
Less: Net (income) attributable to noncontrolling interest									(1,531)	(676)	(505)
Earnings (loss) available for diluted earnings per share									75,513	(26,917)	36,192
Less: Undistributed net income from continuing operations allocated to participating securities									(13,493)	0	(6,586)
Earnings (loss) from continuing operations available to common shareholders for basic earnings per share									62,020	(26,917)	29,606
Discontinued operations
Net income (loss) from discontinued operations available for diluted earnings per share	$ 563	$ (7,164)	$ (2,048)	$ (8,216)	$ (39,482)	$ (106,937)	$ (36,992)	$ (2,719)	(16,865)	(186,130)	(19,609)
Less: Undistributed net income from discontinued operations allocated to participating securities									3,014	0	3,569
Earnings (loss) from discontinued operations available to common shareholders for basic earnings per share									$ (13,851)	$ (186,130)	$ (16,040)
Weighted Average Number of Shares Outstanding Reconciliation [Abstract]
Weighted average common shares outstanding - basic									34,546	34,266	35,317
Weighted average common shares upon conversion of participating securities									7,515	0	7,857
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements									273	0	422
Weighted average common shares outstanding - diluted									42,334	34,266	43,596
Anti-dilutive awards excluded from diluted weighted average shares outstanding									2,102	10,864	2,238

Net Income (Loss) per Share - A

Net Income (Loss) per Share - Additional Information (Details) - $ / shares	Dec. 15, 2016	Dec. 31, 2016	Dec. 31, 2013	Nov. 27, 2013
Debt Instrument [Line Items]
Settlement of tangible equity units, Shares	7,857,000
6% Tangible Equity Units
Debt Instrument [Line Items]
Interest rate percentage			6.00%	6.00%
Convertible Debt
Debt Instrument [Line Items]
Exercise price of unit		$ 24.49
Maximum | 6% Tangible Equity Units
Debt Instrument [Line Items]
Settlement of tangible equity units, Shares	7,857,000

Income Taxes - Income Tax Expen

Income Taxes - Income Tax Expense (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Current tax provision:
U.S. Federal	$ (15,089)	$ 6,740	$ (18,905)
State and other	(1,520)	(418)	(2,182)
Total	(16,609)	6,322	(21,087)
Deferred tax provision:
U.S. Federal	1,382	(38,262)	184
State and other	(75)	(3,191)	53
Total	1,307	(41,453)	237
Income tax expense	$ (15,302)	$ (35,131)	$ (20,850)

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Federal Statutory Rate to Effective Income Tax Rate on Continuing Operations (Detail)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Federal statutory rate (benefit)	35.00%	35.00%	35.00%
State, net of federal benefit	0.00%	10.00%	2.00%
Valuation allowance	(19.00%)	348.00%
Noncontrolling interests	(1.00%)	(3.00%)	0.00%
Installment sale ace adjustment	2.00%	0.00%	0.00%
Stock based compensation	0.00%	5.00%	0.00%
Charitable contributions	0.00%	0.00%	(1.00%)
Oil and gas percentage depletion	0.00%	(1.00%)	0.00%
Other	0.00%	1.00%	0.00%
Effective tax rate	17.00%	395.00%	36.00%

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating Loss Carryforwards [Line Items]
Detriment from a valuation allowance recorded against deferred tax asset, percentage	$ 0.19
Detriment from the recording of a valuation allowance, percentage	(19.00%)	348.00%
Oil and gas percentage depletion carryforwards	$ 9,200,000
AMT credits	5,900,000	$ 3,620,000
Valuation allowance	73,405,000	97,068,000
Decrease in valuation allowance	23,663,000
Unrecognized tax benefit	2,499,000	0	$ 0
Recognized interest accrued related to unrecognized tax benefits	0	0	$ 0
Accrued interest	0	$ 0
Credo
Operating Loss Carryforwards [Line Items]
Oil and gas percentage depletion carryforwards	9,200,000
Domestic Tax Authority
Operating Loss Carryforwards [Line Items]
Operating loss carry forwards	$ 7,500,000
Expiration date of operating loss carry forwards	Dec. 31, 2031
Domestic Tax Authority | Credo
Operating Loss Carryforwards [Line Items]
Operating loss carry forwards	$ 7,500,000
State and Local Jurisdiction
Operating Loss Carryforwards [Line Items]
Operating loss carry forwards	64,200,000
State and Local Jurisdiction | Credo
Operating Loss Carryforwards [Line Items]
Operating loss carry forwards	$ 2,400,000
Minimum | State and Local Jurisdiction
Operating Loss Carryforwards [Line Items]
Expiration date of operating loss carry forwards	Dec. 31, 2017
Maximum | State and Local Jurisdiction
Operating Loss Carryforwards [Line Items]
Expiration date of operating loss carry forwards	Dec. 31, 2036

Income Taxes - Significant Comp

Income Taxes - Significant Components of Deferred Taxes (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Deferred Tax Assets:
Real estate	$ 50,759	$ 69,594
Employee benefits	13,185	15,752
Net operating loss carryforwards	2,804	13,827
Oil and gas properties	1,672	5,510
AMT credits	5,900	3,620
Income producing properties	2,055	0
Oil and gas percentage depletion carryforwards	3,478	3,616
Accruals not deductible until paid	552	911
Other assets	0	139
Gross deferred tax assets	80,405	112,969
Valuation allowance	(73,405)	(97,068)
Deferred tax asset net of valuation allowance	7,000	15,901
Deferred Tax Liabilities:
Undeveloped land	(1,359)	(7,588)
Convertible debt	(5,035)	(6,516)
Income producing properties	0	(2,257)
Timber	(283)	(577)
Gross deferred tax liabilities	6,677	16,938
Deferred tax asset, net	323	0
Deferred tax liabilities, net	$ 0	$ (1,037)

Litigation and Environmental 80

Litigation and Environmental Contingencies - Litigation (Details) - Huffman vs. Forestar Petroleum Corporation - Settled Litigation - USD ($)	3 Months Ended
	Dec. 31, 2016	Sep. 30, 2016
Loss Contingencies [Line Items]
Litigation settlement, amount		$ 150,000
Increase in accrual	$ 1,890,000	$ 1,100,000
Accrual for damages	$ (2,990,000)

Litigation and Environmental 81

Litigation and Environmental Contingencies - Environmental (Detail)	12 Months Ended
	Dec. 31, 2016USD ($)a	Dec. 31, 2015USD ($)a	Dec. 31, 2014USD ($)
Environmental Exit Cost [Line Items]
Asset retirement obligation	$ 103,000	$ 1,758,000	$ 1,807,000
Antioch, California
Environmental Exit Cost [Line Items]
Area of land (in acres) | a	25	289
Area sold without certificate of completion under voluntary remediation program | a	80
Wyoming
Environmental Exit Cost [Line Items]
Environmental liability	$ 1,155,000
Paper Manufacturing Sites [Member]
Environmental Exit Cost [Line Items]
Insurance policy	$ 20,000,000
Length of insurance policy (in years)	10 years

