Forestar (FOR) 10-K 28 Feb 18 2017 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Feb. 23, 2018	Jun. 30, 2017
Entity Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2017
Document Fiscal Year Focus	2,017
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	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		41,938,936
Entity Public Float			$ 707

CONSOLIDATED BALANCE SHEET

CONSOLIDATED BALANCE SHEET - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
ASSETS
Cash and cash equivalents	$ 321,783	$ 265,798
Restricted cash	40,017	275
Real estate, net	130,380	293,003
Assets of discontinued operations	0	14
Assets held for sale	181,607	30,377
Investment in unconsolidated ventures	64,579	77,611
Receivables, net	6,307	8,931
Income taxes receivable	6,674	10,867
Prepaid expenses	3,118	2,000
Property and equipment, net	2,003	3,116
Deferred tax asset, net	2,028	323
Goodwill and other intangible assets	448	37,900
Other assets	2,968	2,993
TOTAL ASSETS	761,912	733,208
LIABILITIES AND EQUITY
Accounts payable	2,382	4,804
Accrued employee compensation and benefits	8,994	4,126
Accrued property taxes	2,153	2,008
Accrued interest	1,489	1,585
Earnest money deposits	11,940	10,511
Other accrued expenses	5,942	12,598
Liabilities of discontinued operations	0	5,295
Liabilities held for sale	1,017	103
Other liabilities	13,934	19,702
Debt, net	108,429	110,358
TOTAL LIABILITIES	156,280	171,090
COMMITMENTS AND CONTINGENCIES
Forestar Group Inc. shareholders’ equity:
Common stock, par value $1.00 per share, 200,000,000 authorized shares, 41,938,936 issued at December 31, 2017 and 44,803,603 issued at December 31, 2016	41,939	44,804
Additional paid-in capital	505,977	553,005
Retained earnings	56,296	12,602
Treasury stock, at cost, 0 shares at December 31, 2017 and 3,187,253 shares at December 31, 2016	0	(49,760)
Total Forestar Group Inc. shareholders’ equity	604,212	560,651
Noncontrolling interests	1,420	1,467
TOTAL EQUITY	605,632	562,118
TOTAL LIABILITIES AND EQUITY	$ 761,912	$ 733,208

CONSOLIDATED BALANCE SHEET (Par

CONSOLIDATED BALANCE SHEET (Parenthetical) - $ / shares	Dec. 31, 2017	Dec. 31, 2016
Statement of Financial Position [Abstract]
Common stock, par value (in usd per share)	$ 1	$ 1
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares issued	41,938,936	44,803,603
Treasury stock, common shares	0	3,187,253

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME (LOSS) - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
REVENUES
Real estate sales and other	$ 112,655	$ 176,535	$ 120,022
Commercial and income producing properties	91	13,738	82,808
Real estate	112,746	190,273	202,830
Mineral resources	1,502	5,076	9,094
Other	74	1,965	6,652
Total revenues	114,322	197,314	218,576
COST AND EXPENSES
Cost of real estate sales and other	(65,012)	(147,653)	(52,640)
Cost of commercial and income producing properties	(2)	(15,442)	(61,251)
Cost of mineral resources	(38,315)	(763)	(2,998)
Cost of other	(6,450)	(5,075)	(3,081)
Other operating	(21,658)	(33,177)	(48,996)
General and administrative	(56,531)	(21,597)	(27,253)
Total cost and expenses	(187,968)	(223,707)	(196,219)
GAIN ON SALE OF ASSETS	113,411	166,747	1,585
OPERATING INCOME	39,765	140,354	23,942
Equity in earnings of unconsolidated ventures	17,899	6,123	16,008
Interest expense	(8,532)	(19,985)	(34,066)
Loss on extinguishment of debt, net	(611)	(35,864)	0
Other non-operating income	3,600	1,718	3,006
INCOME FROM CONTINUING OPERATIONS BEFORE TAXES	52,121	92,346	8,890
Income tax expense	(45,820)	(15,302)	(35,131)
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	6,301	77,044	(26,241)
INCOME (LOSS) FROM DISCONTINUED OPERATIONS, NET OF TAXES	46,031	(16,865)	(186,130)
CONSOLIDATED NET INCOME (LOSS)	52,332	60,179	(212,371)
Less: Net (income) attributable to noncontrolling interests	(2,078)	(1,531)	(676)
NET INCOME (LOSS) ATTRIBUTABLE TO FORESTAR GROUP INC.	$ 50,254	$ 58,648	$ (213,047)
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING
Basic (shares)	42,143	34,546	34,266
Diluted (shares)	42,381	42,334	34,266
NET INCOME (LOSS) PER BASIC SHARE
Continuing operations, basic (usd per share)	$ 0.10	$ 1.80	$ (0.79)
Discontinued operations, basic (usd per share)	1.09	(0.40)	(5.43)
Basic (usd per share)	1.19	1.40	(6.22)
NET INCOME (LOSS) PER DILUTED SHARE
Continuing operations, diluted (usd per share)	0.10	1.78	(0.79)
Discontinued operations, diluted (usd per share)	1.09	(0.40)	(5.43)
Diluted (usd per share)	$ 1.19	$ 1.38	$ (6.22)

CONSOLIDATED STATEMENTS OF EQUI

CONSOLIDATED STATEMENTS OF EQUITY - USD ($)	Total	Common Stock	Additional Paid-in Capital	Treasury Stock	Retained Earnings	Noncontrolling Interest	Stock Options	Stock OptionsAdditional Paid-in Capital	Stock OptionsTreasury Stock	Former Affiliated EntityStock Options	Former Affiliated EntityStock OptionsAdditional Paid-in Capital	Former Affiliated EntityStock OptionsTreasury Stock
Beginning Balances at Dec. 31, 2014	$ 709,742,000	$ 36,947,000	$ 558,945,000	$ (55,691,000)	$ 167,001,000	$ 2,540,000
Beginning Balances, Shares at Dec. 31, 2014		36,946,603		(3,485,278)
Net income	(212,371,000)				(213,047,000)	676,000
Distributions to noncontrolling interest	(701,000)					(701,000)
Issuances of common stock, Shares				335,611
Issuances of common stock, Value			(5,362,000)	$ 5,362,000
Issuances from exercises of stock options, net of swaps, Shares												3,999
Issuances from exercises of stock options, net of swaps, Value										$ 31,000	$ (33,000)	$ 64,000
Shares withheld for payroll taxes, Shares				(51,521)
Shares withheld for payroll taxes, Value	(762,000)		(1,000)	$ (761,000)
Forfeitures of restricted stock, Shares				(6,579)
Forfeitures of restricted stock, Value	0		125,000	$ (125,000)
Share-based compensation	8,576,000		8,576,000
Tax benefit from exercise of restricted stock units and stock options and vested restricted stock	(400,000)		(400,000)
Ending Balances at Dec. 31, 2015	504,115,000	$ 36,947,000	561,850,000	$ (51,151,000)	(46,046,000)	2,515,000
Ending Balances, Shares at Dec. 31, 2015		36,946,603		(3,203,768)
Net income	60,179,000				58,648,000	1,531,000
Distributions to noncontrolling interest	(2,579,000)					(2,579,000)
Issuances of common stock, Shares				288,397
Issuances of common stock, Value	$ 0		(4,570,000)	$ 4,570,000
Issuances from exercises of stock options, net of swaps, Shares									35,406
Issuances from exercises of stock options, net of swaps, Value							$ 328,000	$ (224,000)	$ 552,000
Shares withheld for payroll taxes, Shares	(25,082)			(23,312)
Shares withheld for payroll taxes, Value	$ (222,000)		(28,000)	$ (194,000)
Shares repurchased, Shares	(283,976)			(283,976)
Shares repurchased, Value	$ (3,537,000)			$ (3,537,000)
Share-based compensation	4,045,000		4,045,000
Settlement of tangible equity units, Shares		7,857,000
Settlement of tangible equity units, Value		$ 7,857,000	(7,857,000)
Reacquisition of equity component related to convertible debt	(211,000)		(211,000)
Ending Balances at Dec. 31, 2016	562,118,000	$ 44,804,000	553,005,000	$ (49,760,000)	12,602,000	1,467,000
Ending Balances, Shares at Dec. 31, 2016		44,803,603		(3,187,253)
Net income	52,332,000				50,254,000	2,078,000
Distributions to noncontrolling interest	(2,125,000)					(2,125,000)
Issuances of common stock, Shares				335,261
Issuances of common stock, Value	$ 0		(5,224,000)	$ 5,224,000
Issuances from exercises of stock options, net of swaps, Shares							768,000		63,195
Issuances from exercises of stock options, net of swaps, Value							$ 616,000	$ (367,000)	$ 983,000
Shares withheld for payroll taxes, Shares	(75,870)			(75,870)
Shares withheld for payroll taxes, Value	$ (981,000)		0	$ (981,000)
Shares repurchased, Shares				2,864,667
Shares repurchased, Value	0	$ (2,864,667)	(35,109,000)	$ 44,534,000	(6,560,000)
Share-based compensation	6,458,000		6,458,000
Settlement of tangible equity units, Shares		0
Settlement of tangible equity units, Value	(12,786,000)	$ 0	(12,786,000)
Ending Balances at Dec. 31, 2017	$ 605,632,000	$ 41,939,000	$ 505,977,000	$ 0	$ 56,296,000	$ 1,420,000
Ending Balances, Shares at Dec. 31, 2017		41,938,936		0

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
CASH FLOWS FROM OPERATING ACTIVITIES:
Consolidated net income (loss)	$ 52,332	$ 60,179	$ (212,371)
Adjustments:
Depreciation, depletion and amortization	5,463	11,447	45,085
Change in deferred income taxes	(1,705)	(1,360)	41,261
Equity in earnings of unconsolidated ventures	(17,899)	(6,123)	(16,008)
Distributions of earnings of unconsolidated ventures	23,041	7,719	12,741
Share-based compensation	6,643	4,037	4,246
Real estate cost of sales	63,999	98,412	87,733
Dry hole and unproved leasehold impairment costs	0	0	67,639
Real estate development and acquisition expenditures, net	(103,904)	(81,179)	(107,988)
Reimbursements from utility and improvement districts	20,071	27,107	15,176
Asset impairments	47,172	60,939	108,184
Loss on debt extinguishment, net	611	35,864	0
Gain on sale of assets	(113,214)	(153,083)	(879)
Other	2,877	5,359	4,680
Changes in:
Notes and accounts receivables	2,686	13,214	(978)
Prepaid expenses and other	(1,345)	(133)	3,026
Accounts payable and other accrued liabilities	(7,236)	(16,711)	(11,868)
Income taxes	4,193	1,189	(4,553)
Net cash (used in) provided by operating activities	(16,215)	66,877	35,126
CASH FLOWS FROM INVESTING ACTIVITIES:
Property, equipment, software, reforestation and other	(52)	(6,138)	(14,690)
Oil and gas properties and equipment	(2,400)	(579)	(49,717)
Investment in unconsolidated ventures	(4,548)	(6,089)	(26,349)
Proceeds from sale of assets	130,146	427,849	18,260
Return of investment in unconsolidated ventures	11,398	5,700	12,168
Net cash provided by (used in) investing activities	134,544	420,743	(60,328)
CASH FLOWS FROM FINANCING ACTIVITIES:
Payments of debt	(10,049)	(315,229)	(58,220)
Additions to debt	3,036	3,184	11,463
Deferred financing fees	(313)	0	(295)
Change in restricted cash	39,742	0	0
Distributions to noncontrolling interests, net	(2,125)	(2,579)	(701)
Settlement of equity awards	(12,786)	0	0
Exercise of stock options	616	0	0
Repurchases of common stock	0	(3,537)	0
Payroll taxes on restricted stock and stock options	(981)	(222)	(762)
Other	0	119	32
Net cash (used in) provided by financing activities	(62,344)	(318,264)	(48,483)
Net increase (decrease) in cash and cash equivalents	55,985	169,356	(73,685)
Cash and cash equivalents at beginning of year	265,798	96,442	170,127
Cash and cash equivalents at year-end	321,783	265,798	96,442
Cash paid during the year for:
Interest	4,913	14,790	27,330
Income taxes paid (refunds)	(2,699)	10,205	(4,077)
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION:
Capitalized interest	$ 1,655	$ 2,838	$ 2,938

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2017
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. At year-end 2016, we had 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 consolidated balance sheets for all periods presented. In addition, in 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. The transactions included in our net income in the consolidated statements of income (loss) are the same as those that would be presented in other comprehensive income. Thus, our net income equates to other comprehensive income. We are evaluating the impact of any potential changes in our accounting policies and related party transactions with D.R. Horton post-merger and will update our disclosures accordingly in future periods. The merger was accounted for under the acquisition method in accordance with U.S. Generally Accepted Accounting Principles ("U.S. GAAP"). D.R. Horton was the acquirer for accounting purposes and our consolidated financial statements will continue to be stated at historical cost. Cash and Cash Equivalents Cash and cash equivalents include cash and other short-term instruments with original maturities of three months or less. Cash Flows The consolidated statements of cash flows for 2017 , 2016 and 2015 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. Change in Fiscal Year As a result of the Merger with D.R. Horton, we have elected to change our fiscal year-end from December 31 to September 30, effective January 1, 2018. This change will align our fiscal year-end reporting calendar with D.R. Horton. 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. With the sale of our remaining oil and gas entities in 2017 we no longer have asset retirement obligations 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. Prior to the sale, we recorded the fair value of a liability for an asset retirement obligation in the period in which it was 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). 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, 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. 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 2017 , we sold our remaining owned mineral assets for approximately $85,700,000 and as a result of this sale we recorded a non-cash impairment charge of $37,900,000 related to the mineral resources reporting unit goodwill which is included in cost of mineral resources on our consolidated statements of income (loss). At year-end 2016, we performed our annual goodwill impairment evaluation and concluded that goodwill related to our central Texas water assets was impaired because the carrying value exceeded the fair value and recorded a $3,874,000 non-cash impairment charge which is included in cost of other on our consolidated statements of income (loss). 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. 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 2017 2016 (In thousands) Buildings and building improvements 10 to 40 years $ 2,162 $ 2,700 Property and equipment 2 to 10 years 4,513 4,957 6,675 7,657 Less: accumulated depreciation (4,672 ) (4,541 ) $ 2,003 $ 3,116 Depreciation expense of property and equipment was $441,000 in 2017 , $889,000 in 2016 and $1,067,000 in 2015 . 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. In certain instances earnest money deposits are subject to mortgages which are secured by the real estate under contract with the home builder. These mortgages expire when the earnest money is released to the home builders as lots are developed and sold. At year-end 2017 , $40,408,000 of real estate was subject to earnest money mortgages, including $25,712,000 classified as assets held for sale. 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 in collecting these reimbursements. 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. We generally determine fair value based on the present value of future 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 2017, we recorded $3,420,000 in non-cash impairment charges related to the asset group sold in the strategic asset sale to Starwood and one mitigation project. In 2016, we recorded $56,453,000 in non-cash impairment charges related to six non-core community development projects and two multifamily sites. Reclassifications In 2017, we have reclassified prior years' restricted cash that was included in other assets to a separate line item on our consolidated balance sheets to conform to the current year presentation. Real Estate Revenue 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 exclude from revenue amounts we collect from utility or improvement districts related to the conveyance of water, sewer and other infrastructure related assets. 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. Share-Based Compensation We use the Black-Scholes option pricing model to determine the fair value of stock options, and a Monte Carlo simulation pricing model to determine the fair value of market-leveraged stock units and for stock options with market conditions. The fair value of equity-settled awards is determined on the grant date and the fair value of cash-settled awards is determined at period end. We expense share-based awards ratably over the vesting period or earlier based on retirement eligibility. Owned Mineral Interests Historically, we leased our mineral interests to third-party exploration and production entities, we retained a royalty interest and may have taken an additional participation in production, including a working interest. In first quarter 2017, we sold our remaining owned mineral assets. Oil and Gas Properties (Discontinued Operations) We used 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 were capitalized. Costs to drill exploratory wells were capitalized pending determination of whether the wells had proved reserves and if determined incapable of producing commercial quantities of oil and gas these costs were expensed as dry hole costs. At year-end 2017 , we had 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 were expensed as incurred. Production costs incurred to maintain wells and related equipment were charged to expense as incurred. Depreciation and depletion of producing oil and gas properties was calculated using the units-of-production method. Proved developed reserves were used to compute unit rates for unamortized tangible and intangible drilling and completion costs. Proved reserves were used to compute unit rates for unamortized acquisition of proved leasehold costs. Unit-of-production amortization rates were revised whenever there was an indication of the need for revision but at least once a year and those revisions were accounted for prospectively as changes in accounting estimates. We no longer own any oil and gas working interest properties. Impairment of Oil and Gas Properties (Discontinued Operations) Historically, we evaluated our oil and gas properties, including facilities and equipment, for impairment whenever events or changes in circumstances indicated that the carrying value of the asset may not be recoverable. We estimate the expected undiscounted future cash flows of our oil and gas properties and compared such undiscounted future cash flows to the carrying amount of the oil and gas properties to determine if the carrying amount was recoverable. If the carrying amount exceeded the estimated undiscounted future cash flows, we adjusted the carrying amount of the oil and gas properties to fair value. The factors used to determine fair value were subject to our judgment and expertise and included, but were 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. Assessing unproved leasehold properties to determine impairment required significant judgment. We assessed 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. Oil and Gas Working Interest Revenues (Discontinued Operations) We recognized revenue as oil and gas was produced and sold. There were a significant amount of oil and gas properties which we did not operate and, therefore, revenue was typically recorded in the month of production based on an estimate of our share of volumes produced and prices realized. We obtained 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 was not feasible; therefore we utilized 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 were recorded as actual results became known. A majority of our sales were made under contractual arrangements with terms that were considered to be usual and customary in the oil and gas industry. The contracts were 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 did not have an effect on how we recognized revenue. Mineral Resources Revenues We recognized revenue from mineral bonus payments when we had 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 had been collected, and we had no obligation to refund the payment. We recognized revenue from delay rentals received if drilling had not started within the specified period and when the payment had been collected. We recognized revenue from mineral royalties and non-working interests when the minerals had been delivered to the buyer, the value was determinable, and we were reasonably sure of collection. Other Revenues We recognized revenue from timber sales upon passage of title, which occurred at delivery; when the price was fixed and determinable; and we were reasonably sure of collection. We recognized revenue from recreational leases on a 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, when payment has been collected, all conditions to the agreement have been met and we have no further performance obligations. Water delivery revenues are recognized as water is delivered and metered at the delivery point.

New and Pending Accounting Pron

New and Pending Accounting Pronouncements	12 Months Ended
	Dec. 31, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
New and Pending Accounting Pronouncements	New and Pending Accounting Pronouncements Adoption of New Accounting Standards 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. We adopted the updated standard on January 1, 2017. Effective first quarter 2017, stock-based compensation (SBC) excess tax benefits or deficiencies are reflected in the consolidated statements of income (loss) as a component of the provision for income taxes, whereas they previously were recognized in equity to the extent additional paid-in capital pool was available. Additionally, our consolidated statements of cash flows will now present excess tax benefits as an operating activity, if applicable. Finally, we have elected to account for forfeitures as they occur, rather than estimate expected forfeitures. The adoption of this guidance did not have a material impact on our consolidated financial statements. 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. The updated standard becomes effective for annual and interim periods beginning after December 15, 2017. Due to our change in fiscal year-end, this standard is effective for us beginning October 1, 2018. 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 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. In May 2017, the FASB issued ASU 2017-09, Compensation - Stock Compensation (Topic 718), in order to provide guidance about which changes to terms or conditions of a share-based payment award require an entity to apply modification accounting in Topic 718. The updated standard is effective for financial statements issued for annual periods beginning after December 15, 2017. 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.

Merger

Merger	12 Months Ended
	Dec. 31, 2017
Business Combinations [Abstract]
Merger	Merger On October 5, 2017, we merged with a subsidiary of D.R. Horton and we continued as the surviving entity (the "Merger"). In the Merger, each existing share of our common stock issued and outstanding immediately prior to the effective time (the “Former Forestar Common Stock”) (except for shares of our common stock that were held by us as treasury shares or by us or D.R. Horton or our or their respective subsidiaries) were converted into the right to receive, at the election of the holders of such shares of Former Forestar Common Stock, either an amount in cash equal to the Cash Consideration ( $17.75 per share) or one new share of our common stock (the “New Forestar Common Stock”), subject to proration procedures applicable to oversubscription and undersubscription for the Cash Consideration described in the Merger Agreement. The aggregate amount of Cash Consideration paid by D.R. Horton to holders of Former Forestar Common Stock in the Merger was $558,256,000 . In the Merger, 10,487,873 shares of New Forestar Common Stock (representing 25% of the outstanding shares of New Forestar Common Stock immediately after the effective time) were issued to the holders of our common stock and 31,451,063 shares of New Forestar Common Stock (representing 75% of the outstanding share of the New Forestar Common Stock immediately after the effective time) were issued to D.R. Horton. Subject to the terms of the Merger Agreement, at the effective time, each equity award made or otherwise denominated in shares of Former Forestar Common Stock that was outstanding immediately prior to the effective time under our equity compensation plans was cancelled and of no further force or effect as of the effective time. In exchange for the cancellation of the equity awards, each holder of such an equity award received from us the Cash Consideration for each share of Former Forestar Common Stock underlying such equity award (and in the case of equity awards that were stock options or stock appreciation rights, less the applicable exercise or strike price, but not less than $0), whether or not otherwise vested as of the effective time. With respect to any of our market-leveraged stock units, the number of shares of Former Forestar Common Stock subject to such equity awards were determined pursuant to the terms set forth in the applicable award agreements and based on a per share value equal to $17.75 . In connection with merger activities, we incurred $43,819,000 in transaction costs in 2017, of which, $41,475,000 are included in general and administrative expenses and $2,344,000 in other operating expenses on our consolidated statements of income (loss). These costs include a $20,000,000 merger termination fee paid to Starwood Capital Group, $7,683,000 in executive severance and change in control costs, $7,170,000 in transaction and other fees paid to our financial advisor, $4,617,000 in professional services and other costs and $4,349,000 related to the acceleration of vesting and settlement of equity awards.

Real Estate

Real Estate	12 Months Ended
	Dec. 31, 2017
Real Estate [Abstract]
Real Estate	Real Estate Real estate consists of: At Year-End 2017 2016 (In thousands) Entitled, developed and under development projects $ 127,442 $ 263,859 Other real estate costs (principally land in entitlement in 2016) 2,938 29,144 $ 130,380 $ 293,003 Our estimated reimbursements from utility and improvement districts included in real estate were $9,775,000 at year-end 2017 and $45,157,000 at year-end 2016 , which included $14,749,000 related to our Cibolo Canyons project near San Antonio. In 2017, we collected $19,606,000 in reimbursements that were previously submitted to these districts. 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. At year-end 2017, estimated reimbursements of $27,915,000 , which include $14,127,000 related to Cibolo Canyons, are classified as assets held for sale. Please read Note 22 — Subsequent Event for additional information regarding our strategic asset sale to Starwood. In 2017 , we recognized non-cash impairment charges of $3,420,000 related to the asset group sold in the strategic asset sale to Starwood and one non-core mitigation project. 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 2017 , we sold over 19,000 acres of timberland and undeveloped land in Georgia and Texas for $46,197,000 generating combined net proceeds of $45,396,000 . These transactions resulted in a gain on sale of assets of $28,674,000 . 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 timberland and undeveloped land in Georgia and Alabama for $104,172,000 generating net proceeds of $103,238,000 . These transactions resulted in a gain on sale of assets of $48,891,000 . Depreciation expense related to commercial and income producing properties was $0 in 2017 , $816,000 in 2016 and $6,810,000 in 2015 and is included in other operating expense. We provided a performance bond and standby letter of credit in support of a bond issuance by CCSID. In 2014, we received $50,550,000 from CCSID principally 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 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 decreases as CCSID makes annual ad valorem tax rebate payments, which obligation is scheduled to be retired in full by 2020. At year-end 2017, the surety bond was $5,312,000 . Our rights to receive the excess HOT and sales taxes from CCSID was excluded from the strategic asset sale to Starwood.

