Forestar (FOR) 10-K 4 Mar 16 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Feb. 29, 2016	Jun. 30, 2015
Entity Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Trading Symbol	FOR
Entity Registrant Name	FORESTAR GROUP INC.
Entity Central Index Key	1,406,587
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		33,906,986
Entity Public Float			$ 275

CONSOLIDATED BALANCE SHEET

CONSOLIDATED BALANCE SHEET - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
ASSETS
Cash and cash equivalents	$ 96,442	$ 170,127
Real estate, net	586,715	575,756
Oil and gas properties and equipment, net	80,613	263,493
Investment in unconsolidated ventures	82,453	65,005
Timber	7,683	8,315
Receivables, net	23,656	24,589
Income taxes receivable	12,056	7,503
Prepaid expenses	3,213	6,000
Property and equipment, net	10,732	11,627
Deferred tax asset, net	0	40,624
Goodwill and other intangible assets	63,128	66,131
Other assets	13,822	19,029
TOTAL ASSETS	980,513	1,258,199
LIABILITIES AND EQUITY
Accounts payable	11,959	20,400
Accrued employee compensation and benefits	5,547	8,323
Accrued property taxes	4,788	5,966
Accrued interest	3,267	3,451
Deferred tax liability, net	1,037	0
Earnest money deposits	10,214	10,045
Other accrued expenses	23,481	35,729
Other liabilities	26,323	31,799
Debt	389,782	432,744
TOTAL LIABILITIES	$ 476,398	$ 548,457
COMMITMENTS AND CONTINGENCIES
Forestar Group Inc. shareholders’ equity:
Common stock, par value $1.00 per share, 200,000,000 authorized shares, 36,946,603 issued at December 31, 2015 and December 31, 2014	$ 36,947	$ 36,947
Additional paid-in capital	561,850	558,945
Retained earnings (Accumulated deficit)	(46,046)	167,001
Treasury stock, at cost, 3,203,768 shares at December 31, 2015 and 3,485,278 shares at December 31, 2014	(51,151)	(55,691)
Total Forestar Group Inc. shareholders’ equity	501,600	707,202
Noncontrolling interests	2,515	2,540
TOTAL EQUITY	504,115	709,742
TOTAL LIABILITIES AND EQUITY	$ 980,513	$ 1,258,199

CONSOLIDATED BALANCE SHEET (Par

CONSOLIDATED BALANCE SHEET (Parenthetical) - $ / shares	Dec. 31, 2015	Dec. 31, 2014
Statement of Financial Position [Abstract]
Common stock, par value	$ 1	$ 1
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares issued	36,946,603	36,946,603
Treasury stock, common shares	3,203,768	3,485,278

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
REVENUES
Real estate sales and other	$ 120,022	$ 171,672	$ 152,684
Commercial and income producing properties	82,808	41,440	95,327
Real estate	202,830	213,112	248,011
Oil and gas	52,939	84,300	72,313
Other natural resources	6,652	9,362	10,721
Total revenues	262,421	306,774	331,045
COST AND EXPENSES
Cost of real estate sales and other	(52,640)	(86,432)	(76,628)
Cost of commercial and income producing properties	(61,251)	(37,332)	(80,166)
Cost of oil and gas producing activities	(224,400)	(98,371)	(42,067)
Cost of other natural resources	(3,081)	(3,006)	(2,033)
Other operating	(59,359)	(58,683)	(60,359)
General and administrative	(27,253)	(22,230)	(28,376)
Total expenses	(427,984)	(306,054)	(289,629)
GAIN ON SALE OF ASSETS	879	38,038	5,161
OPERATING INCOME (LOSS)	(164,684)	38,758	46,577
Equity in earnings of unconsolidated ventures	16,008	8,685	8,737
Interest expense	(34,066)	(30,286)	(20,004)
Other non-operating income	3,006	8,588	6,959
INCOME (LOSS) BEFORE TAXES	(179,736)	25,745	42,269
Income tax expense	(32,635)	(8,657)	(7,208)
Net income	(212,371)	17,088	35,061
Less: Net (income) attributable to noncontrolling interests	(676)	(505)	(5,740)
NET INCOME (LOSS) ATTRIBUTABLE TO FORESTAR GROUP INC.	$ (213,047)	$ 16,583	$ 29,321
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING
Basic (usd per share)	34,266	35,317	35,365
Diluted (usd per share)	34,266	43,596	36,813
NET INCOME (LOSS) PER COMMON SHARE
Basic (usd per share)	$ (6.22)	$ 0.38	$ 0.81
Diluted (usd per share)	$ (6.22)	$ 0.38	$ 0.80
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO FORESTAR GROUP INC.	$ (213,047)	$ 16,583	$ 29,321