Commitments and Other Conting82

Commitments and Other Contingencies (Detail) ft² in Thousands, a in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)aft²	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Operating Leased Assets [Line Items]
Operating lease future payments, 2017	$ 2,267
Operating lease future payments, 2018	1,593
Operating lease future payments, 2019	298
Operating lease future payments, 2020	182
Operating lease future payments, 2021	62
Operating lease future payments, thereafter	0
Office Facilities And Other Equipment
Operating Leased Assets [Line Items]
Lease expense	$ 1,923	$ 3,872	$ 2,617
Ground Water Lease
Operating Leased Assets [Line Items]
Remaining years of timber lease	1 year
Timber land area taken on lease | a	20
Remaining contractual obligation	$ 494
Corporate Headquarters
Operating Leased Assets [Line Items]
Remaining contractual obligation	$ 1,983
Corporate Headquarters | Texas
Operating Leased Assets [Line Items]
Net rentable area | ft²	22
Other Office Locations
Operating Leased Assets [Line Items]
Remaining contractual obligation	$ 1,925

Commitments and Other Conting83

Commitments and Other Contingencies - Unallocated Severance-related Costs (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2016
Restructuring Cost and Reserve [Line Items]
Restructuring charges			$ 2,904
Payments for restructuring			3,953
Special Termination Benefits
Restructuring Cost and Reserve [Line Items]
Restructuring charges			2,072
Payments for restructuring			3,121
General and Administrative Expense | One-time Termination Benefits
Restructuring Cost and Reserve [Line Items]
Restructuring charges	$ 3,314		$ 486
General and Administrative Expense | Special Termination Benefits
Restructuring Cost and Reserve [Line Items]
Payments for restructuring		$ 2,732

Commitments and Other Conting84

Commitments and Other Contingencies - Non-core Assets Restructuring Costs (Details) - USD ($) $ in Thousands	1 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2016
Restructuring Cost and Reserve [Line Items]
Restructuring charges		$ 2,904
One-time Termination Benefits | Real Estate Segment
Restructuring Cost and Reserve [Line Items]
Restructuring charges		1,422
One-time Termination Benefits | Other Natural Resources
Restructuring Cost and Reserve [Line Items]
Restructuring charges		164
General and Administrative Expense | One-time Termination Benefits
Restructuring Cost and Reserve [Line Items]
Restructuring charges	$ 3,314	$ 486

Commitments and Other Conting85

Commitments and Other Contingencies - Restructuring Activities (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)
Restructuring Cost and Reserve [Line Items]
Beginning balance	$ (1,049)
Additions	(2,904)
Payments	3,953
Ending balance	0
Special Termination Benefits
Restructuring Cost and Reserve [Line Items]
Beginning balance	(1,049)
Additions	(2,072)
Payments	3,121
Ending balance	0
Facility Closing
Restructuring Cost and Reserve [Line Items]
Beginning balance	0
Additions	(832)
Payments	832
Ending balance	$ 0

Segment Information - Additiona

Segment Information - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2016multifamily_sitesegmentProject
Segment Reporting [Abstract]
Number of business segments | segment	3
Number of projects | Project	3
Number of multifamilly sales | multifamily_site	1
Concentration risk, percentage (more than)	10.00%

Segment Information - Segment R

Segment Information - Segment Revenues and Earnings (Detail) - USD ($) $ in Thousands		3 Months Ended								12 Months Ended
		Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Revenues		$ 64,497	$ 47,207	$ 47,992	$ 37,618	$ 105,392	$ 32,185	$ 43,625	$ 37,374	$ 197,314	$ 218,576	$ 238,164
Depreciation, depletion and amortization										11,447	45,085	41,715
Equity in earnings of unconsolidated ventures		2,251	$ 3,637	$ 188	$ 47	4,470	$ 2,909	$ 5,584	$ 3,045	6,123	16,008	8,685
Income (loss) before taxes from continuing operations										90,815	8,214	57,042
Total assets		733,208				972,246				733,208	972,246
Investment in unconsolidated ventures		77,611				82,453				77,611	82,453	65,005
Capital expenditures										6,138	14,690	37,653
Assets of discontinued operations		14				104,967				14	104,967
Operating Segments | Real Estate
Segment Reporting Information [Line Items]
Revenues										190,273	202,830	213,112
Depreciation, depletion and amortization										976	7,605	3,741
Equity in earnings of unconsolidated ventures										5,778	15,582	8,068
Income (loss) before taxes from continuing operations										121,420	67,678	96,906
Investment in unconsolidated ventures		77,611				82,453				77,611	82,453	65,005
Capital expenditures										5,783	13,644	28,980
Operating Segments | Oil and Gas
Segment Reporting Information [Line Items]
Revenues										5,076	9,094	15,690
Depreciation, depletion and amortization										145	383	684
Equity in earnings of unconsolidated ventures										173	275	586
Income (loss) before taxes from continuing operations										3,327	4,230	9,116
Investment in unconsolidated ventures		0				0				0	0	0
Capital expenditures										0	59	2,240
Operating Segments | Other Natural Resources
Segment Reporting Information [Line Items]
Revenues										1,965	6,652	9,362
Depreciation, depletion and amortization										352	540	497
Equity in earnings of unconsolidated ventures										172	151	31
Income (loss) before taxes from continuing operations										(4,625)	(608)	5,499
Investment in unconsolidated ventures		0				0				0	0	0
Capital expenditures										299	745	5,817
Items Not Allocated To Segments
Segment Reporting Information [Line Items]
Revenues										0	0	0
Depreciation, depletion and amortization										7,772	8,166	8,035
Equity in earnings of unconsolidated ventures										0	0	0
Income (loss) before taxes from continuing operations	[1]									(29,307)	(63,086)	(54,479)
Investment in unconsolidated ventures		0				0				0	0	0
Capital expenditures										56	242	616
Continuing Operations
Segment Reporting Information [Line Items]
Depreciation, depletion and amortization										9,245	16,694	$ 12,957
Total assets	[2]	733,194				867,279				733,194	867,279
Continuing Operations | Operating Segments | Real Estate
Segment Reporting Information [Line Items]
Total assets	[2]	403,062				691,238				403,062	691,238
Continuing Operations | Operating Segments | Oil and Gas
Segment Reporting Information [Line Items]
Total assets	[2]	38,907				39,469				38,907	39,469
Continuing Operations | Operating Segments | Other Natural Resources
Segment Reporting Information [Line Items]
Total assets	[2]	11,531				19,106				11,531	19,106
Continuing Operations | Items Not Allocated To Segments
Segment Reporting Information [Line Items]
Total assets	[2]	$ 279,694				$ 117,466				$ 279,694	$ 117,466
[1]	Items not allocated to segments consist of: For the Year 2016 2015 2014 (In thousands)General and administrative expense$(18,274) $(24,802) $(21,229)Share-based and long-term incentive compensation expense(4,425) (4,474) (3,417)Gain on sale of assets48,891 — —Interest expense(19,985) (34,066) (30,286)Loss on extinguishment of debt, net(35,864) — —Other corporate non-operating income350 256 453 $(29,307) $(63,086) $(54,479)
[2]	Total assets excludes assets of discontinued operations of $14 and $104,967 in 2016 and 2015.