Investment in Unconsolidated Ve

Investment in Unconsolidated Ventures	12 Months Ended
	Dec. 31, 2017
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 2017 , we had ownership interests in 15 ventures that we accounted for using the equity method, none of which are a VIE. 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 2017 2016 2017 2016 2017 2016 2017 2016 (In thousands) 242, LLC (b) (e) $ 19,525 $ 26,503 $ — $ 1,107 $ 19,357 $ 23,136 $ 9,131 $ 10,934 CL Ashton Woods, LP (c) 124 2,653 — — 104 2,198 83 1,107 CL Realty, LLC 4,528 8,048 — — 4,344 7,899 2,172 3,950 CREA FMF Nashville LLC (b) 2,315 56,081 — 37,446 684 17,091 342 4,923 Elan 99, LLC (e) 49,080 49,652 36,348 36,238 11,204 13,100 10,078 11,790 FMF Littleton LLC 66,849 70,282 45,836 44,446 20,289 23,798 5,144 6,128 FMF Peakview LLC — — — — — — — — FOR/SR Forsyth LLC 11,598 10,672 1,551 1,568 10,041 8,990 9,037 8,091 HM Stonewall Estates, Ltd — 852 — — — 852 — 477 LM Land Holdings, LP (c) 19,479 25,538 — 3,477 12,074 20,945 5,935 9,685 MRECV DT Holdings LLC (e) 3,043 4,155 — — 3,043 4,144 2,594 3,729 MRECV Edelweiss LLC/MRECV Lender VIII LLC (e) 8,127 3,484 — — 8,127 3,484 7,189 3,358 MRECV Juniper Ridge LLC (e) 3,936 4,156 — — 3,936 4,156 3,331 3,741 MRECV Meadow Crossing II LLC (e) 3,129 2,492 — — 3,129 2,491 2,738 2,242 Miramonte Boulder Pass, LLC (e) 7,573 10,738 1,398 4,006 4,843 5,265 4,633 5,330 Temco Associates, LLC 4,448 4,368 — — 4,345 4,253 2,172 2,126 Other ventures — — — — — — — — $ 203,754 $ 279,674 $ 85,133 $ 128,288 $ 105,520 $ 141,802 $ 64,579 $ 77,611 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 2017 2016 2015 2017 2016 2015 2017 2016 2015 (In thousands) 242, LLC (b) (e) $ 13,073 $ 5,835 $ 20,995 $ 8,021 $ 1,259 $ 9,588 $ 4,096 $ 668 $ 4,919 CL Ashton Woods, LP 3,179 2,870 9,820 1,456 914 3,881 1,816 1,332 5,000 CL Realty, LLC 499 567 856 (1,155 ) 237 424 (578 ) 119 212 CREA FMF Nashville LLC (b) (d) 5,440 4,955 1,227 17,267 (1,420 ) (1,696 ) 7,563 1,103 (1,696 ) Elan 99, LLC (e) 4,596 1,392 — (1,896 ) (2,739 ) (49 ) (1,712 ) (2,465 ) (44 ) FMF Littleton LLC 6,366 3,116 120 192 (571 ) (367 ) 48 (143 ) (92 ) FMF Peakview LLC — 939 2,057 — (248 ) (1,116 ) — (50 ) (223 ) FOR/SR Forsyth LLC — — — (148 ) (65 ) — (134 ) (58 ) — HM Stonewall Estates, Ltd. 496 2,112 3,990 243 832 1,881 103 361 952 LM Land Holdings, LP (c) 22,127 10,001 10,956 10,629 7,288 8,251 3,563 2,458 3,342 MRECV DT Holdings LLC (e) 1,196 495 — 1,173 477 167 911 429 — MRECV Edelweiss LLC/MRECV Lender VIII LLC (e) 1,018 416 — 1,016 409 151 789 368 137 MRECV Juniper Ridge LLC (e) 1,445 379 — 1,445 380 106 1,089 342 — MRECV Meadow Crossing II LLC (e) 638 267 — 638 220 — 496 198 — Miramonte Boulder Pass, LLC (e) 5,483 4,923 — 177 (399 ) (250 ) (197 ) (200 ) (125 ) PSW Communities, LP — — 29,986 — — 2,688 — — 1,169 TEMCO Associates, LLC 192 1,344 9,485 92 440 2,358 46 220 1,179 Other ventures — 6,519 36,237 — 2,105 33,303 — 1,441 1,278 $ 65,748 $ 46,130 $ 125,729 $ 39,150 $ 9,119 $ 59,320 $ 17,899 $ 6,123 $ 16,008 _____________________ (a) Total includes current maturities of $84,098,000 at year-end 2017 , of which $79,515,000 is non-recourse to us, and $89,756,000 at year-end 2016 , of which $78,557,000 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 $548,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2017 . (c) Includes unrecognized basis difference of $448,000 which is reflected as an increase of our investment in unconsolidated ventures at year-end 2017 . This difference will be amortized as expense over the life of the investment and included in our share of earnings (loss) from the respective venture. (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 accordance with the partnership agreement. (e) Included in our strategic asset sale to Starwood on February 8, 2018. Please read Note 22 - Subsequent Event for additional information regarding this transaction. In 2017 , we invested $4,548,000 in these ventures and received $34,439,000 in distributions; in 2016 , we invested $6,089,000 in these ventures and received $13,419,000 in distributions; and in 2015 , we invested $26,349,000 in these ventures and received $24,909,000 in distributions. Distributions include both return of investments and distributions of earnings. In 2017, CREA FMF Nashville LLC (Acklen), sold a 320 -unit multifamily project in Nashville for $71,750,000 and recognized a gain of $18,986,000 . Our share of earnings was $7,783,000 and we received a distribution of $11,956,000 as a result of this sale. In 2017, venture earnings from 242, LLC benefited from the sale of 46 commercial acres for $9,719,000 generating $6,612,000 in earnings to the venture. Based on our 50% interest in the venture, our pro-rata share of the earnings associated with this sale was $3,306,000 and our pro-rata share of the total distributable cash was $4,348,000 . In 2017, CL Realty, LLC, a venture in which we own a 50% interest, sold certain mineral assets to us for $2,400,000 . Subsequent to closing of this transaction, we received $1,200,000 from the venture, representing our pro-rata share of distributable cash. In 2017, the venture recognized a non-cash impairment charge of $3,756,000 associated with a commercial tract on the Texas coast. 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. We provided construction and development services for some of these ventures for which we receive fees. Fees for these services were $741,000 in 2017 , $2,466,000 in 2016 and $1,856,000 in 2015 , and are included in real estate revenues.

Goodwill and Other Intangible A

Goodwill and Other Intangible Assets	12 Months Ended
	Dec. 31, 2017
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 2017 2016 (In thousands) Goodwill $ — $ 37,900 Identified intangibles, net 448 — $ 448 $ 37,900 Goodwill related to our mineral assets was $0 at year-end 2017 and $37,900,000 at year-end 2016 . In 2017, we recognized a non-cash impairment charge of $37,900,000 related to goodwill attributable to our mineral resources reporting unit as a result of selling our remaining owned mineral assets. In 2016, we recognized a goodwill non-cash impairment charge of $3,874,000 related to interests in groundwater leases in central Texas. Impairment charges are included in cost of mineral resources and cost of other on our consolidated statements of income (loss). Identified intangibles, net represent indefinite lived groundwater leases associated with our central Texas water assets at year-end 2017 and were included in assets held for sale at year-end 2016. In 2017, we recognized a non-cash impairment charge of $1,233,000 related to the indefinite lived groundwater leases. Impairment charges are included in cost of other on our consolidated statements of income (loss).

Held for Sale

Held for Sale	12 Months Ended
	Dec. 31, 2017
Discontinued Operations and Disposal Groups [Abstract]
Held for Sale	Held for Sale At year-end 2017 , assets held for sale principally included certain real estate projects sold on February 8, 2018, and water wells related to our nonparticipating royalty interests in water rights located in east Texas. Please read Note 22 - Subsequent Event for additional information regarding our strategic asset sale to Starwood. The major classes of assets and liabilities held for sale were as follows: At Year-End 2017 2016 Assets Held for Sale: (In thousands) Real estate $ 180,247 $ 19,931 Timber — 1,682 Other intangible assets — 1,681 Oil and gas properties and equipment, net — 782 Property and equipment, net 1,360 6,301 $ 181,607 $ 30,377 Liabilities Held for Sale: Accounts payable 1,017 — Other liabilities — 103 $ 1,017 $ 103

Discontinued Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2017
Discontinued Operations and Disposal Groups [Abstract]
Discontinued Operations	Discontinued Operations We have divested 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 consolidated balance sheets for all periods presented. Summarized results from discontinued operations were as follows: For the Year 2017 2016 2015 Revenues $ 15 $ 5,862 $ 43,845 Cost of oil and gas producing activities (52 ) (6,578 ) (221,402 ) Other operating expenses 226 (7,754 ) (10,363 ) Income (loss) from discontinued operations before income taxes $ 189 $ (8,470 ) $ (187,920 ) Gain (loss) on sale of assets before income taxes (197 ) (13,664 ) (706 ) Income tax benefit 46,039 5,269 2,496 Income (loss) from discontinued operations, net of taxes $ 46,031 $ (16,865 ) $ (186,130 ) In third quarter 2017, we sold the common stock of Forestar Petroleum Corporation for $100,000 . This transaction completed the sale of all our oil and gas assets and related entities. This transaction resulted in a significant tax loss, and the corresponding tax benefit is reported in discontinued operations in 2017. 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 2017 include a benefit of $1,043,000 due to a reduction of an accrual resulting from a change in estimate related to potential environmental liabilities to plug and abandon certain oil and gas wells in Wyoming. 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. 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 . Cost of sales includes non-cash impairment charges of $0 in 2017 , $612,000 in 2016 and $163,029,000 in 2015 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 2017 and 2016 are as follows: At Year-End 2017 2016 (In thousands) Assets of Discontinued Operations: Receivables, net of allowance for bad debt $ — $ 6 Prepaid expenses — 8 $ — $ 14 Liabilities of Discontinued Operations: Accounts payable $ — $ 67 Other accrued expenses — 5,228 $ — $ 5,295 Cash (used in) or provided by operating activities and investing activities of discontinued operations are as follows: For the Year 2017 2016 2015 (In thousands) Operating activities: Asset impairments $ — $ 612 $ 105,337 Changes in accounts payable and other accrued liabilities (3,000 ) — — Dry hole and unproved leasehold impairment charges — — 67,639 Loss (gain) on sale of assets 197 13,664 706 Depreciation, depletion and amortization — 2,202 28,391 $ (2,803 ) $ 16,478 $ 202,073 Investing activities: Oil and gas properties and equipment $ — $ (579 ) $ (49,717 ) Proceeds from sales of assets 200 77,105 17,800 $ 200 $ 76,526 $ (31,917 )

Receivables

Receivables	12 Months Ended
	Dec. 31, 2017
Receivables [Abstract]
Receivables	Receivables Receivables consist of: At Year-End 2017 2016 (In thousands) Other receivables and accrued interest 2,557 1,505 Loans secured by real estate, average interest rate of 5.40% at year-end 2017 and 4.94% at year-end 2016 3,776 7,452 6,333 8,957 Allowance for bad debts (26 ) (26 ) $ 6,307 $ 8,931 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, 2017
Debt Disclosure [Abstract]
Debt	Debt Debt consists of: At Year-End 2017 2016 (In thousands) 8.50% senior secured notes due 2022 — 5,200 3.75% convertible senior notes due 2020, net of discount 108,139 104,673 Other indebtedness due through 2018 at variable and fixed interest rates ranging from 5.0% to 5.50% 290 485 $ 108,429 $ 110,358 Letter of Credit Facility On October 5, 2017, we entered into a Letter of Credit Facility Agreement providing for a $30,000,000 secured standby letter of credit facility (the “LC Facility”). The LC Facility is secured by $30,000,000 in cash deposited with the administrative agent. In addition, we have $10,000,000 on deposit with a participating lender. The total of these two deposits are classified as restricted cash on our consolidated balance sheets. At year-end 2017 , $14,072,000 was outstanding under the LC Facility. Termination of Senior Credit Facility On October 5, 2017, in connection with entry into the LC Facility, we terminated our existing senior credit facility (the “Prior Credit Facility”). The Prior Credit Facility provided for a $50,000,000 revolving line of credit that was scheduled to mature on May 15, 2018. This Prior Credit Facility could be prepaid at any time without penalty and included a $50,000,000 sublimit for letters of credit. All outstanding letters of credit at the time of termination were transferred to the new LC Facility. 8.50% Senior Secured Notes due 2022 On October 30, 2017, we redeemed the remaining $5,315,000 aggregate principal amount of outstanding 8.50% Senior Secured Notes due 2022 (the “Notes”). The Notes were redeemed for $5,928,000 and the redemption resulted in a $524,000 loss on extinguishment of debt. In 2016, we completed a cash tender offer for our Notes, pursuant to which we purchased $215,495,000 principal amount of the outstanding Notes. Total consideration paid was $245,604,000 , which included $29,091,000 in premium 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 in open market transactions. The cash tender offer and open market purchases resulted in a $35,681,000 loss on extinguishment of debt, which included 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. 3.75% Convertible Senior Notes due 2020 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 had an initial conversion rate of 40.8351 per $1,000 principal amount. The initial conversion rate was 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. On October 5, 2017, we had $120,000,000 aggregate principal amount of Convertible Notes outstanding. In connection with the consummation of the Merger, we entered into a Third Supplemental Indenture (together with the base indenture and the prior supplemental indentures, the "Indenture") to the Indenture relating to our Convertible Notes. Pursuant to the Third Supplemental Indenture, the Convertible Notes are no longer convertible into shares of our pre-merger common stock (“Former Forestar Common Stock”) and instead are convertible into cash and shares of our post-merger common stock (“New Forestar Common Stock”) based on the per-share weighted average of the cash and shares of New Forestar Common Stock received by our stockholders that affirmatively made an election in connection with the Merger. As a result of such elections, for each share of Former Forestar Common Stock a holder of Convertible Notes was previously entitled to receive upon conversion of Convertible Notes, such holder is instead entitled to receive $579.77062 in cash and 8.17192 shares of New Forestar Common Stock per $1,000 principal amount of Notes surrendered for conversion. The completion of the Merger constituted a Fundamental Change, as defined in the Indenture. On October 12, 2017, in accordance with the Indenture, we gave notice of the Fundamental Change to holders of the Convertible Notes and made an offer to purchase (a “Fundamental Change Offer”) all or any part (equal to $1,000 or an integral multiple of $1,000) of every holder’s Convertible Notes. Under this offer, we repurchased $1,077,000 of Notes, and recorded a loss on extinguishment of debt of $87,000 . At year-end 2017 , unamortized debt discount of our Convertible Notes was $9,726,000 . The effective interest rate on the liability component was 8 percent and the carrying amount of the equity component was $16,847,000 . We intend to settle the principal amount of Convertible Notes in cash upon conversion, with any excess conversion value to be settled in shares of our common stock. In 2016, we purchased $5,000,000 of 3.75% Convertible Senior Notes due 2020 at 93.25 percent 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 . Deferred Fees and Debt Maturities At year-end 2017 and 2016 , we have $1,058,000 and $1,633,000 in unamortized deferred fees which were deducted from our debt. Amortization of deferred financing fees was $979,000 in 2017 , $3,598,000 in 2016 and $4,002,000 in 2015 and is included in interest expense. Debt maturities during the next five years are: 2018 — $290,000 ; 2019 — $0 ; 2020 — $108,139,000 ; 2021 — $0 ; 2022 — $0 and thereafter — $0 .

Fair Value

Fair Value	12 Months Ended
	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Fair Value	Fair Value Fair value is the exchange price that would be 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 and notes receivable, other assets, debt, accounts payable and other 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 2017 Year-End 2016 Carrying Amount Fair Value Carrying Amount Fair Value Valuation Technique (In thousands) Fixed rate debt $ (109,197 ) $ (109,114 ) $ (111,506 ) $ (109,789 ) Level 2 Non-financial assets measured at fair value on a non-recurring basis include real estate assets, assets held for sale, goodwill and intangible assets, which are measured for impairment. In 2017, we recognized a non-cash impairment charge of $37,900,000 related to goodwill attributable to our mineral resources reporting unit as a result of selling our remaining owned mineral assets. We recognized non-cash impairment charges of $5,852,000 related to our non-core water assets in central Texas and Georgia and $420,000 related to a non-core mitigation project in Georgia. We also recorded a non-cash impairment charge of $3,000,000 related to the asset group to be disposed of in the strategic asset sale to Starwood on February 8, 2018. We based the valuations of our water assets and mitigation project primarily on past and current negotiations with expected buyers. 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. Non-financial assets measured at fair value on a non-recurring basis are as follows: Year-End 2017 Year-End 2016 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (In thousands) Non-financial Assets and Liabilities: Real estate held for sale $ — $ 180,247 $ — $ 180,247 $ — $ — $ — $ — Central Texas water assets $ — $ — $ 1,987 $ 1,987 $ — $ — $ — $ —

Capital Stock

Capital Stock	12 Months Ended
	Dec. 31, 2017
Equity [Abstract]
Capital Stock	Capital Stock On October 5, 2017, our stockholders received New Forestar Common Stock in connection with the Merger. Please see Note 3 — Merger for additional information. 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 . 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. The foregoing purchase authorization terminated upon closing of the Merger with D.R. Horton on October 5, 2017.

Net Income (Loss) per Share

Net Income (Loss) per Share	12 Months Ended
	Dec. 31, 2017
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 treasury stock method in 2017 and the two-class method for 2016 and 2015. 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 previously determined that our 6.00% tangible equity units issued in 2013 were 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 2017 2016 2015 (In thousands) Numerator: Continuing operations Net income (loss) from continuing operations $ 6,301 $ 77,044 $ (26,241 ) Less: Net (income) attributable to noncontrolling interest (2,078 ) (1,531 ) (676 ) Earnings (loss) available for diluted earnings per share $ 4,223 $ 75,513 $ (26,917 ) Less: Undistributed net income from continuing operations allocated to participating securities — (13,493 ) — Earnings (loss) from continuing operations available to common shareholders for basic earnings per share $ 4,223 $ 62,020 $ (26,917 ) Discontinued operations Net income (loss) from discontinued operations available for diluted earnings per share 46,031 (16,865 ) (186,130 ) Less: Undistributed net income from discontinued operations allocated to participating securities — 3,014 — Earnings (loss) from discontinued operations available to common shareholders for basic earnings per share 46,031 (13,851 ) (186,130 ) Denominator: Weighted average common shares outstanding — basic 42,143 34,546 34,266 Weighted average common shares upon conversion of participating securities (a) — 7,515 — Dilutive effect of stock options, restricted stock and equity-settled awards 238 273 — Total weighted average shares outstanding — diluted 42,381 42,334 34,266 Anti-dilutive awards excluded from diluted weighted average shares outstanding 1,093 2,102 10,864 _____________________ (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. 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 $51.42 . The price of our common stock in 2017 did not exceed the conversion price which resulted in no additional diluted outstanding shares.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes Income tax expense from continuing operations consists of: For the Year 2017 2016 2015 (In thousands) Current tax provision: U.S. Federal $ (44,177 ) $ (15,089 ) $ 6,740 State and other (3,378 ) (1,520 ) (418 ) (47,555 ) (16,609 ) 6,322 Deferred tax provision: U.S. Federal 1,678 1,382 (38,262 ) State and other 57 (75 ) (3,191 ) 1,735 1,307 (41,453 ) Income tax expense $ (45,820 ) $ (15,302 ) $ (35,131 ) A reconciliation of the federal statutory rate to the effective income tax rate on continuing operations follows: For the Year 2017 2016 2015 Federal statutory rate (benefit) 35 % 35 % 35 % State, net of federal benefit 3 — 10 Valuation allowance (42 ) (19 ) 348 Tax rate change due to new tax act 40 — — Noncontrolling interests (1 ) (1 ) (3 ) Installment sale ace adjustment — 2 — Stock based compensation 11 — 5 Goodwill 25 — — Merger costs 18 — — Oil and gas percentage depletion — — (1 ) Other (1 ) — 1 Effective tax rate 88 % 17 % 395 % The effective tax rate for all years includes an expense for state income taxes and non-deductible expenses, reduced by a tax benefit related to noncontrolling interests. The effective tax rate for 2017 also includes an expense for non-deductible goodwill related to the sale of our owned mineral assets and non-deductible transaction costs related to the Merger with D.R. Horton. Other 2017 differences, including the remeasurement of our deferred tax assets and liabilities as a result of the Tax Cuts and Jobs Act ("Tax Act"), are fully offset by a change in our valuation allowance. The effective tax rate for 2016 includes a change in valuation allowance due to a decrease in our deferred tax assets. The effective rate for 2015 includes the establishment of a valuation allowance against our deferred tax assets. Significant components of deferred taxes are: At Year-End 2017 2016 (In thousands) Deferred Tax Assets: Real estate $ 37,513 $ 50,759 Employee benefits 1,510 13,185 Net operating loss carryforwards 2,305 2,804 Oil and gas properties — 1,672 AMT credits 1,690 5,900 Income producing properties 794 2,055 Oil and gas percentage depletion carryforwards — 3,478 Accruals not deductible until paid 196 552 Gross deferred tax assets 44,008 80,405 Valuation allowance (39,578 ) (73,405 ) Deferred tax asset net of valuation allowance 4,430 7,000 Deferred Tax Liabilities: Undeveloped land — (1,359 ) Convertible debt (2,402 ) (5,035 ) Timber — (283 ) Gross deferred tax liabilities (2,402 ) (6,677 ) Net Deferred Tax Asset (Liability) $ 2,028 $ 323 The Tax Act was enacted on December 22, 2017, and reduced the federal corporate tax rate from 35 percent to 21 percent for all corporations effective January 1, 2018. ASC 740 requires companies to reflect the effects of a tax law change in the period in which the law is enacted. Accordingly, we have remeasured our deferred tax assets and liabilities along with the corresponding valuation allowance as of the enactment date. This remeasurement resulted in no additional tax expense or benefit except for the release of a portion of the valuation allowance for AMT credits which become fully refundable in future years as a result of the tax law change. We have determined based on current available information that no other tax law changes as a result of the Tax Act have a significant impact on our 2017 tax expense. The adjustment to the deferred tax accounts and our determination that no other tax law changes have a significant impact on our 2017 tax expense are our best estimate based on the information available at this time and may change as additional information, such as regulatory guidance, becomes available. Adjustments to estimated amounts, if any, would be reflected as a discrete expense or benefit in the quarter that it is identified, as allowed by SEC Staff Accounting Bulletin No. 118. On October 5, 2017, D.R. Horton acquired 75 percent of our common stock resulting in an ownership change under Section 382. Section 382 limits our ability to use certain tax attributes and built-in losses and deductions in a given year. Any tax attributes or built-in losses and deductions that are limited in the current year are expected to be fully utilized in future years. At year-end 2017, we had approximately $9,200,000 and $69,200,000 of federal and state net operating loss carryforwards, which include certain recognized built-in losses that are deferred under Section 382. These carryforwards are subject to a full valuation allowance and $45,600,000 of the state carryforwards are attributable to states in which we are not currently doing business due to our exit from the oil and gas business. If not utilized, the federal carryforwards will expire in 2037 and the state carryforwards will expire in 2020 to 2037 . We had approximately $1,690,000 of AMT credit carryforwards which are refundable over the next four years if not used to offset current taxes. At year-end 2017 and 2016, we have provided a valuation allowance for our deferred tax asset of $39,578,000 and $73,405,000 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 primarily attributable to the remeasurement of deferred tax assets and liabilities as a result of the tax rate decrease from the Tax Act. 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, 2017, 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. and in various state jurisdictions. All federal statutes of limitations for tax years prior to 2012 are closed. As a result of filing refund claims for the 2012 through 2014 tax years for carrybacks from the 2015 tax year, the Internal Revenue Service (“IRS”) initiated and completed an audit of our 2012 through 2015 tax years during 2017 resulting in no change to our tax liability. As a result, the IRS cannot re-open the 2012 through 2015 tax years for audit unless they identify an issue that meets the criteria for re-opening an audit under Section 5 of Rev. Proc. 2005-32. We believe there are no such issues in our 2012 through 2015 tax years that meet this criteria and, therefore, we believe the IRS will not re-open our 2012 through 2015 tax years for audit. We are no longer subject to state income tax examinations before 2013. A reconciliation of the beginning and ending amount of tax benefits not recognized for book purposes is as follows: At Year-End (In thousands) 2017 2016 2015 Balance at beginning of year $ 2,499 $ — $ — Increases (decreases) for tax positions of current year — 2,499 — Decreases for dispositions and other (1,449 ) — — Balance at end of year $ 1,050 $ 2,499 $ — If the total amount of unrecognized tax benefits were recognized at year-end 2017, it would result in a $1,050,000 deferred tax asset and a corresponding tax benefit. We recognize interest accrued related to unrecognized tax benefits in income tax expense. In 2017 , 2016 and 2015 , we recognized no interest related to unrecognized tax benefits. At year-end 2017 and 2016 , we had no accrued interest or penalties.