CONSOLIDATED STATEMENTS OF EQUI

CONSOLIDATED STATEMENTS OF EQUITY - USD ($)	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Treasury Stock [Member]	Retained Earnings [Member]	Noncontrolling Interest [Member]	Stock Options [Member]	Former Affiliated Entity [Member]Common Stock [Member]	Former Affiliated Entity [Member]Additional Paid-in Capital [Member]	Former Affiliated Entity [Member]Treasury Stock [Member]	Former Affiliated Entity [Member]Stock Options [Member]
Beginning Balances at Dec. 31, 2012	$ 533,547,000	$ 36,947,000	$ 407,206,000	$ (35,762,000)	$ 121,097,000	$ 4,059,000
Beginning Balances, Shares at Dec. 31, 2012		36,946,603		2,327,623
Net income	35,061,000				29,321,000	5,740,000
Distributions to noncontrolling interest	(7,269,000)					(7,269,000)
Contributions from noncontrolling interest	3,022,000					3,022,000
Issuances of restricted stock, Shares				7,298
Issuances of restricted stock, Value	2,871,000		2,721,000	$ 150,000
Adjustments to Additional Paid in Capital, Equity Component of Convertible Debt, Subsequent Adjustments	17,058,000
TEU issuance proceeds, net of issuance costs - 6,000,000 units	120,335,000
Issuances from exercises of stock options, net of swaps, Shares		0		53,611				0		136,253
Issuances from exercises of stock options, net of swaps, Value	683,000	$ 0	66,000	$ 617,000				$ 0	$ (515,000)	$ 1,938,000	$ 1,423,000
Shares withheld for payroll taxes, Shares				(59,219)
Shares withheld for payroll taxes, Value	(1,137,000)		(8,000)	$ (1,129,000)
Forfeitures of restricted stock, Shares				(9,986)
Forfeitures of restricted stock, Value	0		10,000	$ (10,000)
Share-based compensation	9,911,000		9,911,000
Tax benefit from exercise of restricted stock units and stock options and vested restricted stock	(108,000)		(108,000)
Ending Balances at Dec. 31, 2013	715,397,000	$ 36,947,000	556,676,000	$ (34,196,000)	150,418,000	5,552,000
Ending Balances, Shares at Dec. 31, 2013		36,946,603		2,199,666
Net income	17,088,000				16,583,000	505,000
Distributions to noncontrolling interest	(4,171,000)					(4,171,000)
Contributions from noncontrolling interest	2,585,000					2,585,000
Dissolution of noncontrolling interests	1,342,000					1,342,000
Purchase of noncontrolling interests, net	(6,242,000)		(2,969,000)			(3,273,000)
Issuances of common stock, Shares		0		164,914
Issuances of common stock, Value	0	$ 0	(2,567,000)	$ 2,567,000
Issuances from exercises of stock options, net of swaps, Shares				45,062				0		60,823
Issuances from exercises of stock options, net of swaps, Value	$ 329,000		(333,000)	$ 662,000				$ 0	(43,000)	$ 920,000	877,000
Shares withheld for payroll taxes, Shares	(55,238)			(55,238)
Shares withheld for payroll taxes, Value	$ (1,043,000)		(4,000)	$ (1,039,000)
Shares repurchased, Shares	(1,491,187)			(1,491,187)
Shares repurchased, Value	$ (24,595,000)			$ (24,595,000)
Forfeitures of restricted stock, Shares				(9,986)
Forfeitures of restricted stock, Value	0		10,000	$ (10,000)
Share-based compensation	8,033,000		8,033,000
Tax benefit from exercise of restricted stock units and stock options and vested restricted stock	142,000		142,000
Ending Balances at Dec. 31, 2014	709,742,000	$ 36,947,000	558,945,000	$ (55,691,000)	167,001,000	2,540,000
Ending 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	$ 0		(5,362,000)	$ 5,362,000
Issuances from exercises of stock options, net of swaps, Shares							0			3,999
Issuances from exercises of stock options, net of swaps, Value									$ (33,000)	$ 64,000	$ 31,000
Shares withheld for payroll taxes, Shares	(51,521)			(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