Segment Information - Items Not

Segment Information - Items Not Allocated to Segments (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
General and administrative expense		$ (21,597)	$ (27,253)	$ (22,230)
Gain of sale of assets		166,747	1,585	29,512
Interest expense		(19,985)	(34,066)	(30,286)
Loss on extinguishment of debt, net		(35,864)	0	0
Other corporate non-operating income		1,718	3,006	8,588
Income (loss) before taxes from continuing operations		90,815	8,214	57,042
Items Not Allocated To Segments
Segment Reporting Information [Line Items]
General and administrative expense		(18,274)	(24,802)	(21,229)
Share-based and long-term incentive compensation expense		(4,425)	(4,474)	(3,417)
Gain of sale of assets		48,891	0	0
Interest expense		(19,985)	(34,066)	(30,286)
Loss on extinguishment of debt, net		(35,864)	0	0
Other corporate non-operating income		350	256	453
Income (loss) before taxes from continuing operations	[1]	$ (29,307)	$ (63,086)	$ (54,479)
[1]	Items not allocated to segments consist of: For the Year 2016 2015 2014 (In thousands)General and administrative expense$(18,274) $(24,802) $(21,229)Share-based and long-term incentive compensation expense(4,425) (4,474) (3,417)Gain on sale of assets48,891 — —Interest expense(19,985) (34,066) (30,286)Loss on extinguishment of debt, net(35,864) — —Other corporate non-operating income350 256 453 $(29,307) $(63,086) $(54,479)

Share Based Compensation - Comp

Share Based Compensation - Components of Share-Based Compensation Expense (Income) (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	$ 4,037	$ 4,246	$ 3,417
Deferred cash	388	228	0
Share-based and long-term incentive compensation	4,425	4,474	3,417
Cash Settled Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	717	(3,127)	(3,710)
Equity-settled awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	2,444	5,026	5,168
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	22	(8)	(25)
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	$ 854	$ 2,355	$ 1,984

Share Based Compensation - Shar

Share Based Compensation - Share Based Compensation Expense Included in Operating Expense (Income) (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based and long-term incentive compensation	$ 4,425	$ 4,474	$ 3,417
General and Administrative Expense
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based and long-term incentive compensation	3,323	2,451	1,001
Other Operating Expenses
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based and long-term incentive compensation	$ 1,102	$ 2,023	$ 2,416

Share Based Compensation - Addi

Share Based Compensation - Additional Information (Detail)	3 Months Ended		12 Months Ended
	Mar. 31, 2016directorshares	Sep. 30, 2015USD ($)	Dec. 31, 2016USD ($)$ / sharesshares	Dec. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2014USD ($)$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation			$ 4,037,000	$ 4,246,000	$ 3,417,000
Fair value of awards granted to retirement eligible employees and expensed at date of grant			600,000	$ 517,000	760,000
Unrecognized share-based compensation expense related to non-vested equity-settled awards, restricted stock and stock options			$ 1,878,000
Weighted average period over which amount will be recognized			1 year
Shares issued out of treasury stock | shares			300,491	288,089
Vesting of restricted stock awards and exercises of stock options, shares withheld | shares			25,082	51,521
Payroll taxes on restricted stock and stock options			$ 222,000	$ 762,000
Stock price of non-vested cash-settled awards | $ / shares			$ 13.30
Financial instruments subject to mandatory redemption, settlement terms, share value, amount, noncurrent		$ 17.50
Board of Director Fees
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation			$ 725,000	1,203,000	906,000
Cash Settled Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation			$ 717,000	(3,127,000)	(3,710,000)
Cash Settled Awards | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest			3 years
Cash Settled Awards | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest			4 years
Stock Appreciation Rights (SARs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest			4 years
Expiration period			10 years
Fair value of awards settled in cash			$ 154,000	206,000	$ 1,181,000
Fair value of vested cash-settled awards			$ 1,758,000	$ 3,757,000
Granted, equivalent units | shares			0
Cash Settled Restricted Stock Unit
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted, weighted average grant date fair value | $ / shares			$ 0	$ 13.26	$ 18.96
Fair value of awards settled in cash			$ 1,195,000	$ 2,469,000	$ 2,286,000
Aggregate current value of non-vested cash-settled awards			$ 555,000
Granted, equivalent units | shares			0
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest			3 years
Granted, equivalent units | shares			313,000
Restricted Stock Units (RSUs) | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest			3 years
Restricted Stock Units (RSUs) | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest			4 years
Market-leveraged stock units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest			3 years
Granted, equivalent units | shares				234,000	86,000
Number of shares to be issued if stock price increases by fifty percent | shares			351,000
Numbers of shares to be issued if stock price decreases by fifty percent | shares			117,000
Weighted average estimated fair value of options at grant date | $ / shares				$ 15.11	$ 20.38
Performance Stock Units Psu
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest			3 years
Equity-settled awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation			$ 2,444,000	$ 5,026,000	$ 5,168,000
Unrecognized share-based compensation expense related to non-vested equity-settled awards, restricted stock and stock options			$ 1,106,000
Weighted average period over which amount will be recognized			1 year
Granted, weighted average grant date fair value | $ / shares			$ 9.04
Fair value of vested cash-settled awards			$ 2,884,478	$ 4,451,000	$ 3,119,000
Granted, equivalent units | shares			313,000
Minimum increases in stock price			50.00%
Percentage of decrease in stock price			50.00%
Weighted average estimated fair value of options at grant date | $ / shares			$ 9.04	$ 12.99	$ 19.18
Special Performance | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Special performance stock unit awards to be issued | shares			0
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation			$ 22,000	$ (8,000)	$ (25,000)
Period over or after performance stock unit vest			3 years
Granted, weighted average grant date fair value | $ / shares			$ 0
Fair value of vested cash-settled awards			$ 44,000	88,000	341,000
Granted, equivalent units | shares			0
Minimum percent annualized return on assets vesting for stock unit awards			1.00%
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation			$ 854,000	2,355,000	1,984,000
Unrecognized share-based compensation expense related to non-vested equity-settled awards, restricted stock and stock options			$ 772,000
Weighted average period over which amount will be recognized			2 years
Period over or after performance stock unit vest		3 years	4 years
Expiration period		10 years	10 years
Fair value of vested stock options			$ 0	0	21,000
Intrinsic value of options exercised			$ 61,000	$ 0	568,000
Options outstanding | shares			1,836,000	2,171,000
Weighted average exercise price | $ / shares			$ 20.25
Weighted average remaining contractual term			5 years	5 years
Former Affiliated Entity | Pre Spin Stock Option Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest			4 years
Expiration period			10 years
Intrinsic value of options exercised			$ 0	$ 24,000	$ 352,000
Options outstanding | shares			17,000
Weighted average exercise price | $ / shares			$ 30.56
Weighted average remaining contractual term			1 year
Long Term Incentive Compensation
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Deferred cash compensation			$ 620,000
Requisite service period (in years)			2 years	3 years
Accrued liability			$ 539,000
Director
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of new directors | director	2
Granted (in shares) | shares	20,000
Tranche One | Director
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting, number | shares	6,500
Tranche Two | Director
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting, number | shares			6,500
Tranche Three | Director
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting, number | shares	7,000