Litigation and Environmental Co

Litigation and Environmental Contingencies	12 Months Ended
	Dec. 31, 2017
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 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. 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. With the sale of our remaining oil and gas entities in third quarter 2017 we no longer 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. At year-end 2016, we had 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, 2017
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, including amounts recorded as discontinued operations, was $2,101,000 in 2017 , $1,923,000 in 2016 and $3,872,000 in 2015 . Future minimum rental commitments under non-cancelable operating leases having an initial or remaining term in excess of one year are: 2018 — $1,313,000 ; 2019 — $208,000 ; 2020 — $180,000 ; 2021 — $61,000 ; 2022 — $0 ; and thereafter — $0 . We lease office space in Austin, Texas, as our corporate headquarters and in other locations in support of our business operations. The total remaining contractual obligations for these leases is $1,762,000 . In support of our core community development business, we have a $40,000,000 surety bond program that provides financial assurance to beneficiaries related to execution and performance of our land development business. At year-end 2017, there were $14,708,000 outstanding under this program.

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2017
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. Mineral resources managed our owned mineral assets. Other managed our timber, recreational leases and water resource assets. We have divested 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 2017 , one homebuilder accounted for $20,923,000 of our total real estate segment revenues. In 2016 and 2015 , 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 2017 Revenues $ 112,746 $ 1,502 $ 74 $ — $ 114,322 Depreciation, depletion and amortization 131 28 25 5,279 5,463 Equity in earnings of unconsolidated ventures 16,500 1,395 4 — 17,899 Income (loss) before taxes from continuing operations attributable to Forestar Group Inc. 47,281 45,552 (6,393 ) (36,397 ) (a) 50,043 Total assets 386,222 — 3,346 372,344 761,912 Investment in unconsolidated ventures 64,579 — — — 64,579 Capital expenditures 52 2,400 — — 2,452 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 Investment in unconsolidated ventures 82,453 — — — 82,453 Capital expenditures 13,644 59 745 242 14,690 _____________________ (a) Items not allocated to segments consist of: For the Year 2017 2016 2015 (In thousands) General and administrative expense $ (50,354 ) $ (18,274 ) $ (24,802 ) Share-based and long-term incentive compensation expense (7,201 ) (4,425 ) (4,474 ) Gain on sale of assets 28,674 48,891 — Interest expense (8,532 ) (19,985 ) (34,066 ) Loss on extinguishment of debt, net (611 ) (35,864 ) — Other corporate non-operating income 1,627 350 256 $ (36,397 ) $ (29,307 ) $ (63,086 ) (b) Total assets excludes assets of discontinued operations of $14,000 and $104,967,000 in 2016 and 2015.

Share-Based and Long-Term Incen

Share-Based and Long-Term Incentive Compensation	12 Months Ended
	Dec. 31, 2017
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 2017 2016 2015 (In thousands) Cash-settled awards $ 634 $ 717 $ (3,127 ) Equity-settled awards 5,001 2,444 5,026 Restricted stock — 22 (8 ) Stock options 1,008 854 2,355 Total share-based compensation $ 6,643 $ 4,037 $ 4,246 Deferred cash 558 388 228 $ 7,201 $ 4,425 $ 4,474 Share-based and long-term incentive compensation expense is included in: For the Year 2017 2016 2015 (In thousands) General and administrative $ 6,177 $ 3,323 $ 2,451 Other operating 1,024 1,102 2,023 $ 7,201 $ 4,425 $ 4,474 In 2017, share-based compensation expense included $4,349,000 in charges related to the acceleration of vesting and settlement of outstanding equity awards in connection with the Merger. Excluded from share-based compensation expense in the table above are fees earned by our previous directors in the amount of $449,000 for 2017 , $725,000 for 2016 and $1,203,000 for 2015 for which they elected to defer payment until retirement in the form of share-settled units. These deferred fees were settled in 2017 as a result of the Merger. These expenses are included in general and administrative expense on our consolidated statements of income (loss). Share-Based Compensation The fair value of awards granted to retirement-eligible employees and expensed at the date of grant was $9,000 in 2017 , $600,000 in 2016 and $517,000 in 2015 . Unrecognized share-based compensation expense related to non-vested equity-settled awards was $1,424,000 at year-end 2017 . The weighted average period over which this amount will be recognized is estimated to be four years. We did not capitalize any share-based compensation in 2017 , 2016 or 2015 . In 2017 and 2016 , we issued 322,586 and 300,491 shares out of our treasury stock associated with vesting of stock-based awards or exercise of stock options, net of 75,870 and 25,082 shares withheld having a value of $981,000 and $222,000 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. 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 five 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 are 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 2017 : Equivalent Units Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 42 $14.98 Granted — — Vested (30 ) 15.66 Forfeited (12 ) 13.15 Non-vested at end of period — — The weighted average grant date fair value of cash-settled restricted stock unit awards was $13.26 per unit for 2015. The fair value of cash-settled restricted stock unit awards settled was $2,178,000 in 2017, $1,195,000 in 2016, and $2,469,000 in 2015. The following table summarizes the activity of cash-settled stock appreciation rights in 2017 : 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 374 $12.97 3 $773 Granted — — Exercised (234 ) 10.14 Forfeited (140 ) 17.69 Balance at end of period — — 0 — Exercisable at end of period — — 0 — The intrinsic value of cash-settled stock appreciation rights settled was $1,581,000 in 2017 , $154,000 in 2016 and $206,000 in 2015 . The fair value of accrued cash-settled awards at year-end 2017 was $0 since all outstanding equity awards were accelerated as a result of the Merger and $1,758,000 at year-end 2016 and was included in other liabilities in our consolidated balance sheets. Equity-settled awards Equity-settled awards granted to our employees and directors include restricted stock units (RSU), which vest after three years for directors and five years for employees 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. The following table summarizes the activity of equity-settled awards in 2017 : Equivalent Units Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 555 $ 14.70 Granted 198 14.55 Vested (653 ) 14.28 Forfeited (14 ) 14.59 Non-vested at end of period 86 17.54 In 2017 and 2016 , we granted 198,000 and 313,000 RSU awards. The grant date fair value was based on the market value of the stock on the date of the grant. In 2015 , we granted 234,000 MSU awards. The vesting of these awards was accelerated in accordance with their terms upon change in control of the company and settled in cash in 2017 in connection with the Merger. We estimated the grant date fair value of MSU awards using a Monte Carlo simulation pricing model and the following assumptions: For the Year 2015 Expected stock price volatility 32.9 % Risk-free interest rate 1.0 % Expected dividend yield — % Weighted average grant date fair value of MSU awards (per unit) $ 15.11 The weighted average grant date fair value of equity-settled awards (RSU, MSU and PSU) per unit in 2017, 2016 and 2015 was $14.55 , $9.04 and $12.99 . The fair value of equity-settled awards settled was $14,894,000 , $2,884,000 and $4,451,000 in 2017, 2016 and 2015. 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. All options have been 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 2017 : Options Outstanding Weighted Average Exercise or Settlement 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 1,836 $ 19.39 5 $ 449 Granted — — Exercised or settled in merger (768 ) 14.07 Forfeited (1,068 ) 23.21 Balance at end of period — — — — Exercisable at end of period — — — — We estimated the grant date fair value of stock options 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. The intrinsic value of options exercised was $2,603,000 in 2017 , $61,000 in 2016 and $0 in 2015 . Long-Term Incentive Compensation In 2017 and 2016, we granted $1,180,000 and $620,000 of long-term incentive compensation in the form of deferred cash compensation. The 2017 deferred cash awards vest annually over three years, and the 2016 deferred cash awards vest after two years. The 2016 award provides 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 or accelerated vesting under the change of control provision. The 2016 award and the first payment on the 2017 award were settled in cash based upon their terms in connection with the Merger.

Retirement Plans

Retirement Plans	12 Months Ended
	Dec. 31, 2017
Retirement Benefits [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 $660,000 in 2017 , $978,000 in 2016 and $1,060,000 in 2015 . The unfunded liability for our supplemental plan was $374,000 at year-end 2017 and $334,000 at year-end 2016 and is included in other liabilities.

Supplemental Oil and Gas Disclo

Supplemental Oil and Gas Disclosures (Unaudited)	12 Months Ended
	Dec. 31, 2017
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 2017, we had divested 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 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. In addition, we have sold our remaining mineral assets and no longer own any oil and gas or mineral assets. We engaged independent petroleum engineers, Netherland, Sewell & Associates, Inc., to assist in preparing estimates of our proved oil and gas reserves, all of which were located in the U.S., and future net cash flows as of year-end 2016 and 2015 . These estimates were based on the economic and operating conditions existing at year-end 2016 and 2015 . 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. For 2016 and 2015, the primary internal technical person in charge of overseeing our reserves estimates had a Bachelor of Science in Physics and Mathematics and a Master's of Science in Civil Engineering. He had over 40 years of domestic and international experience in the exploration and production business including 40 years of reserve evaluations. He had been a registered Professional Engineer for over 25 years. As part of our internal control over financial reporting, for 2016 and 2015 we had a process for reviewing well production data and division of interest percentages prior to submitting well level data to NSAI to assist us in preparing reserve estimates. Our primary internal technical person and other members of management reviewed the reserve estimates prepared by NSAI, including the underlying assumptions and estimates upon which they are based, for accuracy and reasonableness. 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 were 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 and 2015 , the average spot price per barrel of oil based on the West Texas Intermediate price was $42.75 and $50.28 and the average price per MMBTU of gas based on the Henry Hub spot was $2.48 and $2.59 . 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 were imprecise and could be expected to change as future information became available. 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 2014 7,672 12,649 Revisions of previous estimates (855 ) (1,675 ) Extensions and discoveries 224 173 Acquisitions — — Sales (704 ) (1,223 ) Production (1,158 ) (1,967 ) Year-end 2015 5,179 7,957 Revisions of previous estimates (11 ) 631 Extensions and discoveries 29 — Acquisitions — — Sales (4,460 ) (3,756 ) Production (291 ) (996 ) Year-end 2016 446 3,836 Revisions of previous estimates — — Extensions and discoveries — — Acquisitions — — Sales (446 ) (3,836 ) Production — — Year-end 2017 — — Our share of ventures accounted for using the equity method: Year-end 2014 — 1,751 Revisions of previous estimates — (320 ) Production — (168 ) Year-end 2015 — 1,263 Revisions of previous estimates — 79 Production — (143 ) Year-end 2016 — 1,199 Sales — (1,199 ) Year-end 2017 — — Total consolidated and our share of equity method ventures: Year-end 2015 Proved developed reserves 5,179 9,220 Proved undeveloped reserves — — Total Year-end 2015 5,179 9,220 Year-end 2016 Proved developed reserves 446 5,035 Proved undeveloped reserves — — Total Year-end 2016 446 5,035 Year-end 2017 Proved developed reserves — — Proved undeveloped reserves — — Total Year-end 2017 — — _____________________ (a) Includes natural gas liquids (NGLs). We did not have any estimated reserves or wells with production of synthetic oil, synthetic gas or products of other non-renewable natural resources that are intended to be upgraded into synthetic oil and gas as of year-end 2017, 2016 or 2015. In 2017, we sold oil and gas wells located primarily in Texas and Louisiana. Our net reserves for those properties as of year-end 2016 were 446,000 barrels of oil and 5,035,000 Mcf of gas. 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 2016 and 2015 , 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 2017 , no new well additions in 2016 and 36 new well additions in 2015 . 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 2017 2016 (In thousands) Consolidated entities: Unproved oil and gas properties $ — $ 374 Proved oil and gas properties — 5,159 Total costs — 5,533 Less accumulated depreciation, depletion and amortization — (4,751 ) $ — $ 782 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 2017 2016 2015 (In thousands) Consolidated entities: Acquisition costs Proved properties $ — $ — $ — Unproved properties — 15 4,832 Exploration costs — 21 17,922 Development costs — 537 27,609 $ — $ 573 $ 50,363 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. Drilling and Other Exploratory and Development Activities The following tables set forth the number of gross and net oil and gas wells in which we participated: Gross Wells Exploratory Development Year Total Oil Gas Dry Oil Gas Dry 2017 — — — — — — — 2016 — — — — — — — 2015 (a) 38 2 — 1 34 — 1 _____________________ (a) Of the gross wells drilled in 2015, we operated 3 wells or 8 percent. The remaining wells represent our participations in wells operated by others. The exploratory dry hole was located in Oklahoma. Net Wells Exploratory Development Year Total Oil Gas Dry Oil Gas Dry 2017 — — — — — — — 2016 — — — — — — — 2015 6.3 0.7 — 0.8 4.3 — 0.5 Present Activities None. Delivery Commitments We have no oil or gas delivery commitments. Wells and Acreage We had no interest in any productive wells as of year-end 2017 . At year-end 2017 , 2016 and 2015 , we had royalty interests in 0 , 473 and 534 gross wells. In addition, at year-end 2017 , 2016 and 2015 , we had working interests in 0 , 32 and 400 gross wells. 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 2017 2016 2015 (In thousands) Consolidated entities: Future cash inflows $ — $ 24,304 $ 216,588 Future production and development costs — (2,988 ) (93,623 ) Future income tax expenses — (3,926 ) (22,218 ) Future net cash flows — 17,390 100,747 10% annual discount for estimated timing of cash flows — (7,077 ) (33,951 ) Standardized measure of discounted future net cash flows $ — $ 10,313 $ 66,796 Our share in ventures accounted for using the equity method: Future cash inflows $ — $ 2,010 $ 2,283 Future production and development costs — (216 ) (245 ) Future income tax expenses — (537 ) (774 ) Future net cash flows — 1,257 1,264 10% annual discount for estimated timing of cash flows — (585 ) (562 ) Standardized measure of discounted future net cash flows $ — $ 672 $ 702 Total consolidated and our share of equity method ventures $ — $ 10,985 $ 67,498 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 2014 $ 163,841 $ 1,775 $ 165,616 Changes resulting from: Net change in sales prices and production costs (136,536 ) (1,112 ) (137,648 ) Net change in future development costs 92 — 92 Sales of oil and gas, net of production costs (31,732 ) (428 ) (32,160 ) Net change due to extensions and discoveries 11,747 — 11,747 Net change due to acquisition of reserves — — — Net change due to divestitures of reserves (15,855 ) — (15,855 ) Net change due to revisions of quantity estimates (15,164 ) (267 ) (15,431 ) Previously estimated development costs incurred 15,096 — 15,096 Accretion of discount 22,600 286 22,886 Net change in timing and other 4,018 (210 ) 3,808 Net change in income taxes 48,689 658 49,347 Aggregate change for the year (97,045 ) (1,073 ) (98,118 ) Year-end 2015 66,796 702 67,498 Changes resulting from: Net change in sales prices and production costs (3,585 ) (60 ) (3,645 ) Net change in future development costs — — — Sales of oil and gas, net of production costs (5,663 ) (208 ) (5,871 ) Net change due to extensions and discoveries 410 — 410 Net change due to acquisition of reserves — — — Net change due to divestitures of reserves (63,535 ) — (63,535 ) Net change due to revisions of quantity estimates 1,304 63 1,367 Previously estimated development costs incurred — — — Accretion of discount 2,992 113 3,105 Net change in timing and other (128 ) (80 ) (208 ) Net change in income taxes 11,722 142 11,864 Aggregate change for the year (56,483 ) (30 ) (56,513 ) Year-end 2016 10,313 672 10,985 Changes resulting from: Net change in sales prices and production costs — — — Net change in future development costs — — — Sales of oil and gas, net of production costs — — — Net change due to extensions and discoveries — — — Net change due to acquisition of reserves — — — Net change due to divestitures of reserves (10,313 ) (672 ) (10,985 ) Net change due to revisions of quantity estimates — — — Previously estimated development costs incurred — — — Accretion of discount — — — Net change in timing and other — — — Net change in income taxes — — — Aggregate change for the year (10,313 ) (672 ) (10,985 ) Year-end 2017 $ — $ — $ — Results of Operations for Oil and Gas Producing Activities Our royalty interests were contractually defined and based on a percentage of production at prevailing market prices. We received our percentage of production in cash. Similarly, for operating properties our working interests and the associated net revenue interests were contractually defined and we paid our proportionate share of the capital and operating costs to develop and operate the well and we marketed our share of the production. Our revenues fluctuated 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 2017 2016 2015 (In thousands) Consolidated entities Revenues $ 1,399 $ 10,111 $ 51,553 Production costs (209 ) (4,392 ) (19,820 ) Exploration costs (34 ) (124 ) (11,864 ) Depreciation, depletion, amortization — (2,157 ) (28,774 ) Non-cash impairment of proved oil and gas properties and unproved leasehold interests (224 ) (612 ) (164,831 ) Oil and gas administrative expenses (1,197 ) (8,700 ) (11,700 ) Accretion expense — (56 ) (144 ) Income tax (expense) benefit (7 ) (20 ) 14,717 Results of operations (272 ) (5,950 ) (170,863 ) Our share in ventures accounted for using the equity method: Revenues $ 100 $ 284 $ 428 Production costs (19 ) (76 ) (102 ) Oil and gas administrative expenses (2 ) (35 ) (51 ) Income tax (expense) benefit — — 21 Results of operations $ 79 $ 173 $ 296 Total results of operations $ (193 ) $ (5,777 ) $ (170,567 ) 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, 2017
Quarterly Financial Information Disclosure [Abstract]
Summary of Quarterly Results of Operations (Unaudited)	Summary of Quarterly Results of Operations (Unaudited) Summarized quarterly financial results for 2017 and 2016 follows: First Quarter (a) Second Quarter (a) Third Quarter (a) Fourth Quarter (a) (In thousands, except per share amounts) 2017 Total revenues $ 22,305 $ 28,015 $ 33,136 $ 30,866 Gross profit (loss) (28,332 ) 11,559 11,251 10,065 Operating income (loss) 36,235 6,965 12,381 (15,816 ) Equity in earnings of unconsolidated ventures 6,362 2,747 1,764 7,026 Income (loss) from continuing operations before taxes attributable to Forestar Group Inc. 40,998 8,120 13,223 (12,298 ) Income from discontinued operations, net of taxes 418 1,229 37,193 7,191 Net income (loss) attributable to Forestar Group Inc. 25,205 (2,579 ) 45,202 (17,574 ) Net income (loss) per share — basic Continuing operations $ 0.59 $ (0.09 ) $ 0.19 $ (0.59 ) Discontinued operations $ 0.01 $ 0.03 $ 0.88 $ 0.17 Net income (loss) per share — basic $ 0.60 $ (0.06 ) $ 1.07 $ (0.42 ) Net income (loss) per share — diluted Continuing operations $ 0.58 (0.09 ) 0.19 $ (0.58 ) Discontinued operations $ 0.01 0.03 0.87 $ 0.18 Net income (loss) per share — diluted $ 0.59 (0.06 ) 1.06 $ (0.40 ) 2016 Total revenues $ 37,618 $ 47,992 $ 47,207 $ 64,497 Gross profit (loss) 18,579 (24,953 ) 17,403 17,352 Operating income 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 _____________________ (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) 2017 Continuing operations $ 37,900 $ — $ — $ 9,272 Discontinued operations $ — $ — $ — $ — 2016 Continuing operations $ — $ 48,826 $ 7,627 $ 3,874 Discontinued operations $ — $ 612 $ — $ —

Subsequent Event

Subsequent Event	12 Months Ended
	Dec. 31, 2017
Subsequent Events [Abstract]
Subsequent Event	Subsequent Event On February 8, 2018, we entered into and closed on a Purchase and Sale Agreement with Starwood Land, L.P. to sell 24 legacy projects for $232,000,000 . This strategic asset sale included projects owned both directly and indirectly through ventures and consisted of approximately 750 developed and under development lots, over 4,000 future undeveloped lots (including all real estate associated with the Cibolo Canyons mixed-use development), 730 unentitled acres in California, an interest in one multifamily operating property and a multifamily development site. The agreement contains representations, warranties and indemnities customary for a real estate industry asset sale and includes certain adjustment provisions to the purchase price. The estimated total net proceeds after certain purchase price adjustments, closing costs and other costs associated with selling these projects is expected to be approximately $216,000,000 . At year-end 2017, we have recorded the estimated fair value of these assets on our balance sheet and as a result have recognized a non-cash impairment charge of $3,000,000 related to the asset group. The owned real estate projects are classified as assets held for sale and our equity interests in ventures continued to be classified as investment in unconsolidated ventures at year-end 2017. The non-cash impairment is included in cost of real estate sales and other on our consolidated statements of income (loss). This transaction is not expected to have a material impact on our fiscal 2018 pre-tax earnings but is expected to generate tax losses which are currently anticipated to substantially reduce our income tax expense for fiscal 2018.