CONSOLIDATED STATEMENTS OF EQU6

CONSOLIDATED STATEMENTS OF EQUITY CONSOLIDATED STATEMENTS OF EQUITY (Parenthetical)	Nov. 27, 2013Unit
6% Tangible Equity Units [Member]
Units issued	6,000,000

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
CASH FLOWS FROM OPERATING ACTIVITIES:
Consolidated net income (loss)	$ (212,371)	$ 17,088	$ 35,061
Adjustments:
Depreciation, depletion and amortization	45,085	41,715	29,980
Change in deferred income taxes	41,261	1,645	5,389
Change in unrecognized tax benefits	0	0	(6,251)
Equity in earnings of unconsolidated ventures	(16,008)	(8,685)	(8,737)
Distributions of earnings of unconsolidated ventures	12,741	5,721	6,360
Share-based compensation	4,246	3,417	16,809
Real estate cost of sales	87,733	84,665	104,899
Dry hole and unproved leasehold impairment costs	67,639	29,528	5,837
Real estate development and acquisition expenditures, net	(107,988)	(114,694)	(106,609)
Reimbursements from utility and improvement districts	15,176	66,047	9,945
Asset impairments	108,184	15,934	1,790
Gain on sale of assets	(879)	(38,038)	(5,161)
Other	4,680	5,887	2,391
Changes in:
Notes and accounts receivables	(978)	10,704	(3,864)
Prepaid expenses and other	3,026	2,180	(795)
Accounts payable and other accrued liabilities	(11,868)	(4,653)	(1,557)
Income taxes	(4,553)	(11,379)	3,290
Net cash provided by operating activities	35,126	107,082	88,777
Property, equipment, software, reforestation and other	(14,690)	(16,398)	(11,828)
Oil and gas properties and equipment	(49,717)	(101,145)	(96,069)
Acquisition of partner's interest in unconsolidated multifamily venture, net of cash	0	(20,155)
Acquisition of oil and gas properties	0	(1,100)	0
Investment in unconsolidated ventures	(26,349)	(14,692)	(857)
Proceeds from sale of assets	18,260	21,962	1,333
Return of investment in unconsolidated ventures	12,168	1,797	3,494
Net cash (used for) investing activities	(60,328)	(129,731)	(103,927)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from issuance of convertible senior notes, net	0	0	120,795
Proceeds from issuance of senior secured notes, net	0	241,947	0
Proceeds from issuance of tangible equity units, net	0	0	144,998
Payments of debt	(58,220)	(225,481)	(106,076)
Additions to debt	11,463	22,593	43,911
Deferred financing fees	(295)	(3,217)	(438)
Distributions to noncontrolling interests, net	(701)	(3,146)	(7,154)
Purchase of noncontrolling interests	0	(7,971)	0
Exercise of stock options	31	1,206	2,106
Repurchases of common stock	0	(24,595)	0
Payroll taxes on restricted stock and stock options	(762)	(1,043)	(1,137)
Excess income tax benefit from share-based compensation	1	176	91
Net cash (used for) provided by financing activities	(48,483)	469	197,096
Net (decrease) increase in cash and cash equivalents	(73,685)	(22,180)	181,946
Cash and cash equivalents at beginning of year	170,127	192,307	10,361
Cash and cash equivalents at year-end	96,442	170,127	192,307
Cash paid during the year for:
Interest	27,330	22,936	13,818
Income taxes paid (refunds)	(4,077)	18,322	4,955
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION:
Capitalized interest	2,938	1,154	816
Noncontrolling interests	$ 0	$ 2,904	2,907
Multi Family Property [Member]
Acquisition of partner's interest in unconsolidated multifamily venture, net of cash			$ 0