Share Based Compensation - Summ

Share Based Compensation - Summarized Activity of Cash Settled Restricted Stock Unit Awards (Detail) - Cash Settled Restricted Stock Unit - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Balance at beginning of year	117
Granted, equivalent units	0
Vested, equivalent units	(41)
Forfeited, equivalent units	(34)
Balance at end of period	42	117
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Non-vested at beginning of year, weighted average grant date fair value	$ 16
Granted, weighted average grant date fair value	0	$ 13.26	$ 18.96
Vested, Weighted Average Grant Date Fair Value	18.84
Forfeited, weighted average grant date	13.83
Non-vested at end of period, weighted average grant date fair value	$ 14.98	$ 16

Share Based Compensation - Su93

Share Based Compensation - Summarized Activity of Cash-Settled Stock Appreciation Rights (Detail) - Stock Appreciation Rights (SARs) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Balance at beginning of year	487
Granted, rights outstanding	0
Exercised, rights outstanding	(52)
Forfeited, rights outstanding	(61)
Balance at end of period	374	487
Exercisable at end of period, rights outstanding	345
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Non-vested at beginning of year, weighted average grant date fair value	$ 12.97
Granted, weighted average exercise price	0
Exercised, weighted average exercise price	9.29
Forfeited, weighted average grant date	16.12
Non-vested at end of period, weighted average grant date fair value	12.97	$ 12.97
Exercisable at end of period, weighted average exercise price	$ 12.87
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Additional Disclosures [Abstract]
Exercisable at end of period, weighted average remaining contractual terms	3 years	4 years
Weighted average remaining contractual term	3 years
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value [Abstract]
Aggregate intrinsic value	$ 773	$ 404
Exercisable at end of period, aggregate intrinsic value	$ 773

Share Based Compensation - Equi

Share Based Compensation - Equity-Settled Awards (Detail) - Equity-settled awards shares in Thousands	12 Months Ended
	Dec. 31, 2016$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Balance at beginning of year | shares	631
Granted, equivalent units | shares	313
Vested, equivalent units | shares	(281)
Forfeited, equivalent units | shares	(108)
Balance at end of period | shares	555
Share-based Compensation Arrangement by Share-based Payment Award, Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Non-vested at beginning of year, weighted average grant date fair value | $ / shares	$ 18.25
Granted, weighted average grant date fair value | $ / shares	9.04
Vested, Weighted Average Grant Date Fair Value | $ / shares	15.12
Forfeited, weighted average grant date | $ / shares	17.91
Non-vested at end of period, weighted average grant date fair value | $ / shares	$ 14.70

Share Based Compensation - Su95

Share Based Compensation - Summarized Activity of Restricted Stock Awards (Detail) - Restricted Stock shares in Thousands	12 Months Ended
	Dec. 31, 2016$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Balance at beginning of year | shares	4
Granted, equivalent units | shares	0
Vested, equivalent units | shares	(4)
Forfeited, equivalent units | shares	0
Balance at end of period | shares	0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Non-vested at beginning of year, weighted average grant date fair value | $ / shares	$ 20.55
Granted, weighted average grant date fair value | $ / shares	0
Vested, Weighted Average Grant Date Fair Value | $ / shares	20.55
Forfeited, weighted average grant date | $ / shares	0
Non-vested at end of period, weighted average grant date fair value | $ / shares	$ 0

Share Based Compensation - Su96

Share Based Compensation - Summarized Activity of Stock Option Awards (Detail) - Stock Options - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Balance at beginning of year, options outstanding	2,171
Granted, options outstanding	53
Exercised, options outstanding	(35)
Forfeited, options outstanding	(353)
Balance at end of period, options outstanding	1,836	2,171
Exercisable at end of period, options outstanding	1,597
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price [Abstract]
Balance at beginning of year, weighted average exercise price	$ 19.56
Granted, weighted average exercise price	9.98
Exercised, weighted average exercise price	9.29
Forfeited, weighted average exercise price	20.03
Balance at end of period, weighted average exercise price	19.39	$ 19.56
Exercisable at end of period, weighted average exercise price	$ 20.25
Share-based Compensation Arrangement by Share-based Payment Award, Options, Aggregate Intrinsic Value [Abstract]
Weighted average remaining contractual term	5 years	5 years
Exercisable at end of period, weighted average remaining contractual term	4 years
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Aggregate intrinsic value	$ 449	$ 156
Exercisable at end of period, aggregate intrinsic value	$ 261

Share Based Compensation - Fair

Share Based Compensation - Fair Value of Stock Options Using Black-Scholes Option Pricing Model (Detail) - $ / shares	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Market-leveraged stock units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected stock price volatility		32.90%	42.20%
Risk-free interest rate		1.00%	0.70%
Expected dividend yield		0.00%	0.00%
Weighted average estimated fair value of options at grant date		$ 15.11	$ 20.38
Stock Options | Market Condition Vesting
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected stock price volatility	39.50%	45.60%
Risk-free interest rate	1.50%	1.80%
Expected life of options (years)	6 years	6 years
Expected dividend yield	0.00%	0.00%
Weighted average estimated fair value of options at grant date	$ 8.60	$ 6.51
Management | Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected stock price volatility		61.40%
Risk-free interest rate		2.20%
Expected dividend yield		0.00%
Weighted average estimated fair value of options at grant date		$ 7.87

Retirement Plans - Additional I

Retirement Plans - Additional Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Compensation and Retirement Disclosure [Abstract]
Expense of defined contribution retirement plans	$ 978	$ 1,060	$ 1,338
Unfunded liability for supplemental plan	$ 334	$ 802