Schedule III - Consolidated Rea

Schedule III - Consolidated Real Estate and Accumulated Depreciation	12 Months Ended
	Dec. 31, 2017
SEC Schedule III, Real Estate and Accumulated Depreciation Disclosure [Abstract]
SEC Schedule III, Real Estate and Accumulated Depreciation Disclosure [Text Block]	Forestar Group Inc. Schedule III — Consolidated Real Estate and Accumulated Depreciation Year-End 2017 (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 Real Estate, Net CALIFORNIA Contra Costa County San Joaquin River 12,225 (10,558 ) 1,667 1,667 (b) COLORADO Douglas County Cielo 3,933 3,187 7,120 7,120 2016 FLORIDA Brevard County The Preserves at Stonebriar 3,002 244 3,246 3,246 2017 Manatee County Palisades 4,516 370 4,886 4,886 2017 Sarasota County Fox Creek 12,257 742 12,999 12,999 2017 GEORGIA Cobb County West Oaks 1,669 748 2,417 2,417 2015 2015 Gwinnett County Independence 15,937 2,651 18,588 18,588 2017 2017 Paulding County Harris Place 265 (219 ) 46 46 2012 Seven Hills 2,964 1,198 61 4,223 4,223 2012 NORTH CAROLINA Cabbarrus County Moss Creek 1,254 116 1,370 1,370 2017 2016 SOUTH CAROLINA York County Habersham 3,877 (948 ) 506 3,435 3,435 2014 2013 TENNESEE Williamson County Morgan Farms 6,841 (4,168 ) 225 2,898 2,898 2013 2013 Weatherford Estates 856 (922 ) 139 73 73 2015 2014 Wilson County Beckwith Crossing 1,294 1,070 275 2,639 2,639 2015 2014 TEXAS Calhoun County Caracol 8,603 (8,025 ) 578 578 2006 2006 Collin County Lakes of Prosper 8,951 (9,094 ) 453 310 310 2012 Parkside 2,177 (1,937 ) 307 547 547 2014 2013 Timber Creek 7,282 6,410 212 13,904 13,904 2007 2007 Denton County Lantana 27,673 (19,680 ) 585 8,578 8,578 2000 1999 River's Edge 1,227 445 1,672 1,672 2014 The Preserve at Pecan Creek 5,855 (681 ) 256 5,430 5,430 2006 2005 Fort Bend County Southern Colony 3,024 4,090 7,114 7,114 2017 Willow Creek Farms 290 3,479 (1,741 ) 60 1,798 1,798 2012 2012 Harris County City Park 3,946 (3,794 ) 229 381 381 2002 2001 Imperial Forest 5,345 (634 ) 5 4,716 4,716 2015 2014 Kaufman County Lakewood Trails 8,009 340 8,349 8,349 2017 Tarrant County Summer Creek Ranch 2,887 (1,651 ) 1,236 1,236 2012 The Bar C Ranch 1,365 3,623 430 5,418 5,418 2012 Other — 4,742 — 4,742 4,742 Total Real Estate, Net $ 290 $ 160,713 $ — $ (34,076 ) $ 3,743 $ 130,380 $ — $ 130,380 $ — Real Estate Held for Sale (c) CALIFORNIA Los Angeles County Land In Entitlement Process $ 3,950 $ 21,752 $ 25,702 $ 25,702 1997 COLORADO Douglas County Pinery West 7,308 3,849 11,157 11,157 2006 2006 Weld County Buffalo Highlands 3,001 (295 ) 2,706 2,706 2006 2005 Johnstown Farms 2,749 4,073 $ 100 6,922 6,922 2002 2002 Stonebraker 3,878 (1,786 ) 2,092 2,092 2005 2005 NORTH CAROLINA Mecklenburg County Walden 12,085 5,446 350 17,881 17,881 2016 2015 SOUTH CAROLINA Lancaster County Ansley Park 5,089 4,198 315 9,602 9,602 2017 2015 TENNESEE Williamson County Scales Farmstead 3,575 4,848 455 8,878 8,878 2015 TEXAS Bastrop County Hunter’s Crossing 3,613 3,970 7,583 7,583 2001 2001 Bexar County Cibolo Canyons 17,305 22,088 1,696 41,089 41,089 2004 1986 Dallas County Stoney Creek 12,822 1,712 608 15,142 15,142 2007 2007 Fort Bend County Summer Lakes 4,269 (1,100 ) 89 3,258 3,258 2013 2012 Summer Park 4,804 (2,490 ) 17 2,331 2,331 2013 2012 Harris County Barrington 8,950 (7,892 ) 1,058 1,058 2011 Hays County Arrowhead Ranch 12,856 7,639 286 20,781 20,781 2015 2007 Travis County West Austin multifamily site 7,274 (1,525 ) 5,749 5,749 2014 Other (d) (1,684 ) (1,684 ) (1,684 ) Total Real Estate Held for Sale (c) $ — $ 113,528 $ — $ 62,803 $ 3,916 $ 180,247 $ — $ 180,247 $ — Total Investment in Real Estate $ 290 $ 274,241 $ — $ 28,727 $ 7,659 $ 310,627 $ — $ 310,627 $ — (a) We do not capitalize carrying costs until development begins. (b) The acquisition date is not available. (c) Included in the strategic asset sale to Starwood on February 8, 2018. Please read Note 22 — Subsequent Event for additional information regarding this transaction. (d) Includes $3,000,000 in non-cash impairment charges in fourth quarter 2017 associated with the asset group sold to Starwood. Reconciliation of real estate (a) : 2017 2016 2015 (In thousands) Balance at beginning of year $ 293,003 $ 618,844 $ 607,133 Amounts capitalized 105,611 89,780 124,633 Amounts retired or adjusted (87,987 ) (415,621 ) (112,922 ) Balance at close of period $ 310,627 $ 293,003 $ 618,844 Reconciliation of accumulated depreciation: 2017 2016 2015 (In thousands) Balance at beginning of year $ — $ (32,129 ) $ (31,377 ) Depreciation expense — (816 ) (6,810 ) Amounts retired or adjusted — 32,945 6,058 Balance at close of period $ — $ — $ (32,129 ) (a) Includes real estate classified as assets held for sale as of year-end 2017.

Summary of Significant Accoun30

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2017
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. At year-end 2016, we had 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 consolidated balance sheets for all periods presented. In addition, in 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.
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.
Cash Flows	Cash Flows The consolidated statements of cash flows for 2017 , 2016 and 2015 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.
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. With the sale of our remaining oil and gas entities in 2017 we no longer have asset retirement obligations 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. Prior to the sale, we recorded the fair value of a liability for an asset retirement obligation in the period in which it was 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).
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, 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.
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 2017 , we sold our remaining owned mineral assets for approximately $85,700,000 and as a result of this sale we recorded a non-cash impairment charge of $37,900,000 related to the mineral resources reporting unit goodwill which is included in cost of mineral resources on our consolidated statements of income (loss). At year-end 2016, we performed our annual goodwill impairment evaluation and concluded that goodwill related to our central Texas water assets was impaired because the carrying value exceeded the fair value and recorded a $3,874,000 non-cash impairment charge
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.
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.
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. In certain instances earnest money deposits are subject to mortgages which are secured by the real estate under contract with the home builder. These mortgages expire when the earnest money is released to the home builders as lots are developed and sold. At year-end 2017 , $40,408,000 of real estate was subject to earnest money mortgages, including $25,712,000 classified as assets held for sale. 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 in collecting these reimbursements. 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. We generally determine fair value based on the present value of future 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.
Reclassifications	Reclassifications In 2017, we have reclassified prior years' restricted cash that was included in other assets to a separate line item on our consolidated balance sheets to conform to the current year presentation.
Revenue	Revenue 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 exclude from revenue amounts we collect from utility or improvement districts related to the conveyance of water, sewer and other infrastructure related assets. 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.
Share-Based Compensation	Share-Based Compensation We use the Black-Scholes option pricing model to determine the fair value of stock options, and a Monte Carlo simulation pricing model to determine the fair value of market-leveraged stock units and for stock options with market conditions. The fair value of equity-settled awards is determined on the grant date and the fair value of cash-settled awards is determined at period end. We expense share-based awards ratably over the vesting period or earlier based on retirement eligibility.
Owned Mineral Interests	Owned Mineral Interests Historically, we leased our mineral interests to third-party exploration and production entities, we retained a royalty interest and may have taken an additional participation in production, including a working interest. In first quarter 2017, we sold our remaining owned mineral assets.
Oil and Gas Properties (Discontinued Operations)	Oil and Gas Properties (Discontinued Operations) We used 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 were capitalized. Costs to drill exploratory wells were capitalized pending determination of whether the wells had proved reserves and if determined incapable of producing commercial quantities of oil and gas these costs were expensed as dry hole costs. At year-end 2017 , we had 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 were expensed as incurred. Production costs incurred to maintain wells and related equipment were charged to expense as incurred. Depreciation and depletion of producing oil and gas properties was calculated using the units-of-production method. Proved developed reserves were used to compute unit rates for unamortized tangible and intangible drilling and completion costs. Proved reserves were used to compute unit rates for unamortized acquisition of proved leasehold costs. Unit-of-production amortization rates were revised whenever there was an indication of the need for revision but at least once a year and those revisions were accounted for prospectively as changes in accounting estimates. We no longer own any oil and gas working interest properties. Impairment of Oil and Gas Properties (Discontinued Operations) Historically, we evaluated our oil and gas properties, including facilities and equipment, for impairment whenever events or changes in circumstances indicated that the carrying value of the asset may not be recoverable. We estimate the expected undiscounted future cash flows of our oil and gas properties and compared such undiscounted future cash flows to the carrying amount of the oil and gas properties to determine if the carrying amount was recoverable. If the carrying amount exceeded the estimated undiscounted future cash flows, we adjusted the carrying amount of the oil and gas properties to fair value. The factors used to determine fair value were subject to our judgment and expertise and included, but were 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. Assessing unproved leasehold properties to determine impairment required significant judgment. We assessed 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.
New and Pending Accounting Pronouncements	New and Pending Accounting Pronouncements Adoption of New Accounting Standards 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. We adopted the updated standard on January 1, 2017. Effective first quarter 2017, stock-based compensation (SBC) excess tax benefits or deficiencies are reflected in the consolidated statements of income (loss) as a component of the provision for income taxes, whereas they previously were recognized in equity to the extent additional paid-in capital pool was available. Additionally, our consolidated statements of cash flows will now present excess tax benefits as an operating activity, if applicable. Finally, we have elected to account for forfeitures as they occur, rather than estimate expected forfeitures. The adoption of this guidance did not have a material impact on our consolidated financial statements. 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. The updated standard becomes effective for annual and interim periods beginning after December 15, 2017. Due to our change in fiscal year-end, this standard is effective for us beginning October 1, 2018. 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 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. In May 2017, the FASB issued ASU 2017-09, Compensation - Stock Compensation (Topic 718), in order to provide guidance about which changes to terms or conditions of a share-based payment award require an entity to apply modification accounting in Topic 718. The updated standard is effective for financial statements issued for annual periods beginning after December 15, 2017. 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.

Summary of Significant Accoun31

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2017
Accounting Policies [Abstract]
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 2017 2016 (In thousands) Buildings and building improvements 10 to 40 years $ 2,162 $ 2,700 Property and equipment 2 to 10 years 4,513 4,957 6,675 7,657 Less: accumulated depreciation (4,672 ) (4,541 ) $ 2,003 $ 3,116

Real Estate (Tables)

Real Estate (Tables)	12 Months Ended
	Dec. 31, 2017
Real Estate [Abstract]
Real Estate	Real estate consists of: At Year-End 2017 2016 (In thousands) Entitled, developed and under development projects $ 127,442 $ 263,859 Other real estate costs (principally land in entitlement in 2016) 2,938 29,144 $ 130,380 $ 293,003

Investment in Unconsolidated 33

Investment in Unconsolidated Ventures (Tables)	12 Months Ended
	Dec. 31, 2017
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 2017 2016 2017 2016 2017 2016 2017 2016 (In thousands) 242, LLC (b) (e) $ 19,525 $ 26,503 $ — $ 1,107 $ 19,357 $ 23,136 $ 9,131 $ 10,934 CL Ashton Woods, LP (c) 124 2,653 — — 104 2,198 83 1,107 CL Realty, LLC 4,528 8,048 — — 4,344 7,899 2,172 3,950 CREA FMF Nashville LLC (b) 2,315 56,081 — 37,446 684 17,091 342 4,923 Elan 99, LLC (e) 49,080 49,652 36,348 36,238 11,204 13,100 10,078 11,790 FMF Littleton LLC 66,849 70,282 45,836 44,446 20,289 23,798 5,144 6,128 FMF Peakview LLC — — — — — — — — FOR/SR Forsyth LLC 11,598 10,672 1,551 1,568 10,041 8,990 9,037 8,091 HM Stonewall Estates, Ltd — 852 — — — 852 — 477 LM Land Holdings, LP (c) 19,479 25,538 — 3,477 12,074 20,945 5,935 9,685 MRECV DT Holdings LLC (e) 3,043 4,155 — — 3,043 4,144 2,594 3,729 MRECV Edelweiss LLC/MRECV Lender VIII LLC (e) 8,127 3,484 — — 8,127 3,484 7,189 3,358 MRECV Juniper Ridge LLC (e) 3,936 4,156 — — 3,936 4,156 3,331 3,741 MRECV Meadow Crossing II LLC (e) 3,129 2,492 — — 3,129 2,491 2,738 2,242 Miramonte Boulder Pass, LLC (e) 7,573 10,738 1,398 4,006 4,843 5,265 4,633 5,330 Temco Associates, LLC 4,448 4,368 — — 4,345 4,253 2,172 2,126 Other ventures — — — — — — — — $ 203,754 $ 279,674 $ 85,133 $ 128,288 $ 105,520 $ 141,802 $ 64,579 $ 77,611
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 2017 2016 2015 2017 2016 2015 2017 2016 2015 (In thousands) 242, LLC (b) (e) $ 13,073 $ 5,835 $ 20,995 $ 8,021 $ 1,259 $ 9,588 $ 4,096 $ 668 $ 4,919 CL Ashton Woods, LP 3,179 2,870 9,820 1,456 914 3,881 1,816 1,332 5,000 CL Realty, LLC 499 567 856 (1,155 ) 237 424 (578 ) 119 212 CREA FMF Nashville LLC (b) (d) 5,440 4,955 1,227 17,267 (1,420 ) (1,696 ) 7,563 1,103 (1,696 ) Elan 99, LLC (e) 4,596 1,392 — (1,896 ) (2,739 ) (49 ) (1,712 ) (2,465 ) (44 ) FMF Littleton LLC 6,366 3,116 120 192 (571 ) (367 ) 48 (143 ) (92 ) FMF Peakview LLC — 939 2,057 — (248 ) (1,116 ) — (50 ) (223 ) FOR/SR Forsyth LLC — — — (148 ) (65 ) — (134 ) (58 ) — HM Stonewall Estates, Ltd. 496 2,112 3,990 243 832 1,881 103 361 952 LM Land Holdings, LP (c) 22,127 10,001 10,956 10,629 7,288 8,251 3,563 2,458 3,342 MRECV DT Holdings LLC (e) 1,196 495 — 1,173 477 167 911 429 — MRECV Edelweiss LLC/MRECV Lender VIII LLC (e) 1,018 416 — 1,016 409 151 789 368 137 MRECV Juniper Ridge LLC (e) 1,445 379 — 1,445 380 106 1,089 342 — MRECV Meadow Crossing II LLC (e) 638 267 — 638 220 — 496 198 — Miramonte Boulder Pass, LLC (e) 5,483 4,923 — 177 (399 ) (250 ) (197 ) (200 ) (125 ) PSW Communities, LP — — 29,986 — — 2,688 — — 1,169 TEMCO Associates, LLC 192 1,344 9,485 92 440 2,358 46 220 1,179 Other ventures — 6,519 36,237 — 2,105 33,303 — 1,441 1,278 $ 65,748 $ 46,130 $ 125,729 $ 39,150 $ 9,119 $ 59,320 $ 17,899 $ 6,123 $ 16,008 _____________________ (a) Total includes current maturities of $84,098,000 at year-end 2017 , of which $79,515,000 is non-recourse to us, and $89,756,000 at year-end 2016 , of which $78,557,000 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 $548,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2017 . (c) Includes unrecognized basis difference of $448,000 which is reflected as an increase of our investment in unconsolidated ventures at year-end 2017 . This difference will be amortized as expense over the life of the investment and included in our share of earnings (loss) from the respective venture. (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 accordance with the partnership agreement. (e) Included in our strategic asset sale to Starwood on February 8, 2018. Please read Note 22 - Subsequent Event for additional information regarding this transaction.

Goodwill and Other Intangible34

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2017
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 2017 2016 (In thousands) Goodwill $ — $ 37,900 Identified intangibles, net 448 — $ 448 $ 37,900

Held for Sale (Tables)

Held for Sale (Tables)	12 Months Ended
	Dec. 31, 2017
Discontinued Operations and Disposal Groups [Abstract]
Assets and Liabilities of Properties Held for Sale	The major classes of assets and liabilities held for sale were as follows: At Year-End 2017 2016 Assets Held for Sale: (In thousands) Real estate $ 180,247 $ 19,931 Timber — 1,682 Other intangible assets — 1,681 Oil and gas properties and equipment, net — 782 Property and equipment, net 1,360 6,301 $ 181,607 $ 30,377 Liabilities Held for Sale: Accounts payable 1,017 — Other liabilities — 103 $ 1,017 $ 103

Discontinued Operations (Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2017
Discontinued Operations and Disposal Groups [Abstract]
Summarized Results from Discontinued Operations	Summarized results from discontinued operations were as follows: For the Year 2017 2016 2015 Revenues $ 15 $ 5,862 $ 43,845 Cost of oil and gas producing activities (52 ) (6,578 ) (221,402 ) Other operating expenses 226 (7,754 ) (10,363 ) Income (loss) from discontinued operations before income taxes $ 189 $ (8,470 ) $ (187,920 ) Gain (loss) on sale of assets before income taxes (197 ) (13,664 ) (706 ) Income tax benefit 46,039 5,269 2,496 Income (loss) from discontinued operations, net of taxes $ 46,031 $ (16,865 ) $ (186,130 )
Disposal Groups, Including Discontinued Operations	The major classes of assets and liabilities of discontinued operations at year-end 2017 and 2016 are as follows: At Year-End 2017 2016 (In thousands) Assets of Discontinued Operations: Receivables, net of allowance for bad debt $ — $ 6 Prepaid expenses — 8 $ — $ 14 Liabilities of Discontinued Operations: Accounts payable $ — $ 67 Other accrued expenses — 5,228 $ — $ 5,295
Significant Operation and Investing Activities of DIscontinued Operations	Cash (used in) or provided by operating activities and investing activities of discontinued operations are as follows: For the Year 2017 2016 2015 (In thousands) Operating activities: Asset impairments $ — $ 612 $ 105,337 Changes in accounts payable and other accrued liabilities (3,000 ) — — Dry hole and unproved leasehold impairment charges — — 67,639 Loss (gain) on sale of assets 197 13,664 706 Depreciation, depletion and amortization — 2,202 28,391 $ (2,803 ) $ 16,478 $ 202,073 Investing activities: Oil and gas properties and equipment $ — $ (579 ) $ (49,717 ) Proceeds from sales of assets 200 77,105 17,800 $ 200 $ 76,526 $ (31,917 )

Receivables (Tables)

Receivables (Tables)	12 Months Ended
	Dec. 31, 2017
Receivables [Abstract]
Receivables	Receivables consist of: At Year-End 2017 2016 (In thousands) Other receivables and accrued interest 2,557 1,505 Loans secured by real estate, average interest rate of 5.40% at year-end 2017 and 4.94% at year-end 2016 3,776 7,452 6,333 8,957 Allowance for bad debts (26 ) (26 ) $ 6,307 $ 8,931

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2017
Debt Disclosure [Abstract]
Debt	Debt consists of: At Year-End 2017 2016 (In thousands) 8.50% senior secured notes due 2022 — 5,200 3.75% convertible senior notes due 2020, net of discount 108,139 104,673 Other indebtedness due through 2018 at variable and fixed interest rates ranging from 5.0% to 5.50% 290 485 $ 108,429 $ 110,358

Fair Value (Tables)

Fair Value (Tables)	12 Months Ended
	Dec. 31, 2017
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 2017 Year-End 2016 Carrying Amount Fair Value Carrying Amount Fair Value Valuation Technique (In thousands) Fixed rate debt $ (109,197 ) $ (109,114 ) $ (111,506 ) $ (109,789 ) Level 2
Carrying Value of Assets	Non-financial assets measured at fair value on a non-recurring basis are as follows: Year-End 2017 Year-End 2016 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (In thousands) Non-financial Assets and Liabilities: Real estate held for sale $ — $ 180,247 $ — $ 180,247 $ — $ — $ — $ — Central Texas water assets $ — $ — $ 1,987 $ 1,987 $ — $ — $ — $ —

Net Income (Loss) per Share (Ta

Net Income (Loss) per Share (Tables)	12 Months Ended
	Dec. 31, 2017
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 2017 2016 2015 (In thousands) Numerator: Continuing operations Net income (loss) from continuing operations $ 6,301 $ 77,044 $ (26,241 ) Less: Net (income) attributable to noncontrolling interest (2,078 ) (1,531 ) (676 ) Earnings (loss) available for diluted earnings per share $ 4,223 $ 75,513 $ (26,917 ) Less: Undistributed net income from continuing operations allocated to participating securities — (13,493 ) — Earnings (loss) from continuing operations available to common shareholders for basic earnings per share $ 4,223 $ 62,020 $ (26,917 ) Discontinued operations Net income (loss) from discontinued operations available for diluted earnings per share 46,031 (16,865 ) (186,130 ) Less: Undistributed net income from discontinued operations allocated to participating securities — 3,014 — Earnings (loss) from discontinued operations available to common shareholders for basic earnings per share 46,031 (13,851 ) (186,130 ) Denominator: Weighted average common shares outstanding — basic 42,143 34,546 34,266 Weighted average common shares upon conversion of participating securities (a) — 7,515 — Dilutive effect of stock options, restricted stock and equity-settled awards 238 273 — Total weighted average shares outstanding — diluted 42,381 42,334 34,266 Anti-dilutive awards excluded from diluted weighted average shares outstanding 1,093 2,102 10,864 _____________________ (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

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Income Tax Expense	Income tax expense from continuing operations consists of: For the Year 2017 2016 2015 (In thousands) Current tax provision: U.S. Federal $ (44,177 ) $ (15,089 ) $ 6,740 State and other (3,378 ) (1,520 ) (418 ) (47,555 ) (16,609 ) 6,322 Deferred tax provision: U.S. Federal 1,678 1,382 (38,262 ) State and other 57 (75 ) (3,191 ) 1,735 1,307 (41,453 ) Income tax expense $ (45,820 ) $ (15,302 ) $ (35,131 )
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 2017 2016 2015 Federal statutory rate (benefit) 35 % 35 % 35 % State, net of federal benefit 3 — 10 Valuation allowance (42 ) (19 ) 348 Tax rate change due to new tax act 40 — — Noncontrolling interests (1 ) (1 ) (3 ) Installment sale ace adjustment — 2 — Stock based compensation 11 — 5 Goodwill 25 — — Merger costs 18 — — Oil and gas percentage depletion — — (1 ) Other (1 ) — 1 Effective tax rate 88 % 17 % 395 %
Significant Components of Deferred Taxes	Significant components of deferred taxes are: At Year-End 2017 2016 (In thousands) Deferred Tax Assets: Real estate $ 37,513 $ 50,759 Employee benefits 1,510 13,185 Net operating loss carryforwards 2,305 2,804 Oil and gas properties — 1,672 AMT credits 1,690 5,900 Income producing properties 794 2,055 Oil and gas percentage depletion carryforwards — 3,478 Accruals not deductible until paid 196 552 Gross deferred tax assets 44,008 80,405 Valuation allowance (39,578 ) (73,405 ) Deferred tax asset net of valuation allowance 4,430 7,000 Deferred Tax Liabilities: Undeveloped land — (1,359 ) Convertible debt (2,402 ) (5,035 ) Timber — (283 ) Gross deferred tax liabilities (2,402 ) (6,677 ) Net Deferred Tax Asset (Liability) $ 2,028 $ 323
Summary of Unrecognized Tax Benefits	A reconciliation of the beginning and ending amount of tax benefits not recognized for book purposes is as follows: At Year-End (In thousands) 2017 2016 2015 Balance at beginning of year $ 2,499 $ — $ — Increases (decreases) for tax positions of current year — 2,499 — Decreases for dispositions and other (1,449 ) — — Balance at end of year $ 1,050 $ 2,499 $ —

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2017
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 2017 Revenues $ 112,746 $ 1,502 $ 74 $ — $ 114,322 Depreciation, depletion and amortization 131 28 25 5,279 5,463 Equity in earnings of unconsolidated ventures 16,500 1,395 4 — 17,899 Income (loss) before taxes from continuing operations attributable to Forestar Group Inc. 47,281 45,552 (6,393 ) (36,397 ) (a) 50,043 Total assets 386,222 — 3,346 372,344 761,912 Investment in unconsolidated ventures 64,579 — — — 64,579 Capital expenditures 52 2,400 — — 2,452 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 Investment in unconsolidated ventures 82,453 — — — 82,453 Capital expenditures 13,644 59 745 242 14,690 _____________________ (a) Items not allocated to segments consist of: For the Year 2017 2016 2015 (In thousands) General and administrative expense $ (50,354 ) $ (18,274 ) $ (24,802 ) Share-based and long-term incentive compensation expense (7,201 ) (4,425 ) (4,474 ) Gain on sale of assets 28,674 48,891 — Interest expense (8,532 ) (19,985 ) (34,066 ) Loss on extinguishment of debt, net (611 ) (35,864 ) — Other corporate non-operating income 1,627 350 256 $ (36,397 ) $ (29,307 ) $ (63,086 ) (b) Total assets excludes assets of discontinued operations of $14,000 and $104,967,000 in 2016 and 2015.