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Basis of Presentation Our consolidated financial statements include the accounts of Forestar Group Inc., all subsidiaries, ventures and other entities in which we have a controlling interest. We account for our investment in other entities in which we have significant influence over operations and financial policies using the equity method (we recognize our share of the entities’ income or loss and any preferential returns and treat distributions as a reduction of our investment). We eliminate all material intercompany accounts and transactions. Noncontrolling interests in consolidated pass-through entities are recognized before income taxes. We prepare our financial statements in accordance with generally accepted accounting principles in the United States, which require us to make estimates and assumptions about future events. Actual results can, and probably will, differ from those we currently estimate. Examples of significant estimates include those related to allocating costs to real estate, measuring long-lived assets for impairment, oil and gas revenue accruals, capital expenditure and lease operating expense accruals associated with our oil and gas production activities, oil and gas reserves and depletion of our oil and gas properties. Cash and Cash Equivalents Cash and cash equivalents include cash and other short-term instruments with original maturities of three months or less. At year-end 2015 and 2014 , restricted cash was $200,000 and $217,000 and is included in other assets. Cash Flows Expenditures for the acquisition and development of single-family and multifamily real estate that we intend to develop for sale are classified as operating activities. Expenditures for the acquisition and development of properties to be held and operated, investment in oil and gas properties and equipment, and business acquisitions are classified as investing activities. Our accrued capital expenditures for unproved leasehold acquisitions and drilling and completion costs at year-end 2015 and 2014 were $7,033,000 and $19,405,000 and are included in other accrued expenses in our consolidated balance sheets. These oil and gas property additions will be reflected as cash used for investing activities in the period the accrued payables are settled. Capitalized Software We capitalize purchased software costs as well as the direct internal and external costs associated with software we develop for our own use. We amortize these capitalized costs using the straight-line method over estimated useful lives generally ranging from three to five years . The carrying value of capitalized software was $237,000 at year-end 2015 and $1,188,000 at year-end 2014 and is included in other assets. The amortization of these capitalized costs was $996,000 in 2015 , $1,067,000 in 2014 and $1,593,000 in 2013 and is included in general and administrative and operating expenses. Environmental and Asset Retirement Obligations We recognize environmental remediation liabilities on an undiscounted basis when environmental assessments or remediation are probable and we can reasonably estimate the cost. We adjust these liabilities as further information is obtained or circumstances change. Our asset retirement obligations are related to the abandonment and site restoration requirements that result from the acquisition, construction and development of our oil and gas properties. We record the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. Accretion expense related to the asset retirement obligation and depletion expense related to capitalized asset retirement cost is included in cost of oil and gas producing activities on our consolidated statements of income (loss). The following summarizes the changes in asset retirement obligations: Year-End 2015 2014 (In thousands) Beginning balance $ 1,807 $ 1,483 Additions 65 314 Property dispositions (119 ) (230 ) Change in estimate — 118 Liabilities settled (139 ) — Accretion expense 144 122 $ 1,758 $ 1,807 Fair Value Measurements Financial instruments for which we did not elect the fair value option include cash and cash equivalents, accounts and notes receivables, other assets, long-term debt, accounts payable and other liabilities. With the exception of long-term notes receivable and debt, the carrying amounts of these financial instruments approximate their fair values due to their short-term nature or variable interest rates. Goodwill and Other Intangible Assets We record goodwill when the purchase price of a business acquisition exceeds the estimated fair value of net identified tangible and intangible assets acquired. We do not amortize goodwill or other indefinite lived intangible assets. Instead, we measure these assets for impairment based on the estimated fair values at least annually or more frequently if impairment indicators exist. We perform the annual impairment measurement in the fourth quarter of each year. Intangible assets with finite useful lives are amortized over their estimated useful lives. In 2015 , we performed our annual goodwill impairment evaluation and concluded that goodwill was not impaired as the estimated fair value exceeded the carrying value. Income Taxes We provide deferred income taxes using current tax rates for temporary differences between the financial accounting carrying value of assets and liabilities and their tax accounting carrying values. We recognize and value income tax exposures for the various taxing jurisdictions where we operate based on laws, elections, commonly accepted tax positions, and management estimates. We include tax penalties and interest in income tax expense. We provide a valuation allowance for any deferred tax asset that is not likely to be recoverable in future periods. When we believe a tax position is supportable but the outcome uncertain, we include the item in our tax return but do not recognize the related benefit in our provision for taxes. Instead, we record a reserve for unrecognized tax benefits, which represents our expectation of the most likely outcome considering the technical merits and specific facts of the position. Changes to liabilities are only made when an event occurs that changes the most likely outcome, such as settlement with the relevant tax authority, expiration