Supplemental Oil and Gas Disc99

Supplemental Oil and Gas Disclosures (Unaudited) - Additional Information (Detail) bbl in Thousands, Mcf in Thousands		12 Months Ended
		Dec. 31, 2016well$ / MMBTU$ / BoebblMcf	Dec. 31, 2015Boewell	Dec. 31, 2015Boe$ / MMBTU	Dec. 31, 2015Boebbl	Dec. 31, 2015BoeMcf	Dec. 31, 2015Boe$ / Boe	Dec. 31, 2014Boewell$ / MMBTU$ / BoebblMcf
Supplemental Oil And Gas Reserve Information [Line Items]
New well addition | well		0	36					106
Crude Oil and NGL
Supplemental Oil And Gas Reserve Information [Line Items]
Average spot price | $ / Boe		42.75					50.28	94.99
Natural Gas in Mmbtu
Supplemental Oil And Gas Reserve Information [Line Items]
Average spot price | $ / MMBTU		2.48		2.59				4.35
Consolidated Entities
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, revisions of previous estimates								608
Oil | Consolidated Entities
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, sales of minerals in place	[1]	4,460			704			105
Proved developed and undeveloped reserves, revisions of previous estimates	[1]	(11)			855			608
Extensions and discoveries (added)	[1]	29			224			2,191
New PDP Reserves | Consolidated Entities
Supplemental Oil And Gas Reserve Information [Line Items]
Extensions and discoveries (added)								694
New PUD Reserves | Consolidated Entities
Supplemental Oil And Gas Reserve Information [Line Items]
Extensions and discoveries (added)								913
Oil Less Natural Gas Liquids | Consolidated Entities
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, sales of minerals in place	[1]	4,155
Natural Gas Liquids | Consolidated Entities
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, sales of minerals in place		305
Natural Gas | Consolidated Entities
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, sales of minerals in place | Mcf		3,756				1,223		218
Proved developed and undeveloped reserves, revisions of previous estimates		631			1,995	1,675		293
Extensions and discoveries (added) | Mcf		0				173		774
BOE
Supplemental Oil And Gas Reserve Information [Line Items]
Proved undeveloped reserve (Energy) | Boe			0	0	0	0	0	2,703,000
[1]	Includes natural gas liquids (NGLs).

Supplemental Oil and Gas Dis100

Supplemental Oil and Gas Disclosures (Unaudited) - Summary of Estimated Quantities of Proved Developed Oil and Natural Gas Reserves (Detail) bbl in Thousands, Mcf in Thousands		12 Months Ended
		Dec. 31, 2016bblMcf	Dec. 31, 2015bblMcf	Dec. 31, 2015bblMcf	Dec. 31, 2014bblMcf
Oil
Reserve Quantities [Line Items]
Beginning Balance	[1]	5,179	7,672
Proved developed reserves	[1]	446	5,179	5,179	5,269
Proved undeveloped reserves	[1]	0	0	0	2,403
Ending Balance	[1]	446	5,179		7,672
Natural Gas
Reserve Quantities [Line Items]
Beginning Balance | Mcf		9,220		14,400
Proved developed reserves | Mcf		5,035	9,220	9,220	12,599
Proved undeveloped reserves | Mcf		0	0	0	1,801
Ending Balance | Mcf		5,035		9,220	14,400
Consolidated Entities
Reserve Quantities [Line Items]
Revisions of previous estimates					608
Consolidated Entities | Oil
Reserve Quantities [Line Items]
Beginning Balance	[1]	5,179	7,672		5,824
Revisions of previous estimates	[1]	(11)	855		608
Extensions and discoveries	[1]	29	224		2,191
Acquisitions	[1]	0	0		85
Sales	[1]	(4,460)	(704)		(105)
Production	[1]	(291)	(1,158)		(931)
Ending Balance	[1]	446	5,179		7,672
Consolidated Entities | Natural Gas
Reserve Quantities [Line Items]
Beginning Balance | Mcf		7,957		12,649	13,630
Revisions of previous estimates		631	1,995	1,675	293
Extensions and discoveries | Mcf		0		173	774
Acquisitions | Mcf		0		0	31
Sales | Mcf		(3,756)		(1,223)	(218)
Production | Mcf		(996)		(1,967)	(1,861)
Ending Balance | Mcf		3,836		7,957	12,649
Equity Method Investee | Oil
Reserve Quantities [Line Items]
Beginning Balance	[1]	0	0		0
Revisions of previous estimates	[1]	0	0		0
Production	[1]	0	0		0
Ending Balance	[1]	0	0		0
Equity Method Investee | Natural Gas
Reserve Quantities [Line Items]
Beginning Balance | Mcf		1,263		1,751	2,332
Revisions of previous estimates | Mcf		79		(320)	(382)
Production | Mcf		(143)		(168)	(199)
Ending Balance | Mcf		1,199		1,263	1,751
[1]	Includes natural gas liquids (NGLs).

Supplemental Oil and Gas Dis101

Supplemental Oil and Gas Disclosures (Unaudited) - Capitalized Cost Related to Oil and Natural Gas Producing Activities (Detail) - Consolidated Entities - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Capitalized Costs Relating To Oil And Gas Producing Activities [Line Items]
Unproved oil and gas properties	$ 374	$ 19,441
Proved oil and gas properties	5,159	119,414
Total costs	5,533	138,855
Less accumulated depreciation, depletion and amortization	(4,751)	(58,242)
Net capitalized costs	$ 782	$ 80,613

Supplemental Oil and Gas Dis102

Supplemental Oil and Gas Disclosures (Unaudited) - Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development (Detail) - Consolidated Entities - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Costs incurred, acquisition of oil and gas properties with proved reserves	$ 0	$ 0	$ 2,001
Costs incurred, acquisition of unproved oil and gas properties	15	4,832	25,666
Exploration costs	21	17,922	39,399
Development costs	537	27,609	40,277
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities	$ 573	$ 50,363	$ 107,343

Supplemental Oil and Gas Dis103

Supplemental Oil and Gas Disclosures (Unaudited) - Estimates of Future Cash Flows from Proved Developed Oil and Natural Gas Reserves (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Standardized measure of discounted future net cash flows	$ 10,985	$ 67,498	$ 165,616	$ 136,853
Consolidated Entities
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future cash inflows	24,304	216,588	665,657
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Production Costs	(2,988)	(93,623)	(271,735)
Future income tax expenses	(3,926)	(22,218)	(106,002)
Future net cash flows	17,390	100,747	287,920
10% annual discount for estimated timing of cash flows	(7,077)	(33,951)	(124,079)
Standardized measure of discounted future net cash flows	10,313	66,796	163,841	135,553
Equity Method Investee
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future cash inflows	2,010	2,283	6,186
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Production Costs	(216)	(245)	(664)
Future income tax expenses	(537)	(774)	(2,098)
Future net cash flows	1,257	1,264	3,424
10% annual discount for estimated timing of cash flows	(585)	(562)	(1,649)
Standardized measure of discounted future net cash flows	$ 672	$ 702	$ 1,775	$ 1,300