Share-Based Compensation (Table

Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2017
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 2017 2016 2015 (In thousands) Cash-settled awards $ 634 $ 717 $ (3,127 ) Equity-settled awards 5,001 2,444 5,026 Restricted stock — 22 (8 ) Stock options 1,008 854 2,355 Total share-based compensation $ 6,643 $ 4,037 $ 4,246 Deferred cash 558 388 228 $ 7,201 $ 4,425 $ 4,474
Share-Based Compensation Expense (Income) Included in Operating Expense	Share-based and long-term incentive compensation expense is included in: For the Year 2017 2016 2015 (In thousands) General and administrative $ 6,177 $ 3,323 $ 2,451 Other operating 1,024 1,102 2,023 $ 7,201 $ 4,425 $ 4,474
Summarized Activity of Cash-Settled Restricted Stock Unit Awards	The following table summarizes the activity of cash-settled restricted stock unit awards in 2017 : Equivalent Units Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 42 $14.98 Granted — — Vested (30 ) 15.66 Forfeited (12 ) 13.15 Non-vested at end of period — —
Summarized Activity of Cash-Settled Stock Appreciation Rights	The following table summarizes the activity of cash-settled stock appreciation rights in 2017 : 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 374 $12.97 3 $773 Granted — — Exercised (234 ) 10.14 Forfeited (140 ) 17.69 Balance at end of period — — 0 — Exercisable at end of period — — 0 —
Summarized Activity of Equity-Settled Awards	The following table summarizes the activity of equity-settled awards in 2017 : Equivalent Units Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 555 $ 14.70 Granted 198 14.55 Vested (653 ) 14.28 Forfeited (14 ) 14.59 Non-vested at end of period 86 17.54
Summarized Activity of Stock Option Awards	The following table summarizes the activity of stock option awards in 2017 : Options Outstanding Weighted Average Exercise or Settlement 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 1,836 $ 19.39 5 $ 449 Granted — — Exercised or settled in merger (768 ) 14.07 Forfeited (1,068 ) 23.21 Balance at end of period — — — — Exercisable at end of period — — — —
Schedule of Fair Value Assumptions of Stock Options	We estimated the grant date fair value of stock options 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 grant date fair value of MSU awards using a Monte Carlo simulation pricing model and the following assumptions: For the Year 2015 Expected stock price volatility 32.9 % Risk-free interest rate 1.0 % Expected dividend yield — % Weighted average grant date fair value of MSU awards (per unit) $ 15.11

Supplemental Oil and Gas Disc44

Supplemental Oil and Gas Disclosures (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2017
Oil and Gas In Process Activities [Line Items]
Summary of Estimated Quantities of Proved Developed Oil and Natural Gas Reserves	Estimated quantities of proved oil and gas reserves are summarized as follows: Reserves Oil (a) (Barrels) Gas (Mcf) (In thousands) Consolidated entities: Year-end 2014 7,672 12,649 Revisions of previous estimates (855 ) (1,675 ) Extensions and discoveries 224 173 Acquisitions — — Sales (704 ) (1,223 ) Production (1,158 ) (1,967 ) Year-end 2015 5,179 7,957 Revisions of previous estimates (11 ) 631 Extensions and discoveries 29 — Acquisitions — — Sales (4,460 ) (3,756 ) Production (291 ) (996 ) Year-end 2016 446 3,836 Revisions of previous estimates — — Extensions and discoveries — — Acquisitions — — Sales (446 ) (3,836 ) Production — — Year-end 2017 — — Our share of ventures accounted for using the equity method: Year-end 2014 — 1,751 Revisions of previous estimates — (320 ) Production — (168 ) Year-end 2015 — 1,263 Revisions of previous estimates — 79 Production — (143 ) Year-end 2016 — 1,199 Sales — (1,199 ) Year-end 2017 — — Total consolidated and our share of equity method ventures: Year-end 2015 Proved developed reserves 5,179 9,220 Proved undeveloped reserves — — Total Year-end 2015 5,179 9,220 Year-end 2016 Proved developed reserves 446 5,035 Proved undeveloped reserves — — Total Year-end 2016 446 5,035 Year-end 2017 Proved developed reserves — — Proved undeveloped reserves — — Total Year-end 2017 — — _____________________ (a) Includes natural gas liquids (NGLs).
Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development Activities	Costs incurred in oil and gas property acquisition, exploration and development activities, whether capitalized or expensed, follows: For the Year 2017 2016 2015 (In thousands) Consolidated entities: Acquisition costs Proved properties $ — $ — $ — Unproved properties — 15 4,832 Exploration costs — 21 17,922 Development costs — 537 27,609 $ — $ 573 $ 50,363
Schedule of Development Wells Drilled	The following tables set forth the number of gross and net oil and gas wells in which we participated: Gross Wells Exploratory Development Year Total Oil Gas Dry Oil Gas Dry 2017 — — — — — — — 2016 — — — — — — — 2015 (a) 38 2 — 1 34 — 1 _____________________ (a) Of the gross wells drilled in 2015, we operated 3 wells or 8 percent. The remaining wells represent our participations in wells operated by others. The exploratory dry hole was located in Oklahoma. Net Wells Exploratory Development Year Total Oil Gas Dry Oil Gas Dry 2017 — — — — — — — 2016 — — — — — — — 2015 6.3 0.7 — 0.8 4.3 — 0.5
Schedule of Exploratory Wells Drilled	The following tables set forth the number of gross and net oil and gas wells in which we participated: Gross Wells Exploratory Development Year Total Oil Gas Dry Oil Gas Dry 2017 — — — — — — — 2016 — — — — — — — 2015 (a) 38 2 — 1 34 — 1 _____________________ (a) Of the gross wells drilled in 2015, we operated 3 wells or 8 percent. The remaining wells represent our participations in wells operated by others. The exploratory dry hole was located in Oklahoma. Net Wells Exploratory Development Year Total Oil Gas Dry Oil Gas Dry 2017 — — — — — — — 2016 — — — — — — — 2015 6.3 0.7 — 0.8 4.3 — 0.5
Estimates of Future Cash Flows from Proved Developed Oil and Natural Gas Reserves	Estimates of future cash flows from proved oil and gas reserves are shown in the following table. Estimated income taxes are calculated by applying the appropriate tax rates to the estimated future pre-tax net cash flows less depreciation of the tax basis of properties and the statutory depletion allowance. At Year-End 2017 2016 2015 (In thousands) Consolidated entities: Future cash inflows $ — $ 24,304 $ 216,588 Future production and development costs — (2,988 ) (93,623 ) Future income tax expenses — (3,926 ) (22,218 ) Future net cash flows — 17,390 100,747 10% annual discount for estimated timing of cash flows — (7,077 ) (33,951 ) Standardized measure of discounted future net cash flows $ — $ 10,313 $ 66,796 Our share in ventures accounted for using the equity method: Future cash inflows $ — $ 2,010 $ 2,283 Future production and development costs — (216 ) (245 ) Future income tax expenses — (537 ) (774 ) Future net cash flows — 1,257 1,264 10% annual discount for estimated timing of cash flows — (585 ) (562 ) Standardized measure of discounted future net cash flows $ — $ 672 $ 702 Total consolidated and our share of equity method ventures $ — $ 10,985 $ 67,498
Changes in Standardized Measure of Discounted Future Net Cash Flow	Changes in the standardized measure of discounted future net cash flow follows: For the Year Consolidated Our Share of Equity Method Ventures Total (In thousands) Year-end 2014 $ 163,841 $ 1,775 $ 165,616 Changes resulting from: Net change in sales prices and production costs (136,536 ) (1,112 ) (137,648 ) Net change in future development costs 92 — 92 Sales of oil and gas, net of production costs (31,732 ) (428 ) (32,160 ) Net change due to extensions and discoveries 11,747 — 11,747 Net change due to acquisition of reserves — — — Net change due to divestitures of reserves (15,855 ) — (15,855 ) Net change due to revisions of quantity estimates (15,164 ) (267 ) (15,431 ) Previously estimated development costs incurred 15,096 — 15,096 Accretion of discount 22,600 286 22,886 Net change in timing and other 4,018 (210 ) 3,808 Net change in income taxes 48,689 658 49,347 Aggregate change for the year (97,045 ) (1,073 ) (98,118 ) Year-end 2015 66,796 702 67,498 Changes resulting from: Net change in sales prices and production costs (3,585 ) (60 ) (3,645 ) Net change in future development costs — — — Sales of oil and gas, net of production costs (5,663 ) (208 ) (5,871 ) Net change due to extensions and discoveries 410 — 410 Net change due to acquisition of reserves — — — Net change due to divestitures of reserves (63,535 ) — (63,535 ) Net change due to revisions of quantity estimates 1,304 63 1,367 Previously estimated development costs incurred — — — Accretion of discount 2,992 113 3,105 Net change in timing and other (128 ) (80 ) (208 ) Net change in income taxes 11,722 142 11,864 Aggregate change for the year (56,483 ) (30 ) (56,513 ) Year-end 2016 10,313 672 10,985 Changes resulting from: Net change in sales prices and production costs — — — Net change in future development costs — — — Sales of oil and gas, net of production costs — — — Net change due to extensions and discoveries — — — Net change due to acquisition of reserves — — — Net change due to divestitures of reserves (10,313 ) (672 ) (10,985 ) Net change due to revisions of quantity estimates — — — Previously estimated development costs incurred — — — Accretion of discount — — — Net change in timing and other — — — Net change in income taxes — — — Aggregate change for the year (10,313 ) (672 ) (10,985 ) Year-end 2017 $ — $ — $ —
Information About Results of Operations of Oil and Natural Gas Interests	Information about the results of operations of our oil and gas interests follows: For the Year 2017 2016 2015 (In thousands) Consolidated entities Revenues $ 1,399 $ 10,111 $ 51,553 Production costs (209 ) (4,392 ) (19,820 ) Exploration costs (34 ) (124 ) (11,864 ) Depreciation, depletion, amortization — (2,157 ) (28,774 ) Non-cash impairment of proved oil and gas properties and unproved leasehold interests (224 ) (612 ) (164,831 ) Oil and gas administrative expenses (1,197 ) (8,700 ) (11,700 ) Accretion expense — (56 ) (144 ) Income tax (expense) benefit (7 ) (20 ) 14,717 Results of operations (272 ) (5,950 ) (170,863 ) Our share in ventures accounted for using the equity method: Revenues $ 100 $ 284 $ 428 Production costs (19 ) (76 ) (102 ) Oil and gas administrative expenses (2 ) (35 ) (51 ) Income tax (expense) benefit — — 21 Results of operations $ 79 $ 173 $ 296 Total results of operations $ (193 ) $ (5,777 ) $ (170,567 )
Consolidated Entities
Oil and Gas In Process Activities [Line Items]
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure	Capitalized costs related to our oil and gas producing activities classified as assets held for sale at year-end 2016 are as follows: At Year-End 2017 2016 (In thousands) Consolidated entities: Unproved oil and gas properties $ — $ 374 Proved oil and gas properties — 5,159 Total costs — 5,533 Less accumulated depreciation, depletion and amortization — (4,751 ) $ — $ 782

Summary of Quarterly Results 45

Summary of Quarterly Results of Operations (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2017
Quarterly Financial Information Disclosure [Abstract]
Summary of Quarterly Results of Operations	Summarized quarterly financial results for 2017 and 2016 follows: First Quarter (a) Second Quarter (a) Third Quarter (a) Fourth Quarter (a) (In thousands, except per share amounts) 2017 Total revenues $ 22,305 $ 28,015 $ 33,136 $ 30,866 Gross profit (loss) (28,332 ) 11,559 11,251 10,065 Operating income (loss) 36,235 6,965 12,381 (15,816 ) Equity in earnings of unconsolidated ventures 6,362 2,747 1,764 7,026 Income (loss) from continuing operations before taxes attributable to Forestar Group Inc. 40,998 8,120 13,223 (12,298 ) Income from discontinued operations, net of taxes 418 1,229 37,193 7,191 Net income (loss) attributable to Forestar Group Inc. 25,205 (2,579 ) 45,202 (17,574 ) Net income (loss) per share — basic Continuing operations $ 0.59 $ (0.09 ) $ 0.19 $ (0.59 ) Discontinued operations $ 0.01 $ 0.03 $ 0.88 $ 0.17 Net income (loss) per share — basic $ 0.60 $ (0.06 ) $ 1.07 $ (0.42 ) Net income (loss) per share — diluted Continuing operations $ 0.58 (0.09 ) 0.19 $ (0.58 ) Discontinued operations $ 0.01 0.03 0.87 $ 0.18 Net income (loss) per share — diluted $ 0.59 (0.06 ) 1.06 $ (0.40 ) 2016 Total revenues $ 37,618 $ 47,992 $ 47,207 $ 64,497 Gross profit (loss) 18,579 (24,953 ) 17,403 17,352 Operating income 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 _____________________ (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) 2017 Continuing operations $ 37,900 $ — $ — $ 9,272 Discontinued operations $ — $ — $ — $ — 2016 Continuing operations $ — $ 48,826 $ 7,627 $ 3,874 Discontinued operations $ — $ 612 $ — $ —

Summary of Significant Accoun46

Summary of Significant Accounting Policies - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2017USD ($)community_development_project	Dec. 31, 2016USD ($)community_development_projectmultifamily_site	Dec. 31, 2015USD ($)
Significant Accounting Policies [Line Items]
Non-cash impairment charges	$ 47,172,000	$ 60,939,000	$ 108,184,000
Capitalized exploratory well costs	0
Earnest money mortgages	40,408,000
Non-Oil And Gas Properties
Significant Accounting Policies [Line Items]
Depreciation expense of property and equipment	$ 441,000	889,000	$ 1,067,000
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%
Real Estate Impairment Charges
Significant Accounting Policies [Line Items]
Non-cash impairment charges	$ 3,420,000	$ 56,453,000
Community Development Project
Significant Accounting Policies [Line Items]
Number of properties impaired | community_development_project	1	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
Significant Accounting Policies [Line Items]
Purchase price of properties sold	85,700,000
Non-cash impairment charges	37,900,000
Disposal Group, Held-for-sale, Not Discontinued Operations
Significant Accounting Policies [Line Items]
Earnest money mortgages	$ 25,712,000

Summary of Significant Accoun47

Summary of Significant Accounting Policies - Estimated Useful Lives of Property Plant and Equipment (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Property, Plant and Equipment [Line Items]
Property plant and equipment, gross	$ 6,675	$ 7,657
Less: accumulated depreciation	(4,672)	(4,541)
Property Plant And Equipment, Net	2,003	3,116
Building and Building Improvements
Property, Plant and Equipment [Line Items]
Property plant and equipment, gross	2,162	2,700
Property and Equipment
Property, Plant and Equipment [Line Items]
Property plant and equipment, gross	$ 4,513	$ 4,957
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

Merger (Details)

Merger (Details) - USD ($) $ / shares in Units, $ in Thousands	Oct. 05, 2017	Dec. 31, 2017
Business Acquisition [Line Items]
Transaction costs		$ 43,819
D.R. Horton Merger Agreement
Business Acquisition [Line Items]
Share price	$ 17.75
Payments to acquire businesses, gross	$ 558,256
Forestar Group Inc.
Business Acquisition [Line Items]
Payments for merger related costs		7,170
Severance costs		7,683
Professional fees		4,617
All Other Shareholders | D.R. Horton Merger Agreement
Business Acquisition [Line Items]
Stock issued during period, shares, acquisitions	10,487,873
Stockholders' equity, ownership interest by shareholder	25.00%
D.R. Horton, Inc. | D.R. Horton Merger Agreement
Business Acquisition [Line Items]
Stock issued during period, shares, acquisitions	31,451,063
Stockholders' equity, ownership interest by shareholder	75.00%
Starwood Capital Group | Forestar Group Inc.
Business Acquisition [Line Items]
Payments for merger related costs		20,000
General and Administrative Expense
Business Acquisition [Line Items]
Transaction costs		41,475
General and Administrative Expense | D.R. Horton Merger Agreement
Business Acquisition [Line Items]
Acceleration of vesting and settlement of equity		4,349
Other operating expense
Business Acquisition [Line Items]
Transaction costs		$ 2,344

Real Estate - Real Estate (Deta

Real Estate - Real Estate (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Real Estate Properties [Line Items]
Carrying value	$ 130,380	$ 293,003
Entitled, developed and under development projects
Real Estate Properties [Line Items]
Carrying value	127,442	263,859
Other real estate costs (principally land in entitlement in 2016)
Real Estate Properties [Line Items]
Carrying value	$ 2,938	$ 29,144

Real Estate - Additional Inform

Real Estate - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2017USD ($)acommunity_development_project	Dec. 31, 2016USD ($)apropertyroomcommunity_development_projectmultifamily_site	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Real Estate Properties [Line Items]
Cost of asset in developed and under development projects	$ 27,915,000
Recovery of direct costs	(20,071,000)	$ (27,107,000)	$ (15,176,000)
Non-cash impairment charges	47,172,000	60,939,000	108,184,000
Gain of sale of assets	113,411,000	166,747,000	1,585,000
Payment of debt	10,049,000	315,229,000	58,220,000
Utility and Improvement District
Real Estate Properties [Line Items]
Cost of asset in developed and under development projects	9,775,000	45,157,000
Cibolo Canyons Project | San Antonio, Texas
Real Estate Properties [Line Items]
Cost of asset in developed and under development projects	14,127,000	14,749,000
Consolidated Properties
Real Estate Properties [Line Items]
Recovery of direct costs	19,606,000
Income Producing Properties | Land, Buildings and Improvements
Real Estate Properties [Line Items]
Depreciation expense, related to commercial and income producing properties	0	816,000	$ 6,810,000
Radisson Hotel & Suites, Austin | Austin, Texas
Real Estate Properties [Line Items]
Sales price		130,000,000
Net proceeds		128,764,000
Gain of sale of assets		$ 95,336,000
Number of hotel rooms | room		413
Payment of debt		$ 15,400,000
Eleven | Multi Family Property | Austin, Texas
Real Estate Properties [Line Items]
Sales price		60,150,000
Net proceeds		59,719,000
Gain of sale of assets		9,116,000
Payment of debt		$ 23,936,000
Number of units of multifamily project | property		257
Dillon | Charlotte, North Carolina
Real Estate Properties [Line Items]
Sales price		$ 25,979,000
Net proceeds		25,428,000
Gain of sale of assets		$ 1,223,000
Number of units of multifamily project | property		379
Music Row | Nashville, Tennessee
Real Estate Properties [Line Items]
Sales price		$ 15,025,000
Net proceeds		14,703,000
Gain of sale of assets		$ 3,968,000
Number of units of multifamily project | property		230
Downtown Edge | Austin, Texas
Real Estate Properties [Line Items]
Sales price		$ 5,000,000
Net proceeds		4,975,000
Gain of sale of assets		(3,870,000)
Real Estate Impairment Charges
Real Estate Properties [Line Items]
Non-cash impairment charges	$ 3,420,000	$ 56,453,000
Community Development Project
Real Estate Properties [Line Items]
Number of properties impaired | community_development_project	1	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 Texas
Real Estate Properties [Line Items]
Area of land (in acres) | a	19,000
Sales price	$ 46,197,000
Net proceeds	45,396,000
Gain of sale of assets	28,674,000
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Georgia and Alabama
Real Estate Properties [Line Items]
Area of land (in acres) | a		58,300
Sales price		$ 104,172,000
Net proceeds		103,238,000
Gain of sale of assets		$ 48,891,000
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
Bonds | Cibolo Canyons Project | San Antonio, Texas
Real Estate Properties [Line Items]
Payments received from special improvement district				$ 50,550,000
Debt instrument, face amount				48,900,000
Letters of credit outstanding, amount				$ 6,846,000
Surety bond for bond trustee	$ 5,312,000

Investment In Unconsolidated 51

Investment In Unconsolidated Ventures - Additional Information (Detail)		3 Months Ended								12 Months Ended
		Dec. 31, 2017USD ($)apropertyventure	Sep. 30, 2017USD ($)	Jun. 30, 2017USD ($)	Mar. 31, 2017USD ($)	Dec. 31, 2016USD ($)property	Sep. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2017USD ($)apropertyventure	Dec. 31, 2016USD ($)property	Dec. 31, 2015USD ($)
Schedule of Equity Method Investments [Line Items]
Number of ventures under ownership interest using equity method | venture		15								15
Investment in unconsolidated ventures										$ 4,548,000	$ 6,089,000	$ 26,349,000
Distributions										34,439,000	13,419,000	24,909,000
Gain of sale of assets										113,411,000	166,747,000	1,585,000
Earnings (Loss)										39,150,000	9,119,000	59,320,000
Equity in earnings of unconsolidated ventures		$ 7,026,000	$ 1,764,000	$ 2,747,000	$ 6,362,000	$ 2,251,000	$ 3,637,000	$ 188,000	$ 47,000	17,899,000	6,123,000	16,008,000
Non-cash impairment charges										47,172,000	60,939,000	108,184,000
Fees for services										$ 741,000	2,466,000	1,856,000
Variable Interest Entity, Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Number of ventures that are a VIE | venture										0
CREA FMF
Schedule of Equity Method Investments [Line Items]
Distributions										$ 11,956,000
Net proceeds										71,750,000
Gain of sale of assets										$ 18,986,000
CREA FMF | Multi Family Property
Schedule of Equity Method Investments [Line Items]
Number of units of multifamily project | property		320								320
FMF Peakview
Schedule of Equity Method Investments [Line Items]
Net proceeds											13,917,000
Gain of sale of assets											$ 10,363,000
FMF Peakview | Multi Family Property
Schedule of Equity Method Investments [Line Items]
Number of units of multifamily project | property						304					304
Forestar Group Inc. | CREA FMF
Schedule of Equity Method Investments [Line Items]
Net proceeds										$ 7,783,000
242, LLC
Schedule of Equity Method Investments [Line Items]
Earnings (Loss)	[1],[2]									8,021,000	$ 1,259,000	9,588,000
Equity in earnings of unconsolidated ventures	[1],[2]									4,096,000	668,000	4,919,000
242, LLC | Equity Method Investments
Schedule of Equity Method Investments [Line Items]
Distributions										4,348,000
Net proceeds										$ 9,719,000
Area of land (in acres) | a		46								46
Earnings (Loss)										$ 6,612,000
Equity method investment, ownership percentage		50.00%								50.00%
Equity in earnings of unconsolidated ventures										$ 3,306,000
CL Realty
Schedule of Equity Method Investments [Line Items]
Earnings (Loss)										(1,155,000)	237,000	424,000
Equity in earnings of unconsolidated ventures										(578,000)	$ 119,000	$ 212,000
CL Realty | Equity Method Investments
Schedule of Equity Method Investments [Line Items]
Distributions										1,200,000
Net proceeds										$ 2,400,000
Equity method investment, ownership percentage		50.00%								50.00%
Non-cash impairment charges										$ 3,756,000
[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 $548,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2017.
[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

Investment In Unconsolidated 52

Investment In Unconsolidated Ventures - Summarized Balance Sheet Information (Detail) - USD ($) $ in Thousands		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Venture Assets		$ 203,754	$ 279,674
Venture Borrowings	[1]	85,133	128,288
Venture Equity		105,520	141,802
Investment in unconsolidated ventures		64,579	77,611	$ 82,453
242, LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets	[2],[3]	19,525	26,503
Venture Borrowings	[2],[3]	0	1,107
Venture Equity	[2],[3]	19,357	23,136
Investment in unconsolidated ventures	[2],[3]	9,131	10,934
CL Ashton Woods
Schedule of Equity Method Investments [Line Items]
Venture Assets	[4]	124	2,653
Venture Borrowings	[4]	0	0
Venture Equity	[4]	104	2,198
Investment in unconsolidated ventures	[4]	83	1,107
CL Realty
Schedule of Equity Method Investments [Line Items]
Venture Assets		4,528	8,048
Venture Borrowings		0	0
Venture Equity		4,344	7,899
Investment in unconsolidated ventures		2,172	3,950
CREA FMF
Schedule of Equity Method Investments [Line Items]
Venture Assets	[2]	2,315	56,081
Venture Borrowings	[2]		37,446
Venture Equity	[2]	684	17,091
Investment in unconsolidated ventures	[2]	342	4,923
Elan 99 LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets		49,080	49,652
Venture Borrowings			36,238
Venture Equity		11,204	13,100
Investment in unconsolidated ventures		10,078	11,790
FMF Littleton
Schedule of Equity Method Investments [Line Items]
Venture Assets		66,849	70,282
Venture Borrowings		45,836	44,446
Venture Equity		20,289	23,798
Investment in unconsolidated ventures		5,144	6,128
FMF Peakview
Schedule of Equity Method Investments [Line Items]
Venture Assets		0	0
Venture Borrowings		0	0
Venture Equity		0	0
Investment in unconsolidated ventures		0	0
FOR/SR Forsyth LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets		11,598	10,672
Venture Borrowings		1,551	1,568
Venture Equity		10,041	8,990
Investment in unconsolidated ventures		9,037	8,091
HM Stonewall Estates
Schedule of Equity Method Investments [Line Items]
Venture Assets	[4]	0	852
Venture Borrowings	[4]	0	0
Venture Equity	[4]	0	852
Investment in unconsolidated ventures	[4]	0	477
LM Land Holdings
Schedule of Equity Method Investments [Line Items]
Venture Assets	[4]	19,479	25,538
Venture Borrowings	[4]	0	3,477
Venture Equity	[4]	12,074	20,945
Investment in unconsolidated ventures	[4]	5,935	9,685
MRECV DT Holdings LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets		3,043	4,155
Venture Borrowings		0	0
Venture Equity		3,043	4,144
Investment in unconsolidated ventures		2,594	3,729
MRECV Edelweiss LLC/MRECV Lender VIII LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets		8,127	3,484
Venture Borrowings		0	0
Venture Equity		8,127	3,484
Investment in unconsolidated ventures		7,189	3,358
MRECV Juniper Ridge LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets	[5]	3,936	4,156
Venture Borrowings	[5]	0	0
Venture Equity	[5]	3,936	4,156
Investment in unconsolidated ventures	[5]	3,331	3,741
MRECV Meadow Crossing II LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets		3,129	2,492
Venture Borrowings		0	0
Venture Equity		3,129	2,491
Investment in unconsolidated ventures		2,738	2,242
Miramonte Boulder Pass, LLC
Schedule of Equity Method Investments [Line Items]
Venture Assets	[5]	7,573	10,738
Venture Borrowings	[5]	1,398	4,006
Venture Equity	[5]	4,843	5,265
Investment in unconsolidated ventures	[5]	4,633	5,330
Temco
Schedule of Equity Method Investments [Line Items]
Venture Assets		4,448	4,368
Venture Borrowings		0	0
Venture Equity		4,345	4,253
Investment in unconsolidated ventures		2,172	2,126
Other Ventures
Schedule of Equity Method Investments [Line Items]
Venture Assets	[3]	0	0
Venture Borrowings	[3]	0	0
Venture Equity	[3]	0	0
Investment in unconsolidated ventures	[3]	0	$ 0
Nashville, Tennessee | Construction Loans | CREA FMF
Schedule of Equity Method Investments [Line Items]
Venture Borrowings	[2]	0
Houston, Texas | Construction Loans | Elan 99 LLC
Schedule of Equity Method Investments [Line Items]
Venture Borrowings		$ 36,348
[1]	Total includes current maturities of $84,098,000 at year-end 2017, of which $79,515,000 is non-recourse to us, and $89,756,000 at year-end 2016, of which $78,557,000 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 $548,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2017.
[3]	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
[4]	Includes unrecognized basis difference of $448,000 which is reflected as an increase of our investment in unconsolidated ventures at year-end 2017. This difference will be amortized as expense over the life of the investment and included in our share of earnings (loss) from the respective venture.
[5]	Please read Note 22 - Subsequent Event for additional information regarding this transaction.

Investment In Unconsolidated 53

Investment In Unconsolidated Ventures - Summarized Income Statement Information (Detail) - USD ($) $ in Thousands		3 Months Ended								12 Months Ended
		Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Revenues										$ 65,748	$ 46,130	$ 125,729
Earnings (Loss)										39,150	9,119	59,320
Our share of earnings (loss)		$ 7,026	$ 1,764	$ 2,747	$ 6,362	$ 2,251	$ 3,637	$ 188	$ 47	17,899	6,123	16,008
242, LLC
Schedule of Equity Method Investments [Line Items]
Revenues	[1],[2]									13,073	5,835	20,995
Earnings (Loss)	[1],[2]									8,021	1,259	9,588
Our share of earnings (loss)	[1],[2]									4,096	668	4,919
CL Ashton Woods
Schedule of Equity Method Investments [Line Items]
Revenues	[2]									3,179	2,870	9,820
Earnings (Loss)	[2]									1,456	914	3,881
Our share of earnings (loss)	[2]									1,816	1,332	5,000
CL Realty
Schedule of Equity Method Investments [Line Items]
Revenues										499	567	856
Earnings (Loss)										(1,155)	237	424
Our share of earnings (loss)										(578)	119	212
CREA FMF
Schedule of Equity Method Investments [Line Items]
Revenues	[1],[2]									5,440	4,955	1,227
Earnings (Loss)	[1],[2]									17,267	(1,420)	(1,696)
Our share of earnings (loss)	[1],[2]									7,563	1,103	(1,696)
Elan 99 LLC
Schedule of Equity Method Investments [Line Items]
Revenues										4,596	1,392	0
Earnings (Loss)										(1,896)	(2,739)	(49)
Our share of earnings (loss)										(1,712)	(2,465)	(44)
FMF Littleton
Schedule of Equity Method Investments [Line Items]
Revenues										6,366	3,116	120
Earnings (Loss)										192	(571)	(367)
Our share of earnings (loss)										48	(143)	(92)
FMF Peakview
Schedule of Equity Method Investments [Line Items]
Revenues										0	939	2,057
Earnings (Loss)										0	(248)	(1,116)
Our share of earnings (loss)										0	(50)	(223)
FOR/SR Forsyth LLC
Schedule of Equity Method Investments [Line Items]
Revenues										0	0	0
Earnings (Loss)										(148)	(65)	0
Our share of earnings (loss)										(134)	(58)	0
HM Stonewall Estates
Schedule of Equity Method Investments [Line Items]
Revenues	[3]									496	2,112	3,990
Earnings (Loss)	[3]									243	832	1,881
Our share of earnings (loss)	[3]									103	361	952
LM Land Holdings
Schedule of Equity Method Investments [Line Items]
Revenues	[3]									22,127	10,001	10,956
Earnings (Loss)	[3]									10,629	7,288	8,251
Our share of earnings (loss)	[3]									3,563	2,458	3,342
MRECV DT Holdings LLC
Schedule of Equity Method Investments [Line Items]
Revenues	[4]									1,196	495	0
Earnings (Loss)	[4]									1,173	477	167
Our share of earnings (loss)	[4]									911	429	0
MRECV Edelweiss LLC/MRECV Lender VIII LLC
Schedule of Equity Method Investments [Line Items]
Revenues										1,018	416	0
Earnings (Loss)										1,016	409	151
Our share of earnings (loss)										789	368	137
MRECV Juniper Ridge LLC
Schedule of Equity Method Investments [Line Items]
Revenues	[4]									1,445	379	0
Earnings (Loss)	[4]									1,445	380	106
Our share of earnings (loss)	[4]									1,089	342	0
MRECV Meadow Crossing II LLC
Schedule of Equity Method Investments [Line Items]
Revenues										638	267	0
Earnings (Loss)										638	220	0
Our share of earnings (loss)										496	198	0
Miramonte Boulder Pass, LLC
Schedule of Equity Method Investments [Line Items]
Revenues	[4]									5,483	4,923	0
Earnings (Loss)	[4]									177	(399)	(250)
Our share of earnings (loss)	[4]									(197)	(200)	(125)
PSW Communities
Schedule of Equity Method Investments [Line Items]
Revenues										0	0	29,986
Earnings (Loss)										0	0	2,688
Our share of earnings (loss)										0	0	1,169
Temco
Schedule of Equity Method Investments [Line Items]
Revenues										192	1,344	9,485
Earnings (Loss)										92	440	2,358
Our share of earnings (loss)										46	220	1,179
Other Ventures
Schedule of Equity Method Investments [Line Items]
Revenues										0	6,519	36,237
Earnings (Loss)										0	2,105	33,303
Our share of earnings (loss)										$ 0	$ 1,441	$ 1,278
[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 $548,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2017.
[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 $448,000 which is reflected as an increase of our investment in unconsolidated ventures at year-end 2017. This difference will be amortized as expense over the life of the investment and included in our share of earnings (loss) from the respective venture.
[4]	Please read Note 22 - Subsequent Event for additional information regarding this transaction.

Investment In Unconsolidated 54

Investment In Unconsolidated Ventures - Summarized Income Statement Information (Footnotes) (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Reduction in investment	$ 448
242, LLC
Schedule of Equity Method Investments [Line Items]
Reduction in investment	548
Equity Method Investments
Schedule of Equity Method Investments [Line Items]
Long-term debt, current maturities	84,098	$ 89,756
Equity Method Investments | Non-recourse Debt
Schedule of Equity Method Investments [Line Items]
Long-term debt, current maturities	$ 79,515	$ 78,557

Goodwill and Other Intangible55

Goodwill and Other Intangible Assets - Carrying Value of Goodwill and Other Intangible Assets (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	$ 0	$ 37,900
Identified intangibles, net	448	0
Total	$ 448	$ 37,900

Goodwill and Other Intangible56

Goodwill and Other Intangible Assets - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Goodwill acquired on acquisition	$ 0	$ 37,900,000
Non-cash impairment charges	47,172,000	60,939,000	$ 108,184,000
Unproved leasehold interests
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Goodwill acquired on acquisition	0	$ 37,900,000
Water Resources Company | Groundwater Leases
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Non-cash impairment charges	1,233,000
Texas | Water Resources Company
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Non-cash impairment charges	3,874,000
The Mineral Companies | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Goodwill, impairment loss	37,900,000
Non-cash impairment charges	$ 37,900,000

Held for Sale (Assets and Liabi

Held for Sale (Assets and Liabilities of Properties Held for Sale) (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Assets Held for Sale [Abstract]
Real estate	$ 130,380	$ 293,003
Property and equipment, net	2,003	3,116
Total assets	761,912	733,208
Liabilities Held for Sale [Abstract]
Accounts payable	2,382	4,804
Other liabilities	13,934	19,702
Total Liabiltiies	156,280	171,090
Disposal Group, Held-for-sale, Not Discontinued Operations
Assets Held for Sale [Abstract]
Real estate	180,247	19,931
Timber	0	1,682
Other intangible assets	0	1,681
Oil and gas properties and equipment, net	0	782
Property and equipment, net	1,360	6,301
Total assets	181,607	30,377
Liabilities Held for Sale [Abstract]
Accounts payable	1,017	0
Other liabilities	0	103
Total Liabiltiies	$ 1,017	$ 103

Discontinued Operations (Summar

Discontinued Operations (Summarized Results from Discontinued Operations) (Detail) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Discontinued Operations and Disposal Groups [Abstract]
Revenues									$ 15	$ 5,862	$ 43,845
Cost of oil and gas producing activities									(52)	(6,578)	(221,402)
Other operating expenses									226	(7,754)	(10,363)
Income (loss) from discontinued operations before income taxes									189	(8,470)	(187,920)
Gain (loss) on sale of assets before income taxes									(197)	(13,664)	(706)
Income tax benefit									46,039	5,269	2,496
Net income (loss) from discontinued operations available for diluted earnings per share	$ 7,191	$ 37,193	$ 1,229	$ 418	$ 563	$ (7,164)	$ (2,048)	$ (8,216)	$ 46,031	$ (16,865)	$ (186,130)

Discontinued Operations (Additi

Discontinued Operations (Additional Information) (Detail) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Sep. 30, 2017USD ($)	Sep. 30, 2017USD ($)	Dec. 31, 2017USD ($)awell	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)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)
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
Reimbursement of capital costs related to sale of in progress wells			3,269
Non-cash impairment charges			47,172	$ 60,939	$ 108,184
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]
Accrual for environmental loss contingencies, revision in estimates		$ 1,043
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
Productive oil wells, number of wells, gross | well					39
Productive oil wells, number of wells, net | well					7
Cost of Sales
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Non-cash impairment charges			$ 0	$ 612	$ 163,029
Discontinued Operations, Disposed of by Sale | Forestar Petroleum Company
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Sale of stock, consideration received on transaction	$ 100

Discontinued Operations (Assets

Discontinued Operations (Assets and Liabilities of Discontinued Operations) (Detail) (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Assets of Discontinued Operations:
Receivables, net of allowance for bad debt	$ 0	$ 6
Prepaid expenses	0	8
Assets	0	14	$ 104,967
Liabilities of Discontinued Operations:
Accounts payable	0	67
Other accrued expenses	0	5,228
Liabiltiies	$ 0	$ 5,295

Discontinued Operations (Signif

Discontinued Operations (Significant Operating and Investing Activities of Discontinued Operations) (Detail) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Net Cash Provided by (Used in) Operating Activities, Discontinuing Operations [Abstract]
Asset impairments	$ 47,172	$ 60,939	$ 108,184
Dry hole and unproved leasehold impairment costs	0	0	67,639
Loss (gain) on sale of assets	197	13,664	706
Depreciation, depletion and amortization	5,463	11,447	45,085
Cash provided by (used in) operating activities, discontinued operations	(2,803)	16,478	202,073
Net Cash Provided by (Used in) Investing Activities, Discontinuing Operations [Abstract] [Abstract]
Oil and gas properties and equipment	(2,400)	(579)	(49,717)
Cash provided by (used in) investing activities, discontinued operations	200	76,526	(31,917)
Discontinued Operations
Net Cash Provided by (Used in) Operating Activities, Discontinuing Operations [Abstract]
Asset impairments	0	612	105,337
Changes in accounts payable and other accrued liabilities	(3,000)	0	0
Dry hole and unproved leasehold impairment costs	0	0	67,639
Loss (gain) on sale of assets	197	13,664	706
Depreciation, depletion and amortization	0	2,202	28,391
Net Cash Provided by (Used in) Investing Activities, Discontinuing Operations [Abstract] [Abstract]
Oil and gas properties and equipment	0	(579)	(49,717)
Proceeds from sales of assets	$ 200	$ 77,105	$ 17,800

Receivables - Receivables (Deta

Receivables - Receivables (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	$ 6,333	$ 8,957
Allowance for bad debts	(26)	(26)
Receivables, net	6,307	8,931
Other receivables and accrued interest
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	2,557	1,505
Loans secured by real estate
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	$ 3,776	$ 7,452
Average interest rates	5.40%	4.94%

Receivables - Additional Inform

Receivables - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2017
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, 2017	Dec. 31, 2016
Line of Credit Facility [Line Items]
Debt	$ 108,429	$ 110,358
Senior Notes
Line of Credit Facility [Line Items]
Debt	0	5,200
Convertible Debt
Line of Credit Facility [Line Items]
Debt	108,139	104,673
Other Indebtedness
Line of Credit Facility [Line Items]
Debt	$ 290	$ 485

Debt - Debt (Detail)

Debt - Debt (Detail)	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 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%
Senior Secured Credit Facility | Revolving Credit Facility
Line of Credit Facility [Line Items]
Average interest rate	8.50%	8.50%
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)	Oct. 30, 2017USD ($)	Oct. 12, 2017USD ($)	Oct. 05, 2017USD ($)shares	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2013USD ($)
Line of Credit Facility [Line Items]
Debt instrument, collateral amount			$ 30,000,000
Debt instrument, additional collateral amount			10,000,000
Extinguishment of debt, amount				$ 10,049,000	$ 315,229,000	$ 58,220,000
Loss on extinguishment of debt, net				611,000	35,864,000	0
Accrued interest				1,489,000	1,585,000
Converted instrument, amount			579.77062
Deferred finance costs, net				1,058,000	1,633,000
Amortization of deferred financing fees				979,000	3,598,000	$ 4,002,000
Debt maturities, 2018				290,000
Debt maturities, 2019				0
Debt maturities, 2020				108,139,000
Debt maturities, 2021				0
Debt maturities, 2022				0
Debt maturities, thereafter				0
Senior Notes
Line of Credit Facility [Line Items]
Interest rate percentage	8.50%
Loss on extinguishment of debt, net					35,681,000
Write off of deferred debt issuance cost					5,416,000
Tender offer advisory services					$ 1,301,000
Senior Notes | Eight Point Five Zero Senior Secured Notes
Line of Credit Facility [Line Items]
Repurchased amount	$ 5,315,000
Extinguishment of debt, amount	5,928,000
Loss on extinguishment of debt, net	$ (524,000)
Convertible Debt
Line of Credit Facility [Line Items]
Repurchased amount		$ 1,077,000
Interest rate percentage					3.75%		3.75%
Extinguishment of debt, amount					$ 4,452,000
Principal amount of debt			$ 120,000,000				$ 125,000,000
Extinguishment of debt, amount					5,000,000
Loss on extinguishment of debt, net		$ (87,000)			183,000
Maturity date							Mar. 1, 2020
Initial conversion rate							40.8351
Principal amount of initial conversion rate							$ 1,000
Unamortized debt discount				$ 9,726,000
Effective interest rate				8.00%
Carrying amount of equity component				$ 16,847,000	$ 211,000
Percentage of principal amount redeemed					93.25%
Repayments of long-term debt, including payments for repurchase of equity					$ 4,663,000
Gain (loss) on early extinguishment of debt					110,000
Senior Secured Credit Facility | Letter of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity under term loan facility				50,000,000
Sublimit for letters of credit under line of credit facility				50,000,000
Tender Offer | Senior Notes
Line of Credit Facility [Line Items]
Extinguishment of debt, amount					245,604,000
Extinguishment of debt, amount					215,495,000
Unamortized premium					29,091,000
Accrued interest					1,018,000
Open Market Transaction | Senior Notes
Line of Credit Facility [Line Items]
Principal amount of debt					$ 9,750,000
Common Stock
Line of Credit Facility [Line Items]
Converted instrument, shares issued | shares			8.17192
Keybank National Association | Standby Letters of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity under term loan facility			$ 30,000,000
Current borrowing capacity				$ 14,072,000

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, 2017	Dec. 31, 2016
Reported Value Measurement
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fixed rate debt	$ (109,197)	$ (111,506)
Estimate of Fair Value Measurement
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fixed rate debt	$ (109,114)	$ (109,789)

Fair Value - Additional Informa

Fair Value - Additional Information (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2017USD ($)community_development_project	Dec. 31, 2016USD ($)community_development_projectmultifamily_site	Dec. 31, 2015USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset impairments	$ 47,172	$ 60,939	$ 108,184
Real Estate Impairment Charges
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset impairments	$ 3,420	$ 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	1	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
The Mineral Companies | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset impairments	$ 37,900
Water Resources Company | Georgia and Texas
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset impairments	5,852
Water Resources Company | Georgia
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset impairments	420
Equity Method Investments | Cost of Real Estate Sales
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset impairments	$ 3,000

Fair Value - Carrying Value of

Fair Value - Carrying Value of Assets (Detail) - Non-recurring - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Real Estate
Non-Financial Assets and Liabilities:
Assets, fair value disclosure, nonrecurring	$ 180,247	$ 0
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	180,247	0
Real Estate | Level 3
Non-Financial Assets and Liabilities:
Assets, fair value disclosure, nonrecurring	0	0
Central Texas water assets
Non-Financial Assets and Liabilities:
Assets, fair value disclosure, nonrecurring	1,987	0
Central Texas water assets | Level 1
Non-Financial Assets and Liabilities:
Assets, fair value disclosure, nonrecurring	0	0
Central Texas water assets | Level 2
Non-Financial Assets and Liabilities:
Assets, fair value disclosure, nonrecurring	0	0
Central Texas water assets | Level 3
Non-Financial Assets and Liabilities:
Assets, fair value disclosure, nonrecurring	$ 1,987	$ 0

Capital Stock - (Detail)

Capital Stock - (Detail) - USD ($) $ in Thousands	Dec. 15, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2013	Nov. 27, 2013
Class of Stock [Line Items]
Settlement of tangible equity units, Shares	7,857,000
Number of shares repurchased			283,976
Value of share repurchased		$ 0	$ 3,537
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
6% Tangible Equity Units
Class of Stock [Line Items]
Interest rate percentage				6.00%	6.00%

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, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Continuing operations
Consolidated net income (loss)									$ 6,301	$ 77,044	$ (26,241)
Less: Net (income) attributable to noncontrolling interest									(2,078)	(1,531)	(676)
Earnings (loss) available for diluted earnings per share									4,223	75,513	(26,917)
Less: Undistributed net income from continuing operations allocated to participating securities									0	(13,493)	0
Earnings (loss) from continuing operations available to common shareholders for basic earnings per share									4,223	62,020	(26,917)
Discontinued operations
Net income (loss) from discontinued operations available for diluted earnings per share	$ 7,191	$ 37,193	$ 1,229	$ 418	$ 563	$ (7,164)	$ (2,048)	$ (8,216)	46,031	(16,865)	(186,130)
Less: Undistributed net income from discontinued operations allocated to participating securities									0	3,014	0
Earnings (loss) from discontinued operations available to common shareholders for basic earnings per share									$ 46,031	$ (13,851)	$ (186,130)
Weighted Average Number of Shares Outstanding Reconciliation [Abstract]
Weighted average common shares outstanding - basic									42,143	34,546	34,266
Weighted average common shares upon conversion of participating securities									0	7,515	0
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements									238	273	0
Weighted average common shares outstanding - diluted									42,381	42,334	34,266
Anti-dilutive awards excluded from diluted weighted average shares outstanding									1,093	2,102	10,864