Supplemental Oil and Gas Dis104

Supplemental Oil and Gas Disclosures (Unaudited) - Changes in Standardized Measure of Discounted Future Net Cash Flow (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule Of Changes In Standardized Measure Of Discounted Future Net Cash Flows [Line Items]
Beginning Balance	$ 67,498	$ 165,616	$ 136,853
Changes resulting from:
Net change in sales prices and production costs	(3,645)	(137,648)	507
Net change in future development costs	0	92	1,308
Sales of oil and gas, net of production costs	(5,871)	(32,160)	(63,979)
Net change due to extensions and discoveries	410	11,747	58,228
Net change due to acquisition of reserves	0	0	2,778
Net change due to divestitures of reserves	(63,535)	(15,855)	(5,804)
Net change due to revisions of quantity estimates	1,367	(15,431)	14,960
Previously estimated development costs incurred	0	(15,096)	(15,497)
Accretion of discount	3,105	22,886	18,277
Net change in timing and other	(208)	3,808	4,313
Net change in income taxes	11,864	49,347	(17,322)
Aggregate change for the year	(56,513)	(98,118)	28,763
Ending Balance	10,985	67,498	165,616
Consolidated Entities
Schedule Of Changes In Standardized Measure Of Discounted Future Net Cash Flows [Line Items]
Beginning Balance	66,796	163,841	135,553
Changes resulting from:
Net change in sales prices and production costs	(3,585)	(136,536)	(1,064)
Net change in future development costs	0	92	1,308
Sales of oil and gas, net of production costs	(5,663)	(31,732)	(63,192)
Net change due to extensions and discoveries	410	11,747	58,228
Net change due to acquisition of reserves	0	0	2,778
Net change due to divestitures of reserves	(63,535)	(15,855)	(5,804)
Net change due to revisions of quantity estimates	1,304	(15,164)	15,303
Previously estimated development costs incurred	0	(15,096)	(15,497)
Accretion of discount	2,992	22,600	18,067
Net change in timing and other	(128)	4,018	4,198
Net change in income taxes	11,722	48,689	(17,031)
Aggregate change for the year	(56,483)	(97,045)	28,288
Ending Balance	10,313	66,796	163,841
Equity Method Investee
Schedule Of Changes In Standardized Measure Of Discounted Future Net Cash Flows [Line Items]
Beginning Balance	702	1,775	1,300
Changes resulting from:
Net change in sales prices and production costs	(60)	(1,112)	1,571
Net change in future development costs	0	0	0
Sales of oil and gas, net of production costs	(208)	(428)	(787)
Net change due to extensions and discoveries	0	0	0
Net change due to acquisition of reserves	0	0	0
Net change due to divestitures of reserves		0	0
Net change due to revisions of quantity estimates	63	(267)	(343)
Previously estimated development costs incurred	0	0	0
Accretion of discount	113	286	210
Net change in timing and other	(80)	(210)	115
Net change in income taxes	142	658	(291)
Aggregate change for the year	(30)	(1,073)	475
Ending Balance	$ 672	$ 702	$ 1,775

Supplemental Oil and Gas Dis105

Supplemental Oil and Gas Disclosures (Unaudited) - Information About Results of Operations of Oil and Natural Gas Interests (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Consolidated entities
Results of operations	$ (5,777)	$ (170,567)	$ (19,703)
Consolidated Entities
Consolidated entities
Revenues	10,111	51,553	82,919
Production costs	(4,392)	(19,820)	(19,727)
Exploration costs	(124)	(11,864)	(17,416)
Depreciation, depletion, amortization	(2,157)	(28,774)	(29,442)
Results of Operations, Impairment of Oil and Gas Properties	(612)	(164,831)	(32,665)
Oil and gas administrative expenses	(8,700)	(11,700)	(17,000)
Results of Operations, Accretion of Asset Retirement Obligations	(56)	(144)	(121)
Income tax expenses	(20)	14,717	13,398
Results of operations	(5,950)	(170,863)	(20,054)
Equity Method Investee
Consolidated entities
Royalty revenues	284	428	786
Production costs	(76)	(102)	(105)
Oil and gas administrative expenses	(35)	(51)	(95)
Income tax expenses	0	21	(235)
Results of operations	$ 173	$ 296	$ 351

Summary of Quarterly Results106

Summary of Quarterly Results of Operations (Unaudited) - Summary of Quarterly Results of Operations (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Total revenues	$ 64,497	$ 47,207	$ 47,992	$ 37,618	$ 105,392	$ 32,185	$ 43,625	$ 37,374	$ 197,314	$ 218,576	$ 238,164
Gross profit	17,352	17,403	(24,953)	18,579	46,655	12,879	21,060	18,012
Operating income (loss)	50,980	6,256	69,528	13,590	29,929	(8,482)	5,919	(3,424)	140,354	23,942	70,560
Equity in earnings of unconsolidated ventures	2,251	3,637	188	47	4,470	2,909	5,584	3,045	6,123	16,008	8,685
Income (loss) before taxes	51,069	7,163	26,591	5,992	26,747	(13,711)	3,382	(8,204)	92,346	8,890	57,547
Income (loss) discontinued operations, net of taxes	563	(7,164)	(2,048)	(8,216)	(39,482)	(106,937)	(36,992)	(2,719)	(16,865)	(186,130)	(19,609)
Net income (loss) attributable to Forestar Group Inc.	$ 43,745	$ 9,665	$ 9,614	$ (4,376)	$ (6,166)	$ (164,216)	$ (34,507)	$ (8,158)	$ 58,648	$ (213,047)	$ 16,583
Net income (loss) per share -- basic
Continuing operations, basic (usd per share)	$ 1.03	$ 0.40	$ 0.28	$ 0.11	$ 0.97	$ (1.67)	$ 0.07	$ (0.16)	$ 1.80	$ (0.79)	$ 0.84
Discontinued operations, basic (usd per share)	0.01	(0.17)	(0.05)	(0.24)	(1.15)	(3.12)	(1.08)	(0.08)	(0.40)	(5.43)	(0.46)
Net income (loss) per share - basic	1.04	0.23	0.23	(0.13)	(0.18)	(4.79)	(1.01)	(0.24)	1.40	(6.22)	0.38
Net income (loss) per share -- diluted
Continuing operations, diluted (usd per share)	1.02	0.40	0.28	0.09	0.79	(1.67)	0.06	(0.16)	1.78	(0.79)	0.83
Discontinued operations, diluted (usd per share)	0.01	(0.17)	(0.05)	(0.19)	(0.93)	(3.12)	(0.87)	(0.08)	(0.40)	(5.43)	(0.45)
Net income (loss) per share - diluted	$ 1.03	$ 0.23	$ 0.23	$ (0.10)	$ (0.14)	$ (4.79)	$ (0.81)	$ (0.24)	$ 1.38	$ (6.22)	$ 0.38
Continuing Operations
Supplemental Oil And Gas Reserve Information [Line Items]
Impairment of oil and gas properties	$ 3,874	$ 7,627	$ 48,826	$ 0	$ 315	$ 0	$ 225	$ 504
Discontinued Operations
Supplemental Oil And Gas Reserve Information [Line Items]
Impairment of oil and gas properties	$ 0	$ 0	$ 612	$ 0	$ 37,646	$ 81,240	$ 45,938	$ 7

Subsequent Events (Details)

Subsequent Events (Details)	Feb. 17, 2017USD ($)	Mar. 31, 2017USD ($)	Dec. 31, 2016USD ($)$ / shares	Dec. 31, 2015USD ($)$ / shares	Dec. 31, 2014USD ($)	Jan. 05, 2017right$ / sharesshares
Subsequent Event [Line Items]
Common stock, par value | $ / shares			$ 1	$ 1
Proceeds from sale of oil and gas property and equipment			$ 80,374,000	$ 17,800,000	$ 17,660,000
Non-cash impairment charges			$ 60,939,000	$ 108,184,000	$ 15,934,000
Forecast | The Mineral Companies | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Subsequent Event [Line Items]
Gain on disposition of oil and gas property		$ 82,400,000
Gain of sale of assets		10,600,000
Non-cash impairment charges		$ 37,900,000
Subsequent Event
Subsequent Event [Line Items]
Number of rights issued | right						1
Common stock, par value | $ / shares						$ 1
Subsequent Event | The Mineral Companies | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Subsequent Event [Line Items]
Purchase price of properties sold	$ 85,600,000
Proceeds from sale of oil and gas property and equipment	$ 75,000,000
Subsequent Event | Series B Preferred Stock
Subsequent Event [Line Items]
Number of securities called by each right | shares						0.001
Preferred stock, par value | $ / shares						$ 0.01
Purchase price of stock called by each right (dollars in share) | $ / shares						$ 50

Schedule III - Consolidated Rea

Schedule III - Consolidated Real Estate and Accumulated Depreciation (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 238,077
Improvements less Cost of Sales and Other		49,971
Carrying Costs	[1]	4,955
Land & Land Improvements		293,003
Total		293,003	$ 618,844	$ 607,133	$ 547,530
Accumulated depreciation		0	$ (32,129)	$ (31,377)	$ (28,066)
Amount of encumbrances		486
Entitled, developed and under development projects
Real Estate and Accumulated Depreciation [Line Items]
Land		234,047
Improvements less Cost of Sales and Other		24,857
Carrying Costs	[1]	4,955
Land & Land Improvements		263,859
Total		263,859
Amount of encumbrances		486
Entitled, developed and under development projects | Other County | Other Property
Real Estate and Accumulated Depreciation [Line Items]
Land		5,222
Improvements less Cost of Sales and Other		(276)
Carrying Costs	[1]	25
Land & Land Improvements		4,971
Total		4,971
Entitled, developed and under development projects | Tennessee | Williamson County | Morgan Farms
Real Estate and Accumulated Depreciation [Line Items]
Land		6,841
Improvements less Cost of Sales and Other		(1,808)
Carrying Costs	[1]	88
Land & Land Improvements		5,121
Total		$ 5,121
Date of Construction		2,013
Date Acquired		2,013
Entitled, developed and under development projects | Tennessee | Williamson County | Scales Farmstead
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,575
Improvements less Cost of Sales and Other		9,319
Carrying Costs	[1]	389
Land & Land Improvements		13,283
Total		$ 13,283
Date Acquired		2,015
Entitled, developed and under development projects | Tennessee | Williamson County | Weatherford Estates
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 856
Improvements less Cost of Sales and Other		374
Carrying Costs	[1]	138
Land & Land Improvements		1,368
Total		$ 1,368
Date of Construction		2,015
Date Acquired		2,014
Entitled, developed and under development projects | Tennessee | Williamson County | Beckwith Crossing
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,294
Improvements less Cost of Sales and Other		2,397
Carrying Costs	[1]	161
Land & Land Improvements		3,852
Total		$ 3,852
Date of Construction		2,015
Date Acquired		2,014
Entitled, developed and under development projects | Arizona | Pima County | Dove Mountain
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 5,860
Improvements less Cost of Sales and Other		3
Land & Land Improvements		5,863
Total		$ 5,863
Date Acquired		2,015
Entitled, developed and under development projects | California | Contra Costa County | San Joaquin River
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 12,225
Improvements less Cost of Sales and Other		(10,558)
Land & Land Improvements		1,667
Total		1,667
Entitled, developed and under development projects | Colorado | Douglas County | Pinery West
Real Estate and Accumulated Depreciation [Line Items]
Land		7,308
Improvements less Cost of Sales and Other		3,791
Land & Land Improvements		11,099
Total		$ 11,099
Date of Construction		2,006
Date Acquired		2,006
Entitled, developed and under development projects | Colorado | Douglas County | Cielo
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,933
Improvements less Cost of Sales and Other		2,645
Land & Land Improvements		6,578
Total		$ 6,578
Date Acquired		2,016
Entitled, developed and under development projects | Colorado | Weld County | Buffalo Highlands
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,001
Improvements less Cost of Sales and Other		(295)
Land & Land Improvements		2,706
Total		$ 2,706
Date of Construction		2,006
Date Acquired		2,005
Entitled, developed and under development projects | Colorado | Weld County | Johnstown Farms
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 2,749
Improvements less Cost of Sales and Other		4,189
Carrying Costs	[1]	100
Land & Land Improvements		7,038
Total		$ 7,038
Date of Construction		2,002
Date Acquired		2,002
Entitled, developed and under development projects | Colorado | Weld County | Stone Braker
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,878
Improvements less Cost of Sales and Other		(1,786)
Land & Land Improvements		2,092
Total		$ 2,092
Date of Construction		2,005
Date Acquired		2,005
Entitled, developed and under development projects | Georgia | Cobb County | West Oaks
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,669
Improvements less Cost of Sales and Other		1,543
Land & Land Improvements		3,212
Total		$ 3,212
Date of Construction		2,015
Date Acquired		2,015
Entitled, developed and under development projects | Georgia | Paulding County | Harris Place
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 265
Improvements less Cost of Sales and Other		(111)
Land & Land Improvements		154
Total		$ 154
Date Acquired		2,012
Entitled, developed and under development projects | Georgia | Paulding County | Seven Hills
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 2,964
Improvements less Cost of Sales and Other		1,162
Carrying Costs	[1]	13
Land & Land Improvements		4,139
Total		$ 4,139
Date Acquired		2,012
Entitled, developed and under development projects | North Carolina | Cabbarus County | Moss Creek
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,254
Improvements less Cost of Sales and Other		101
Land & Land Improvements		1,355
Total		$ 1,355
Date Acquired		2,016
Entitled, developed and under development projects | North Carolina | Mechlanburg County | Walden
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 12,085
Improvements less Cost of Sales and Other		2,279
Carrying Costs	[1]	87
Land & Land Improvements		14,451
Total		$ 14,451
Date Acquired		2,015
Entitled, developed and under development projects | South Carolina | York County | Habersham
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,877
Improvements less Cost of Sales and Other		1,128
Carrying Costs	[1]	421
Land & Land Improvements		5,426
Total		$ 5,426
Date of Construction		2,014
Date Acquired		2,013
Entitled, developed and under development projects | South Carolina | Lancaster County | Ansley
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 5,089
Improvements less Cost of Sales and Other		1,594
Land & Land Improvements		6,683
Total		$ 6,683
Date Acquired		2,015
Entitled, developed and under development projects | Texas | Hays County | Arrowhead Ranch
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 12,856
Improvements less Cost of Sales and Other		9,204
Carrying Costs	[1]	233
Land & Land Improvements		22,293
Total		$ 22,293
Date of Construction		2,015
Date Acquired		2,007
Entitled, developed and under development projects | Texas | Tarrant County | Summer Creek Ranch
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 2,887
Improvements less Cost of Sales and Other		(1,377)
Land & Land Improvements		1,510
Total		$ 1,510
Date Acquired		2,012
Entitled, developed and under development projects | Texas | Tarrant County | Bar C Ranch
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,365
Improvements less Cost of Sales and Other		842
Carrying Costs	[1]	197
Land & Land Improvements		2,404
Total		$ 2,404
Date Acquired		2,012
Entitled, developed and under development projects | Texas | Calhoun County | Caracol
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 8,603