Net Income (Loss) per Share - A

Net Income (Loss) per Share - Additional Information (Details) - $ / shares	Dec. 15, 2016	Dec. 31, 2017	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		$ 51.42
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, 2017	Dec. 31, 2016	Dec. 31, 2015
Current tax provision:
U.S. Federal	$ (44,177)	$ (15,089)	$ 6,740
State and other	(3,378)	(1,520)	(418)
Total	(47,555)	(16,609)	6,322
Deferred tax provision:
U.S. Federal	1,678	1,382	(38,262)
State and other	57	(75)	(3,191)
Total	1,735	1,307	(41,453)
Income tax expense	$ (45,820)	$ (15,302)	$ (35,131)

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Federal Statutory Rate to Effective Income Tax Rate on Continuing Operations (Detail)	Dec. 22, 2017	Dec. 21, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Federal statutory rate (benefit)	21.00%	35.00%	35.00%	35.00%	35.00%
State, net of federal benefit			3.00%	0.00%	10.00%
Valuation allowance			(42.00%)	(19.00%)	348.00%
Tax rate change due to new tax act			40.00%	0.00%	0.00%
Noncontrolling interests			(1.00%)	(1.00%)	(3.00%)
Installment sale ace adjustment			0.00%	2.00%	0.00%
Stock based compensation			11.00%	0.00%	5.00%
Goodwill			25.00%	0.00%	0.00%
Merger costs			18.00%	0.00%	0.00%
Oil and gas percentage depletion			0.00%	0.00%	(1.00%)
Other			(1.00%)	0.00%	1.00%
Effective tax rate			88.00%	17.00%	395.00%

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($)	Dec. 22, 2017	Dec. 21, 2017	Oct. 05, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating Loss Carryforwards [Line Items]
Federal statutory rate (benefit), percent	21.00%	35.00%		35.00%	35.00%	35.00%
AMT credits				$ 1,690,000	$ 5,900,000
Valuation allowance				39,578,000	73,405,000
Unrecognized tax benefit				1,050,000	2,499,000	$ 0	$ 0
Recognized interest accrued related to unrecognized tax benefits				0	0	$ 0
Accrued interest				0	$ 0
Domestic Tax Authority
Operating Loss Carryforwards [Line Items]
Operating loss carry forwards				$ 9,200,000
Expiration date of operating loss carry forwards				Dec. 31, 2037
State and Local Jurisdiction
Operating Loss Carryforwards [Line Items]
Operating loss carry forwards				$ 69,200,000
Operating loss carry forwards attributable to states not currently doing business with				$ 45,600,000
Minimum | State and Local Jurisdiction
Operating Loss Carryforwards [Line Items]
Expiration date of operating loss carry forwards				Dec. 31, 2020
Maximum | State and Local Jurisdiction
Operating Loss Carryforwards [Line Items]
Expiration date of operating loss carry forwards				Dec. 31, 2037
D.R. Horton Merger Agreement | D.R. Horton, Inc.
Operating Loss Carryforwards [Line Items]
Stockholders' equity, ownership interest by shareholder			75.00%

Income Taxes - Significant Comp

Income Taxes - Significant Components of Deferred Taxes (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Deferred Tax Assets:
Real estate	$ 37,513	$ 50,759
Employee benefits	1,510	13,185
Net operating loss carryforwards	2,305	2,804
Oil and gas properties	0	1,672
AMT credits	1,690	5,900
Income producing properties	794	2,055
Oil and gas percentage depletion carryforwards	0	3,478
Accruals not deductible until paid	196	552
Gross deferred tax assets	44,008	80,405
Valuation allowance	(39,578)	(73,405)
Deferred tax asset net of valuation allowance	4,430	7,000
Deferred Tax Liabilities:
Undeveloped land	0	(1,359)
Convertible debt	(2,402)	(5,035)
Timber	0	(283)
Gross deferred tax liabilities	2,402	6,677
Deferred tax asset, net	$ 2,028	$ 323

Income Taxes - Unrecognized Tax

Income Taxes - Unrecognized Tax Benefits (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at beginning of year	$ 2,499	$ 0	$ 0
Increases (decreases) for tax positions of current year	0	2,499	0
Decreases for dispositions and other	(1,449)	0	0
Balance at end of year	$ 1,050	$ 2,499	$ 0

Litigation and Environmental 78

Litigation and Environmental Contingencies - Environmental (Detail)	12 Months Ended
	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)a
Antioch, California
Environmental Exit Cost [Line Items]
Area of land not sold (in acres)		25
Area of land (in acres)		289
Area sold without certificate of completion under voluntary remediation program		80
Wyoming
Environmental Exit Cost [Line Items]
Environmental liability | $	$ 1,155,000
Paper Manufacturing Sites
Environmental Exit Cost [Line Items]
Insurance policy | $		$ 20,000,000
Length of insurance policy (in years)		10 years

Commitments and Other Conting79

Commitments and Other Contingencies (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operating Leased Assets [Line Items]
Operating lease future payments, 2018	$ 1,313
Operating lease future payments, 2019	208
Operating lease future payments, 2020	180
Operating lease future payments, 2021	61
Operating lease future payments, 2022	0
Operating lease future payments, thereafter	0
Debt	108,429	$ 110,358
Office Facilities And Other Equipment
Operating Leased Assets [Line Items]
Lease expense	2,101	$ 1,923	$ 3,872
Other Office Locations
Operating Leased Assets [Line Items]
Remaining contractual obligation	1,762
Surety Bond
Operating Leased Assets [Line Items]
Principal amount of debt	40,000
Debt	$ 14,708

Segment Information - Additiona

Segment Information - Additional Information (Detail) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017USD ($)	Sep. 30, 2017USD ($)	Jun. 30, 2017USD ($)	Mar. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2017USD ($)homebuildersegment	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Segment Reporting Information [Line Items]
Number of business segments | segment									3
Number of homebuilders | homebuilder									1
Revenues	$ 30,866	$ 33,136	$ 28,015	$ 22,305	$ 64,497	$ 47,207	$ 47,992	$ 37,618	$ 114,322	$ 197,314	$ 218,576
Concentration risk, percentage (more than)									10.00%
Real Estate
Segment Reporting Information [Line Items]
Revenues									$ 20,923

Segment Information - Segment R

Segment Information - Segment Revenues and Earnings (Detail) - USD ($) $ in Thousands		3 Months Ended								12 Months Ended
		Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Revenues		$ 30,866	$ 33,136	$ 28,015	$ 22,305	$ 64,497	$ 47,207	$ 47,992	$ 37,618	$ 114,322	$ 197,314	$ 218,576
Depreciation, depletion and amortization										5,463	11,447	45,085
Equity in earnings of unconsolidated ventures		7,026	$ 1,764	$ 2,747	$ 6,362	2,251	$ 3,637	$ 188	$ 47	17,899	6,123	16,008
Income (loss) before taxes from continuing operations										50,043	90,815	8,214
Total assets		761,912				733,208				761,912	733,208
Investment in unconsolidated ventures		64,579				77,611				64,579	77,611	82,453
Capital expenditures										2,452	6,138	14,690
Assets of discontinued operations		0				14				0	14	104,967
Real Estate
Segment Reporting Information [Line Items]
Revenues										20,923
Operating Segments | Real Estate
Segment Reporting Information [Line Items]
Revenues										112,746	190,273	202,830
Depreciation, depletion and amortization										131	976	7,605
Equity in earnings of unconsolidated ventures										16,500	5,778	15,582
Income (loss) before taxes from continuing operations										47,281	121,420	67,678
Investment in unconsolidated ventures		64,579				77,611				64,579	77,611	82,453
Capital expenditures										52	5,783	13,644
Operating Segments | Oil and Gas
Segment Reporting Information [Line Items]
Revenues										1,502	5,076	9,094
Depreciation, depletion and amortization										28	145	383
Equity in earnings of unconsolidated ventures										1,395	173	275
Income (loss) before taxes from continuing operations										45,552	3,327	4,230
Investment in unconsolidated ventures		0				0				0	0	0
Capital expenditures										2,400	0	59
Operating Segments | Other Natural Resources
Segment Reporting Information [Line Items]
Revenues										74	1,965	6,652
Depreciation, depletion and amortization										25	352	540
Equity in earnings of unconsolidated ventures										4	172	151
Income (loss) before taxes from continuing operations										(6,393)	(4,625)	(608)
Investment in unconsolidated ventures		0				0				0	0	0
Capital expenditures										0	299	745
Items Not Allocated To Segments
Segment Reporting Information [Line Items]
Revenues										0	0	0
Depreciation, depletion and amortization										5,279	7,772	8,166
Equity in earnings of unconsolidated ventures										0	0	0
Income (loss) before taxes from continuing operations	[1]									(36,397)	(29,307)	(63,086)
Investment in unconsolidated ventures		0				0				0	0	0
Capital expenditures										0	56	242
Continuing Operations
Segment Reporting Information [Line Items]
Depreciation, depletion and amortization										5,463	9,245	$ 16,694
Total assets	[2]	761,912				733,194				761,912	733,194
Continuing Operations | Operating Segments | Real Estate
Segment Reporting Information [Line Items]
Total assets	[2]	386,222				403,062				386,222	403,062
Continuing Operations | Operating Segments | Oil and Gas
Segment Reporting Information [Line Items]
Total assets	[2]	0				38,907				0	38,907
Continuing Operations | Operating Segments | Other Natural Resources
Segment Reporting Information [Line Items]
Total assets	[2]	3,346				11,531				3,346	11,531
Continuing Operations | Items Not Allocated To Segments
Segment Reporting Information [Line Items]
Total assets	[2]	$ 372,344				$ 279,694				$ 372,344	$ 279,694
[1]	Items not allocated to segments consist of: For the Year 2017 2016 2015 (In thousands)General and administrative expense$(50,354) $(18,274) $(24,802)Share-based and long-term incentive compensation expense(7,201) (4,425) (4,474)Gain on sale of assets28,674 48,891 —Interest expense(8,532) (19,985) (34,066)Loss on extinguishment of debt, net(611) (35,864) —Other corporate non-operating income1,627 350 256 $(36,397) $(29,307) $(63,086)
[2]	Total assets excludes assets of discontinued operations of $14,000 and $104,967,000 in 2016 and 2015.

Segment Information - Items Not

Segment Information - Items Not Allocated to Segments (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
General and administrative expense		$ (56,531)	$ (21,597)	$ (27,253)
Gain of sale of assets		113,411	166,747	1,585
Interest expense		(8,532)	(19,985)	(34,066)
Loss on extinguishment of debt, net		(611)	(35,864)	0
Other corporate non-operating income		3,600	1,718	3,006
Income (loss) before taxes from continuing operations		50,043	90,815	8,214
Items Not Allocated To Segments
Segment Reporting Information [Line Items]
General and administrative expense		(50,354)	(18,274)	(24,802)
Share-based and long-term incentive compensation expense		(7,201)	(4,425)	(4,474)
Gain of sale of assets		28,674	48,891	0
Interest expense		(8,532)	(19,985)	(34,066)
Loss on extinguishment of debt, net		(611)	(35,864)	0
Other corporate non-operating income		1,627	350	256
Income (loss) before taxes from continuing operations	[1]	$ (36,397)	$ (29,307)	$ (63,086)
[1]	Items not allocated to segments consist of: For the Year 2017 2016 2015 (In thousands)General and administrative expense$(50,354) $(18,274) $(24,802)Share-based and long-term incentive compensation expense(7,201) (4,425) (4,474)Gain on sale of assets28,674 48,891 —Interest expense(8,532) (19,985) (34,066)Loss on extinguishment of debt, net(611) (35,864) —Other corporate non-operating income1,627 350 256 $(36,397) $(29,307) $(63,086)

Share Based Compensation - Comp

Share Based Compensation - Components of Share-Based Compensation Expense (Income) (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	$ 6,643	$ 4,037	$ 4,246
Deferred cash	558	388	228
Share-based and long-term incentive compensation	7,201	4,425	4,474
Cash Settled Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	634	717	(3,127)
Equity-settled awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	5,001	2,444	5,026
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	0	22	(8)
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	$ 1,008	$ 854	$ 2,355

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, 2017	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based and long-term incentive compensation	$ 7,201	$ 4,425	$ 4,474
General and Administrative Expense
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based and long-term incentive compensation	6,177	3,323	2,451
Other Operating Expenses
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based and long-term incentive compensation	$ 1,024	$ 1,102	$ 2,023

Share Based Compensation - Addi

Share Based Compensation - Additional Information (Detail)	3 Months Ended	12 Months Ended
	Mar. 31, 2016directorshares	Dec. 31, 2017USD ($)$ / sharesshares	Dec. 31, 2016USD ($)$ / sharesshares	Dec. 31, 2015USD ($)$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation		$ 6,643,000	$ 4,037,000	$ 4,246,000
Fair value of awards granted to retirement eligible employees and expensed at date of grant		9,000	$ 600,000	517,000
Unrecognized share-based compensation expense related to non-vested equity-settled awards, restricted stock and stock options		$ 1,424,000
Weighted average period over which amount will be recognized		4 years
Shares issued out of treasury stock | shares		322,586	300,491
Vesting of restricted stock awards and exercises of stock options, shares withheld | shares		75,870	25,082
Payroll taxes on restricted stock and stock options		$ 981,000	$ 222,000	762,000
Board of Director Fees
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation		449,000	725,000	1,203,000
Cash Settled Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation		$ 634,000	717,000	(3,127,000)
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		5 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		$ 1,581,000	154,000	$ 206,000
Fair value of vested cash-settled awards		$ 0	1,758,000
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
Fair value of awards settled in cash		$ 2,178,000	$ 1,195,000	$ 2,469,000
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		5 years
Granted, equivalent units | shares		198,000	313,000
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
Weighted average estimated fair value of options at grant date | $ / shares				$ 15.11
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		$ 5,001,000	$ 2,444,000	$ 5,026,000
Granted, weighted average grant date fair value | $ / shares		$ 14.55
Fair value of vested cash-settled awards		$ 14,894,000	$ 2,884,000	$ 4,451,000
Granted, equivalent units | shares		198,000
Weighted average estimated fair value of options at grant date | $ / shares		$ 14.55	$ 9.04	$ 12.99
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation		$ 0	$ 22,000	$ (8,000)
Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation		$ 1,008,000	854,000	2,355,000
Period over or after performance stock unit vest		4 years
Expiration period		10 years
Intrinsic value of options exercised		$ 2,603,000	$ 61,000	$ 0
Options outstanding | shares		0	1,836,000
Weighted average exercise price | $ / shares		$ 0
Weighted average remaining contractual term		0 years	5 years
Long Term Incentive Compensation
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Deferred cash compensation		$ 1,180,000	$ 620,000
Requisite service period (in years)		3 years	2 years
Director
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of new directors | director	2
Granted (in shares) | shares	20,000
Director | 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
Share-based Compensation Award, Tranche Two [Member] | Director
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting, number | shares		6,500
Tranche One | 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
D.R. Horton Merger Agreement | General and Administrative Expense
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Acceleration of vesting and settlement of equity		$ 4,349,000

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, 2017	Dec. 31, 2016	Dec. 31, 2015
Market-leveraged stock units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected stock price volatility			32.90%
Risk-free interest rate			1.00%
Expected dividend yield			0.00%
Weighted average estimated fair value of options at grant date			$ 15.11
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

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, 2017	Dec. 31, 2015
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	42
Granted, equivalent units	0
Vested, equivalent units	(30)
Forfeited, equivalent units	(12)
Balance at end of period	0
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	$ 14.98
Granted, weighted average grant date fair value	0	$ 13.26
Vested, Weighted Average Grant Date Fair Value	15.66
Forfeited, weighted average grant date	13.15
Non-vested at end of period, weighted average grant date fair value	$ 0

Share Based Compensation - Su88

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, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Balance at beginning of year	374
Granted, rights outstanding	0
Exercised, rights outstanding	(234)
Forfeited, rights outstanding	(140)
Balance at end of period	0	374
Exercisable at end of period, rights outstanding	0
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	10.14
Forfeited, weighted average grant date	17.69
Non-vested at end of period, weighted average grant date fair value	0	$ 12.97
Exercisable at end of period, weighted average exercise price	$ 0
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	0 years	3 years
Weighted average remaining contractual term	0 years
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value [Abstract]
Aggregate intrinsic value	$ 0	$ 773
Exercisable at end of period, aggregate intrinsic value	$ 0

Share Based Compensation - Equi

Share Based Compensation - Equity-Settled Awards (Detail) - Equity-settled awards shares in Thousands	12 Months Ended
	Dec. 31, 2017$ / 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	555
Granted, equivalent units | shares	198
Vested, equivalent units | shares	(653)
Forfeited, equivalent units | shares	(14)
Balance at end of period | shares	86
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	$ 14.70
Granted, weighted average grant date fair value | $ / shares	14.55
Vested, Weighted Average Grant Date Fair Value | $ / shares	14.28
Forfeited, weighted average grant date | $ / shares	14.59
Non-vested at end of period, weighted average grant date fair value | $ / shares	$ 17.54

Share Based Compensation - Su90

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, 2017	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Balance at beginning of year, options outstanding	1,836
Granted, options outstanding	0
Exercised, options outstanding	(768)
Forfeited, options outstanding	(1,068)
Balance at end of period, options outstanding	0	1,836
Exercisable at end of period, options outstanding	0
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	$ 19.39
Granted, weighted average exercise price	0
Exercised, weighted average exercise price	14.07
Forfeited, weighted average exercise price	23.21
Balance at end of period, weighted average exercise price	0	$ 19.39
Exercisable at end of period, weighted average exercise price	$ 0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Aggregate Intrinsic Value [Abstract]
Weighted average remaining contractual term	0 years	5 years
Exercisable at end of period, weighted average remaining contractual term	0 years
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Aggregate intrinsic value	$ 0	$ 449
Exercisable at end of period, aggregate intrinsic value	$ 0

Retirement Plans - Additional I

Retirement Plans - Additional Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Retirement Benefits [Abstract]
Expense of defined contribution retirement plans	$ 660	$ 978	$ 1,060
Unfunded liability for supplemental plan	$ 374	$ 334

Supplemental Oil and Gas Disc92

Supplemental Oil and Gas Disclosures (Unaudited) - Additional Information (Detail) bbl in Thousands, Mcf in Thousands		12 Months Ended
		Dec. 31, 2017wellbblMcf	Dec. 31, 2016well$ / MMBTU$ / BoebblMcf	Dec. 31, 2015BoebblMcf	Dec. 31, 2015BoewellbblMcf	Dec. 31, 2015Boe$ / MMBTUbblMcf	Dec. 31, 2015BoebblMcf	Dec. 31, 2015BoebblMcf	Dec. 31, 2015Boe$ / BoebblMcf	Dec. 31, 2014BoebblMcf
Supplemental Oil And Gas Reserve Information [Line Items]
New well addition | well		0	0		36
Wells which company has royalty interest in		0	473	534
Wells which company has working interest in | well		0	32		400
Crude Oil and NGL
Supplemental Oil And Gas Reserve Information [Line Items]
Average spot price | $ / Boe			42.75						50.28
Natural Gas in Mmbtu
Supplemental Oil And Gas Reserve Information [Line Items]
Average spot price | $ / MMBTU			2.48			2.59
Oil
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, net	[1]	0	446	5,179	5,179	5,179	5,179	5,179	5,179
Oil | Consolidated Entities
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, net	[1]	0	446	5,179	5,179	5,179	5,179	5,179	5,179	7,672
Proved developed and undeveloped reserves, sales of minerals in place	[1]	446	4,460				704
Proved developed and undeveloped reserves, revisions of previous estimates	[1]	0	11				855
Oil Less Natural Gas Liquids
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, net	[1]		446
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
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, net | Mcf		0	5,035	9,220	9,220	9,220	9,220	9,220	9,220
Natural Gas | Consolidated Entities
Supplemental Oil And Gas Reserve Information [Line Items]
Proved developed and undeveloped reserves, net | Mcf		0	3,836	7,957	7,957	7,957	7,957	7,957	7,957	12,649
Proved developed and undeveloped reserves, sales of minerals in place | Mcf		3,836	3,756					1,223
Proved developed and undeveloped reserves, revisions of previous estimates		0	(631)				1,995	1,675
BOE
Supplemental Oil And Gas Reserve Information [Line Items]
Proved undeveloped reserve (Energy) | Boe				0	0	0	0	0	0	2,703,000
[1]	Includes natural gas liquids (NGLs).

Supplemental Oil and Gas Disc93

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, 2017bblMcf	Dec. 31, 2016bblMcf	Dec. 31, 2015bblMcf	Dec. 31, 2015bblMcf
Oil
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning Balance	[1]	446	5,179
Proved developed reserves	[1]	0	446	5,179	5,179
Proved undeveloped reserves	[1]	0	0	0	0
Ending Balance	[1]	0	446	5,179
Natural Gas
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning Balance | Mcf		5,035	9,220
Proved developed reserves | Mcf		0	5,035	9,220	9,220
Proved undeveloped reserves | Mcf		0	0	0	0
Ending Balance | Mcf		0	5,035		9,220
Consolidated Entities | Oil
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning Balance	[1]	446	5,179	7,672
Revisions of previous estimates	[1]	0	(11)	(855)
Extensions and discoveries	[1]	0	29	224
Acquisitions	[1]	0	0	0
Sales	[1]	(446)	(4,460)	(704)
Production	[1]	0	(291)	(1,158)
Ending Balance	[1]	0	446	5,179
Consolidated Entities | Natural Gas
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning Balance | Mcf		3,836	7,957		12,649
Revisions of previous estimates		0	631	(1,995)	(1,675)
Extensions and discoveries | Mcf		0	0		173
Acquisitions | Mcf		0	0		0
Sales | Mcf		(3,836)	(3,756)		(1,223)
Production | Mcf		0	(996)		(1,967)
Ending Balance | Mcf		0	3,836		7,957
Equity Method Investee | Oil
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning Balance	[1]	0	0	0
Revisions of previous estimates	[1]		0	0
Sales	[1]	0
Production	[1]		0	0
Ending Balance	[1]	0	0	0
Equity Method Investee | Natural Gas
Proved Developed and Undeveloped Reserves [Roll Forward]
Beginning Balance | Mcf		1,199	1,263		1,751
Revisions of previous estimates | Mcf			(79)		320
Sales | Mcf		(1,199)
Production | Mcf			(143)		(168)
Ending Balance | Mcf		0	1,199		1,263
[1]	Includes natural gas liquids (NGLs).