Improvements less Cost of Sales and Other		(8,025)
Land & Land Improvements		578
Total		$ 578
Date of Construction		2,006
Date Acquired		2,006
Entitled, developed and under development projects | Texas | Bastrop County | Hunters Crossing
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,613
Improvements less Cost of Sales and Other		5,226
Land & Land Improvements		8,839
Total		$ 8,839
Date of Construction		2,001
Date Acquired		2,001
Entitled, developed and under development projects | Texas | Bexar County | Cibolo Canyons
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 17,305
Improvements less Cost of Sales and Other		26,397
Carrying Costs	[1]	1,203
Land & Land Improvements		44,905
Total		$ 44,905
Date of Construction		2,004
Date Acquired		1,986
Entitled, developed and under development projects | Texas | Harris County | City Park
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,946
Improvements less Cost of Sales and Other		(2,243)
Carrying Costs	[1]	229
Land & Land Improvements		1,932
Total		$ 1,932
Date of Construction		2,002
Date Acquired		2,001
Entitled, developed and under development projects | Texas | Harris County | Barrington
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 8,950
Improvements less Cost of Sales and Other		(7,483)
Land & Land Improvements		1,467
Total		$ 1,467
Date Acquired		2,011
Entitled, developed and under development projects | Texas | Harris County | Imperial Forest
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 5,345
Improvements less Cost of Sales and Other		(957)
Carrying Costs	[1]	4
Land & Land Improvements		4,392
Total		$ 4,392
Date of Construction		2,015
Date Acquired		2,014
Entitled, developed and under development projects | Texas | Collin County | Lakes Of Prosper
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 8,951
Improvements less Cost of Sales and Other		(3,005)
Carrying Costs	[1]	348
Land & Land Improvements		6,294
Total		$ 6,294
Date Acquired		2,012
Entitled, developed and under development projects | Texas | Collin County | Park Place
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 2,177
Improvements less Cost of Sales and Other		(4)
Carrying Costs	[1]	183
Land & Land Improvements		2,356
Total		$ 2,356
Date of Construction		2,014
Date Acquired		2,013
Entitled, developed and under development projects | Texas | Collin County | Timber Creek
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 7,282
Improvements less Cost of Sales and Other		9,862
Land & Land Improvements		17,144
Total		$ 17,144
Date of Construction		2,007
Date Acquired		2,007
Entitled, developed and under development projects | Texas | Collin County | Village Park
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 4,772
Improvements less Cost of Sales and Other		(4,720)
Land & Land Improvements		52
Total		$ 52
Date Acquired		2,012
Entitled, developed and under development projects | Texas | Comal County | Oak Creek Estates
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,921
Improvements less Cost of Sales and Other		685
Carrying Costs	[1]	22
Land & Land Improvements		2,628
Total		$ 2,628
Date of Construction		2,006
Date Acquired		2,005
Entitled, developed and under development projects | Texas | Dallas County | Stoney Creek
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 12,822
Improvements less Cost of Sales and Other		327
Carrying Costs	[1]	443
Land & Land Improvements		13,592
Total		$ 13,592
Date of Construction		2,007
Date Acquired		2,007
Entitled, developed and under development projects | Texas | Denton County | Lantana
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 27,673
Improvements less Cost of Sales and Other		(11,242)
Carrying Costs	[1]	529
Land & Land Improvements		16,960
Total		$ 16,960
Date of Construction		2,000
Date Acquired		1,999
Entitled, developed and under development projects | Texas | Denton County | River's Edge
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,227
Improvements less Cost of Sales and Other		436
Land & Land Improvements		1,663
Total		$ 1,663
Date Acquired		2,014
Entitled, developed and under development projects | Texas | Denton County | The Preserve At Pecan Creek
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 5,855
Improvements less Cost of Sales and Other		(1,387)
Carrying Costs	[1]	47
Land & Land Improvements		4,515
Total		$ 4,515
Date of Construction		2,006
Date Acquired		2,005
Entitled, developed and under development projects | Texas | Fort Bend County | Summer Lakes
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 4,269
Improvements less Cost of Sales and Other		374
Carrying Costs	[1]	78
Land & Land Improvements		4,721
Total		$ 4,721
Date of Construction		2,013
Date Acquired		2,012
Entitled, developed and under development projects | Texas | Fort Bend County | Summer Park
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 4,804
Improvements less Cost of Sales and Other		(2,557)
Carrying Costs	[1]	17
Land & Land Improvements		2,264
Total		$ 2,264
Date of Construction		2,013
Date Acquired		2,012
Entitled, developed and under development projects | Texas | Fort Bend County | Willow Creek Farms
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,479
Improvements less Cost of Sales and Other		(1,187)
Land & Land Improvements		2,292
Total		$ 2,292
Date of Construction		2,012
Date Acquired		2,012
Amount of encumbrances		$ 486
Undeveloped Land Type
Real Estate and Accumulated Depreciation [Line Items]
Land		4,030
Improvements less Cost of Sales and Other		25,114
Land & Land Improvements		29,144
Total		29,144
Undeveloped Land Type | California | Los Angeles | Land In Entitlement Process
Real Estate and Accumulated Depreciation [Line Items]
Land		3,950
Improvements less Cost of Sales and Other		20,838
Land & Land Improvements		24,788
Total		$ 24,788
Date Acquired		1,997
Undeveloped Land Type | Georgia | Cherokee County | Undeveloped Land
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 80
Improvements less Cost of Sales and Other
Land & Land Improvements		80
Total		80
Undeveloped Land Type | Texas | Undeveloped Land
Real Estate and Accumulated Depreciation [Line Items]
Improvements less Cost of Sales and Other		5
Land & Land Improvements		5
Total		5
Undeveloped Land Type | Texas | Bexar County | Undeveloped Land
Real Estate and Accumulated Depreciation [Line Items]
Improvements less Cost of Sales and Other		2,548
Land & Land Improvements		2,548
Total		2,548
Undeveloped Land Type | Texas | Montgomery County | Undeveloped Land
Real Estate and Accumulated Depreciation [Line Items]
Improvements less Cost of Sales and Other		1,723
Land & Land Improvements		1,723
Total		$ 1,723
[1]	Includes natural gas liquids (NGLs).

Schedule III - Reconciliation o

Schedule III - Reconciliation of Real Estate and Accumulated Depreciation (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
SEC Schedule III, Real Estate and Accumulated Depreciation Disclosure [Abstract]
Beginning balance	$ 618,844	$ 607,133	$ 547,530
Amounts capitalized	89,780	124,633	214,184
Amounts retired or adjusted	(415,621)	(112,922)	(154,581)
Ending balance	293,003	618,844	607,133
Beginning balance	(32,129)	(31,377)	(28,066)
Depreciation expense	(816)	(6,810)	(3,319)
Amounts retired or adjusted	32,945	6,058	8
Ending balance	$ 0	$ (32,129)	$ (31,377)