Supplemental Oil and Gas Disc94

Supplemental Oil and Gas Disclosures (Unaudited) - Capitalized Cost Related to Oil and Natural Gas Producing Activities (Detail) - Consolidated Entities - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Capitalized Costs Relating To Oil And Gas Producing Activities [Line Items]
Unproved oil and gas properties	$ 0	$ 374
Proved oil and gas properties	0	5,159
Total costs	0	5,533
Less accumulated depreciation, depletion and amortization	0	(4,751)
Net capitalized costs	$ 0	$ 782

Supplemental Oil and Gas Disc95

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, 2017	Dec. 31, 2016	Dec. 31, 2015
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	$ 0
Costs incurred, acquisition of unproved oil and gas properties	0	15	4,832
Exploration costs	0	21	17,922
Development costs	0	537	27,609
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities	$ 0	$ 573	$ 50,363

Supplemental Oil and Gas Disc96

Supplemental Oil and Gas Disclosures (Unaudited) Supplemental Oil and Gas Disclosures (Unaudited) - Schedule of Gross and Net Oil and Gas Wells Drilled (Details) - well	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2015
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Wells drilled, gross	38
Wells drilled, net	6.3
Wells operated by company		3
Percentage of wells operated by company		8.00%
Oil
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Exploratory wells drilled, gross productive		2
Development wells drilled, gross productive		34
Exploratory wells drilled, net productive		0.7
Development wells drilled, net productive		4.3
Dry
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Exploratory wells drilled, gross nonproductive		1
Development wells drilled, net nonnproductive		1
Exploratory wells drilled, net nonproductive		0.8
Development wells drilled, net unproductive		0.5

Supplemental Oil and Gas Disc97

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, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Standardized measure of discounted future net cash flows	$ 0	$ 10,985	$ 67,498	$ 165,616
Consolidated Entities
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future cash inflows	0	24,304	216,588
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Production Costs	0	(2,988)	(93,623)
Future income tax expenses	0	(3,926)	(22,218)
Future net cash flows	0	17,390	100,747
10% annual discount for estimated timing of cash flows	0	(7,077)	(33,951)
Standardized measure of discounted future net cash flows	0	10,313	66,796	163,841
Equity Method Investee
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future cash inflows	0	2,010	2,283
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Production Costs	0	(216)	(245)
Future income tax expenses	0	(537)	(774)
Future net cash flows	0	1,257	1,264
10% annual discount for estimated timing of cash flows	0	(585)	(562)
Standardized measure of discounted future net cash flows	$ 0	$ 672	$ 702	$ 1,775

Supplemental Oil and Gas Disc98

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, 2017	Dec. 31, 2016	Dec. 31, 2015
Schedule Of Changes In Standardized Measure Of Discounted Future Net Cash Flows [Line Items]
Beginning Balance	$ 10,985	$ 67,498	$ 165,616
Changes resulting from:
Net change in sales prices and production costs	0	(3,645)	(137,648)
Net change in future development costs	0	0	92
Sales of oil and gas, net of production costs	0	(5,871)	(32,160)
Net change due to extensions and discoveries	0	410	11,747
Net change due to acquisition of reserves	0	0	0
Net change due to divestitures of reserves	(10,985)	(63,535)	(15,855)
Net change due to revisions of quantity estimates	0	1,367	(15,431)
Previously estimated development costs incurred	0	0	15,096
Accretion of discount	0	3,105	22,886
Net change in timing and other	0	(208)	3,808
Net change in income taxes	0	11,864	49,347
Aggregate change for the year	(10,985)	(56,513)	(98,118)
Ending Balance	0	10,985	67,498
Consolidated Entities
Schedule Of Changes In Standardized Measure Of Discounted Future Net Cash Flows [Line Items]
Beginning Balance	10,313	66,796	163,841
Changes resulting from:
Net change in sales prices and production costs	0	(3,585)	(136,536)
Net change in future development costs	0	0	92
Sales of oil and gas, net of production costs	0	(5,663)	(31,732)
Net change due to extensions and discoveries	0	410	11,747
Net change due to acquisition of reserves	0	0	0
Net change due to divestitures of reserves	(10,313)	(63,535)	(15,855)
Net change due to revisions of quantity estimates	0	1,304	(15,164)
Previously estimated development costs incurred	0	0	15,096
Accretion of discount	0	2,992	22,600
Net change in timing and other	0	(128)	4,018
Net change in income taxes	0	11,722	48,689
Aggregate change for the year	(10,313)	(56,483)	(97,045)
Ending Balance	0	10,313	66,796
Equity Method Investee
Schedule Of Changes In Standardized Measure Of Discounted Future Net Cash Flows [Line Items]
Beginning Balance	672	702	1,775
Changes resulting from:
Net change in sales prices and production costs	0	(60)	(1,112)
Net change in future development costs	0	0	0
Sales of oil and gas, net of production costs	0	(208)	(428)
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	(672)	0	0
Net change due to revisions of quantity estimates	0	63	(267)
Previously estimated development costs incurred	0	0	0
Accretion of discount	0	113	286
Net change in timing and other	0	(80)	(210)
Net change in income taxes	0	142	658
Aggregate change for the year	(672)	(30)	(1,073)
Ending Balance	$ 0	$ 672	$ 702

Supplemental Oil and Gas Disc99

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, 2017	Dec. 31, 2016	Dec. 31, 2015
Consolidated entities
Results of operations	$ (193)	$ (5,777)	$ (170,567)
Consolidated Entities
Consolidated entities
Revenues	1,399	10,111	51,553
Production costs	(209)	(4,392)	(19,820)
Exploration costs	(34)	(124)	(11,864)
Depreciation, depletion, amortization	0	(2,157)	(28,774)
Results of Operations, Impairment of Oil and Gas Properties	(224)	(612)	(164,831)
Oil and gas administrative expenses	(1,197)	(8,700)	(11,700)
Results of Operations, Accretion of Asset Retirement Obligations	0	(56)	(144)
Income tax expenses	(7)	(20)	14,717
Results of operations	(272)	(5,950)	(170,863)
Equity Method Investee
Consolidated entities
Royalty revenues	100	284	428
Production costs	(19)	(76)	(102)
Oil and gas administrative expenses	(2)	(35)	(51)
Income tax expenses	0	0	21
Results of operations	$ 79	$ 173	$ 296

Summary of Quarterly Results100

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, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Total revenues	$ 30,866	$ 33,136	$ 28,015	$ 22,305	$ 64,497	$ 47,207	$ 47,992	$ 37,618	$ 114,322	$ 197,314	$ 218,576
Gross profit	10,065	11,251	11,559	(28,332)	17,352	17,403	(24,953)	18,579
Operating income (loss)	(15,816)	12,381	6,965	36,235	50,980	6,256	69,528	13,590	39,765	140,354	23,942
Equity in earnings of unconsolidated ventures	7,026	1,764	2,747	6,362	2,251	3,637	188	47	17,899	6,123	16,008
Income (loss) before taxes	(12,298)	13,223	8,120	40,998	51,069	7,163	26,591	5,992	52,121	92,346	8,890
Income (loss) discontinued operations, net of taxes	7,191	37,193	1,229	418	563	(7,164)	(2,048)	(8,216)	46,031	(16,865)	(186,130)
Net income (loss) attributable to Forestar Group Inc.	$ (17,574)	$ 45,202	$ (2,579)	$ 25,205	$ 43,745	$ 9,665	$ 9,614	$ (4,376)	$ 50,254	$ 58,648	$ (213,047)
Net income (loss) per share -- basic
Continuing operations, basic (usd per share)	$ (0.59)	$ 0.19	$ (0.09)	$ 0.59	$ 1.03	$ 0.40	$ 0.28	$ 0.11	$ 0.10	$ 1.80	$ (0.79)
Discontinued operations, basic (usd per share)	0.17	0.88	0.03	0.01	0.01	(0.17)	(0.05)	(0.24)	1.09	(0.40)	(5.43)
Basic (usd per share)	(0.42)	1.07	(0.06)	0.60	1.04	0.23	0.23	(0.13)	1.19	1.40	(6.22)
Net income (loss) per share -- diluted
Continuing operations, diluted (usd per share)	(0.58)	0.19	(0.09)	0.58	1.02	0.40	0.28	0.09	0.10	1.78	(0.79)
Discontinued operations, diluted (usd per share)	0.18	0.87	0.03	0.01	0.01	(0.17)	(0.05)	(0.19)	1.09	(0.40)	(5.43)
Diluted (usd per share)	$ (0.40)	$ 1.06	$ (0.06)	$ 0.59	$ 1.03	$ 0.23	$ 0.23	$ (0.10)	$ 1.19	$ 1.38	$ (6.22)
Continuing Operations
Supplemental Oil And Gas Reserve Information [Line Items]
Impairment of oil and gas properties	$ 9,272	$ 0	$ 0	$ 37,900	$ 3,874	$ 7,627	$ 48,826	$ 0
Discontinued Operations
Supplemental Oil And Gas Reserve Information [Line Items]
Impairment of oil and gas properties	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 612	$ 0

Subsequent Event (Details)

Subsequent Event (Details) $ in Thousands	Feb. 08, 2018USD ($)Project	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Subsequent Event [Line Items]
Non-cash impairment charges | $		$ 47,172	$ 60,939	$ 108,184
Subsequent Event | Starwood Land, L.P. | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Subsequent Event [Line Items]
Purchase price of properties sold | $	$ 232,000
Net proceeds | $	$ 216,000
Entitled, developed and under development projects | Subsequent Event | Starwood Land, L.P. | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Subsequent Event [Line Items]
Number of projects sold	24
Land In Entitlement | Subsequent Event | Starwood Land, L.P. | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Subsequent Event [Line Items]
Number of projects sold	750
Future Undeveloped Lots | Subsequent Event | Starwood Land, L.P. | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Subsequent Event [Line Items]
Number of projects sold	4,000
Unentitled Acres | Subsequent Event | Starwood Land, L.P. | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Subsequent Event [Line Items]
Number of projects sold	730
Multifamily Site | Subsequent Event | Starwood Land, L.P. | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Subsequent Event [Line Items]
Number of projects sold	1
Equity Method Investments | Cost of Real Estate Sales
Subsequent Event [Line Items]
Non-cash impairment charges | $		$ 3,000

Schedule III - Consolidated 102

Schedule III - Consolidated Real Estate and Accumulated Depreciation (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Real Estate and Accumulated Depreciation [Line Items]
Encumbrances		$ 290
Land		274,241
Improvements less Cost of Sales and Other		28,727
Carrying Costs	[1]	7,659
Land & Land Improvements		310,627
Total		310,627	$ 293,003	$ 618,844	$ 607,133
Accumulated depreciation		0	0	(32,129)	$ (31,377)
Non-cash impairment charges		47,172	$ 60,939	$ 108,184
Real Estate, Net
Real Estate and Accumulated Depreciation [Line Items]
Encumbrances		290
Land		160,713
Improvements less Cost of Sales and Other		(34,076)
Carrying Costs	[2]	3,743
Land & Land Improvements		130,380
Total		130,380
Real Estate, Net | Other County | Other Property
Real Estate and Accumulated Depreciation [Line Items]
Land		0
Improvements less Cost of Sales and Other		4,742
Carrying Costs	[2]	0
Land & Land Improvements		4,742
Total		4,742
Real Estate, Net | 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
Real Estate, Net | Colorado | Douglas County | Cielo
Real Estate and Accumulated Depreciation [Line Items]
Land		3,933
Improvements less Cost of Sales and Other		3,187
Land & Land Improvements		7,120
Total		$ 7,120
Date Acquired		2,016
Real Estate, Net | Florida | Broward County | The Preserves at Stonebriar
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,002
Improvements less Cost of Sales and Other		244
Land & Land Improvements		3,246
Total		$ 3,246
Date Acquired		2,017
Real Estate, Net | Florida | Manatee County | Palisades
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 4,516
Improvements less Cost of Sales and Other		370
Land & Land Improvements		4,886
Total		$ 4,886
Date Acquired		2,017
Real Estate, Net | Florida | Sarasota County | Fox Creek
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 12,257
Improvements less Cost of Sales and Other		742
Land & Land Improvements		12,999
Total		$ 12,999
Date Acquired		2,017
Real Estate, Net | Georgia | Cobb County | West Oaks
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,669
Improvements less Cost of Sales and Other		748
Land & Land Improvements		2,417
Total		$ 2,417
Date of Construction		2,015
Date Acquired		2,015
Real Estate, Net | Georgia | Guinnett County | Independence
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 15,937
Improvements less Cost of Sales and Other		2,651
Land & Land Improvements		18,588
Total		$ 18,588
Date of Construction		2,017
Date Acquired		2,017
Real Estate, Net | Georgia | Paulding County | Harris Place
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 265
Improvements less Cost of Sales and Other		(219)
Land & Land Improvements		46
Total		$ 46
Date Acquired		2,012
Real Estate, Net | Georgia | Paulding County | Seven Hills
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 2,964
Improvements less Cost of Sales and Other		1,198
Carrying Costs	[2]	61
Land & Land Improvements		4,223
Total		$ 4,223
Date Acquired		2,012
Real Estate, Net | North Carolina | Cabbarus County | Moss Creek
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,254
Improvements less Cost of Sales and Other		116
Land & Land Improvements		1,370
Total		$ 1,370
Date of Construction		2,017
Date Acquired		2,016
Real Estate, Net | South Carolina | York County | Habersham
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,877
Improvements less Cost of Sales and Other		(948)
Carrying Costs	[2]	506
Land & Land Improvements		3,435
Total		$ 3,435
Date of Construction		2,014
Date Acquired		2,013
Real Estate, Net | Tennessee | Wilson County | Beckwith Crossing
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,294
Improvements less Cost of Sales and Other		1,070
Carrying Costs	[2]	275
Land & Land Improvements		2,639
Total		$ 2,639
Date of Construction		2,015
Date Acquired		2,014
Real Estate, Net | Tennessee | Williamson County | Morgan Farms
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 6,841
Improvements less Cost of Sales and Other		(4,168)
Carrying Costs	[2]	225
Land & Land Improvements		2,898
Total		$ 2,898
Date of Construction		2,013
Date Acquired		2,013
Real Estate, Net | Tennessee | Williamson County | Weatherford Estates
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 856
Improvements less Cost of Sales and Other		(922)
Carrying Costs	[2]	139
Land & Land Improvements		73
Total		$ 73
Date of Construction		2,015
Date Acquired		2,014
Real Estate, Net | 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
Real Estate, Net | Texas | Collin County | Lakes Of Prosper
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 8,951
Improvements less Cost of Sales and Other		(9,094)
Carrying Costs	[2]	453
Land & Land Improvements		310
Total		$ 310
Date Acquired		2,012
Real Estate, Net | Texas | Collin County | Parkside
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 2,177
Improvements less Cost of Sales and Other		(1,937)
Carrying Costs	[2]	307
Land & Land Improvements		547
Total		$ 547
Date of Construction		2,014
Date Acquired		2,013
Real Estate, Net | Texas | Collin County | Timber Creek
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 7,282
Improvements less Cost of Sales and Other		6,410
Carrying Costs	[2]	212
Land & Land Improvements		13,904
Total		$ 13,904
Date of Construction		2,007
Date Acquired		2,007
Real Estate, Net | Texas | Denton County | Lantana
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 27,673
Improvements less Cost of Sales and Other		(19,680)
Carrying Costs	[2]	585
Land & Land Improvements		8,578
Total		$ 8,578
Date of Construction		2,000
Date Acquired		1,999
Real Estate, Net | Texas | Denton County | River's Edge
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,227
Improvements less Cost of Sales and Other		445
Land & Land Improvements		1,672
Total		$ 1,672
Date Acquired		2,014
Real Estate, Net | 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		(681)
Carrying Costs	[2]	256
Land & Land Improvements		5,430
Total		$ 5,430
Date of Construction		2,006
Date Acquired		2,005
Real Estate, Net | Texas | Kaufman County | Lakewood Trails
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 8,009
Improvements less Cost of Sales and Other		340
Land & Land Improvements		8,349
Total		$ 8,349
Date Acquired		2,017
Real Estate, Net | Texas | Tarrant County | Summer Creek Ranch
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 2,887
Improvements less Cost of Sales and Other		(1,651)
Land & Land Improvements		1,236
Total		$ 1,236
Date Acquired		2,012
Real Estate, Net | Texas | Tarrant County | Bar C Ranch
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,365
Improvements less Cost of Sales and Other		3,623
Carrying Costs	[2]	430
Land & Land Improvements		5,418
Total		$ 5,418
Date Acquired		2,012
Real Estate, Net | Texas | Fort Bend County | Southern Colony
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,024
Improvements less Cost of Sales and Other		4,090
Land & Land Improvements		7,114
Total		$ 7,114
Date Acquired		2,017
Real Estate, Net | Texas | Fort Bend County | Willow Creek Farms
Real Estate and Accumulated Depreciation [Line Items]
Encumbrances		$ 290
Land		3,479
Improvements less Cost of Sales and Other		(1,741)
Carrying Costs	[2]	60
Land & Land Improvements		1,798
Total		$ 1,798
Date of Construction		2,012
Date Acquired		2,012
Real Estate, Net | Texas | Harris County | City Park
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,946
Improvements less Cost of Sales and Other		(3,794)
Carrying Costs	[2]	229
Land & Land Improvements		381
Total		$ 381
Date of Construction		2,002
Date Acquired		2,001
Real Estate, Net | Texas | Harris County | Imperial Forest
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 5,345
Improvements less Cost of Sales and Other		(634)
Carrying Costs	[2]	5
Land & Land Improvements		4,716
Total		$ 4,716
Date of Construction		2,015
Date Acquired		2,014
Real Estate, Held For Sale
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 113,528
Improvements less Cost of Sales and Other	[3]	62,803
Carrying Costs	[2],[3]	3,916
Land & Land Improvements	[3]	180,247
Total	[3]	180,247
Real Estate, Held For Sale | California | Los Angeles | Land In Entitlement Process
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	3,950
Improvements less Cost of Sales and Other	[3]	21,752
Land & Land Improvements	[3]	25,702
Total	[3]	$ 25,702
Date Acquired	[3]	1,997
Real Estate, Held For Sale | Colorado | Douglas County | Pinery West
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 7,308
Improvements less Cost of Sales and Other	[3]	3,849
Land & Land Improvements	[3]	11,157
Total	[3]	$ 11,157
Date of Construction	[3]	2,006
Date Acquired	[3]	2,006
Real Estate, Held For Sale | Colorado | Weld County | Buffalo Highlands
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 3,001
Improvements less Cost of Sales and Other	[3]	(295)
Land & Land Improvements	[3]	2,706
Total	[3]	$ 2,706
Date of Construction	[3]	2,006
Date Acquired	[3]	2,005
Real Estate, Held For Sale | Colorado | Weld County | Johnstown Farms
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 2,749
Improvements less Cost of Sales and Other	[3]	4,073
Carrying Costs	[2],[3]	100
Land & Land Improvements	[3]	6,922
Total	[3]	$ 6,922
Date of Construction	[3]	2,002
Date Acquired	[3]	2,002
Real Estate, Held For Sale | Colorado | Weld County | Stone Braker
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 3,878
Improvements less Cost of Sales and Other	[3]	(1,786)
Land & Land Improvements	[3]	2,092
Total	[3]	$ 2,092
Date of Construction	[3]	2,005
Date Acquired	[3]	2,005
Real Estate, Held For Sale | North Carolina | Mechlanburg County | Walden
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 12,085
Improvements less Cost of Sales and Other	[3]	5,446
Carrying Costs	[2],[3]	350
Land & Land Improvements	[3]	17,881
Total	[3]	$ 17,881
Date of Construction	[3]	2,016
Date Acquired	[3]	2,015
Real Estate, Held For Sale | South Carolina | Lancaster County | Ansley
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 5,089
Improvements less Cost of Sales and Other	[3]	4,198
Carrying Costs	[2],[3]	315
Land & Land Improvements	[3]	9,602
Total	[3]	$ 9,602
Date of Construction	[3]	2,017
Date Acquired	[3]	2,015
Real Estate, Held For Sale | Tennessee | Williamson County | Scales Farmstead
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 3,575
Improvements less Cost of Sales and Other	[3]	4,848
Carrying Costs	[2],[3]	455
Land & Land Improvements	[3]	8,878
Total	[3]	$ 8,878
Date Acquired	[3]	2,015
Real Estate, Held For Sale | Texas | Bastrop County | Hunters Crossing
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 3,613
Improvements less Cost of Sales and Other	[3]	3,970
Land & Land Improvements	[3]	7,583
Total	[3]	$ 7,583
Date of Construction	[3]	2,001
Date Acquired	[3]	2,001
Real Estate, Held For Sale | Texas | Bexar County | Cibolo Canyons
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 17,305
Improvements less Cost of Sales and Other	[3]	22,088
Carrying Costs	[2],[3]	1,696
Land & Land Improvements	[3]	41,089
Total	[3]	$ 41,089
Date of Construction	[3]	2,004
Date Acquired	[3]	1,986
Real Estate, Held For Sale | Texas | Dallas County | Stoney Creek
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 12,822
Improvements less Cost of Sales and Other	[3]	1,712
Carrying Costs	[2],[3]	608
Land & Land Improvements	[3]	15,142
Total	[3]	$ 15,142
Date of Construction	[3]	2,007
Date Acquired	[3]	2,007
Real Estate, Held For Sale | Texas | Fort Bend County | Summer Lakes
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 4,269
Improvements less Cost of Sales and Other	[3]	(1,100)
Carrying Costs	[2],[3]	89
Land & Land Improvements	[3]	3,258
Total	[3]	$ 3,258
Date of Construction	[3]	2,013
Date Acquired	[3]	2,012
Real Estate, Held For Sale | Texas | Fort Bend County | Summer Park
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 4,804
Improvements less Cost of Sales and Other	[3]	(2,490)
Carrying Costs	[2],[3]	17
Land & Land Improvements	[3]	2,331
Total	[3]	$ 2,331
Date of Construction	[3]	2,013
Date Acquired	[3]	2,012
Real Estate, Held For Sale | Texas | Harris County | Barrington
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 8,950
Improvements less Cost of Sales and Other	[3]	(7,892)
Land & Land Improvements	[3]	1,058
Total	[3]	$ 1,058
Date Acquired	[3]	2,011
Real Estate, Held For Sale | Texas | Hays County | Arrowhead Ranch
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 12,856
Improvements less Cost of Sales and Other	[3]	7,639
Carrying Costs	[2],[3]	286
Land & Land Improvements	[3]	20,781
Total	[3]	$ 20,781
Date of Construction	[3]	2,015
Date Acquired	[3]	2,007
Real Estate, Held For Sale | Texas | Travis County | West Austin
Real Estate and Accumulated Depreciation [Line Items]
Land	[3]	$ 7,274
Improvements less Cost of Sales and Other	[3]	(1,525)
Land & Land Improvements	[3]	5,749
Total	[3]	$ 5,749
Date Acquired	[3]	2,014
Real Estate, Held For Sale | Texas | Other County | Other Property
Real Estate and Accumulated Depreciation [Line Items]
Improvements less Cost of Sales and Other	[3],[4]	$ (1,684)
Land & Land Improvements	[3],[4]	(1,684)
Total	[3],[4]	(1,684)
Equity Method Investments | Cost of Real Estate Sales
Real Estate and Accumulated Depreciation [Line Items]
Non-cash impairment charges		$ 3,000
[1]	Includes natural gas liquids (NGLs).
[2]	We do not capitalize carrying costs until development begins.
[3]	Included in the strategic asset sale to Starwood on February 8, 2018. Please read Note 22 — Subsequent Event for additional information regarding this transaction.
[4]	Includes $3,000,000 in non-cash impairment charges in fourth quarter 2017 associated with the asset group sold to Starwood.

Schedule III - Reconciliation o

Schedule III - Reconciliation of Real Estate and Accumulated Depreciation (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
SEC Schedule III, Reconciliation of Carrying Amount of Real Estate Investments [Roll Forward]
Beginning balance	$ 293,003	$ 618,844	$ 607,133
Amounts capitalized	105,611	89,780	124,633
Amounts retired or adjusted	(87,987)	(415,621)	(112,922)
Ending balance	310,627	293,003	618,844
Beginning balance	0	(32,129)	(31,377)
Depreciation expense	0	(816)	(6,810)
Amounts retired or adjusted	0	32,945	6,058
Ending balance	$ 0	$ 0	$ (32,129)