of statutes of limitations, changes in tax law, or recent court rulings. Owned Mineral Interests When we lease our mineral interests to third-party exploration and production entities, we retain a royalty interest and may take an additional participation in production, including a working interest. Mineral interests and working interests related to our owned mineral interests are included in oil and gas properties and equipment on our balance sheet, net of accumulated depletion. Oil and Gas Properties We use the successful efforts method of accounting for our oil and gas producing activities. Costs to acquire mineral interests leased, costs to drill and complete development of oil and gas wells and related asset retirement costs are capitalized. Costs to drill exploratory wells are capitalized pending determination of whether the wells have proved reserves and if determined incapable of producing commercial quantities of oil and gas these costs are expensed as dry hole costs. At year-end 2014, we had $8,575,000 in capitalized exploratory well costs pending determination of proved reserves, of which $8,454,000 was charged to expense in 2015 with the remaining capitalized based on determination of proved reserves. At year-end 2015 , we have no capitalized exploratory well costs pending determination of proved reserves. Exploration costs include dry hole costs, geological and geophysical costs, expired unproved leasehold costs and seismic studies, and are expensed as incurred. Production costs incurred to maintain wells and related equipment are charged to expense as incurred. Depreciation and depletion of producing oil and gas properties is calculated using the units-of-production method. Proved developed reserves are used to compute unit rates for unamortized tangible and intangible drilling and completion costs. Proved reserves are used to compute unit rates for unamortized acquisition of proved leasehold costs. Unit-of-production amortization rates are revised whenever there is an indication of the need for revision but at least once a year and those revisions are accounted for prospectively as changes in accounting estimates. Impairment of Oil and Gas Properties We evaluate our oil and gas properties, including facilities and equipment, for impairment whenever events or changes in circumstances indicate that the carrying value of an asset may not be recoverable. We estimate the expected undiscounted future cash flows of our oil and gas properties and compare such undiscounted future cash flows to the carrying amount of the oil and gas properties to determine if the carrying amount is recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, we will adjust the carrying amount of the oil and gas properties to fair value. The factors used to determine fair value are subject to our judgment and expertise and include, but are not limited to, recent sales prices of comparable properties, the present value of future cash flows, net of estimated operating and development costs using estimates of proved reserves, future commodity pricing, future production estimates, anticipated capital expenditures, and various discount rates commensurate with the risk and current market conditions associated with realizing the expected cash flows projected. Because of the uncertainty inherent in these factors, we cannot predict when or if future impairment charges for proved properties will be recorded. The assessment of unproved leasehold properties to determine any possible impairment requires significant judgment. We assess our unproved leasehold properties periodically for impairment on a property-by-property basis based on remaining lease terms, drilling results or future plans to develop acreage. Impairment expense for proved and unproved oil and gas properties are included in costs of oil and gas producing activities. Operating Leases We occupy office space in various locations under operating leases. The lease agreements may contain rent escalation clauses, construction allowances and/or contingent rent provisions. We expense operating leases ratably over the shorter of the useful life or the lease term. For scheduled rent escalation clauses, we recognize the base rent expense on a straight-line basis and record the difference between the recognized rent expense and the amounts payable under the lease as deferred lease credits included in other liabilities in the consolidated balance sheets. Deferred lease credits are amortized over the lease term. For construction allowances, we record leasehold improvement assets included in property and equipment in the consolidated balance sheets amortized over the shorter of their economic lives or the lease term. The related deferred lease credits are amortized as a reduction of rent expense over the lease term. Property and Equipment We carry property and equipment at cost less accumulated depreciation. We capitalize the cost of significant additions and improvements, and we expense the cost of repairs and maintenance. We capitalize interest costs incurred on major construction projects. We depreciate these assets using the straight-line method over their estimated useful lives as follows: Estimated Year-End Useful Lives 2015 2014 (In thousands) Buildings and building improvements 10 to 40 years $ 4,044 $ 4,461 Property and equipment 2 to 10 years 12,230 14,084 16,274 18,545 Less: accumulated depreciation (5,542 ) (6,918 ) $ 10,732 $ 11,627 Depreciation expense of property and equipment was $1,067,000 in 2015 , $903,000 in 2014 and $1,028,000 in 2013 . Real Estate We carry real estate at the lower of cost or fair value less cost to sell. We capitalize interest costs once development begins, and we continue to capitalize throughout the development period. We also capitalize infrastructure, improvements, amenities, and other development costs incurred during the development period. We determine the cost of real estate sold using the relative sales value method. When we sell real estate from projects that are not finished, we include in the cost of real estate sold estimates of future development costs through completion, allocated based on relative sales values. These estimates of future development costs are reevaluated at least annually, with any adjustments being allocated prospectively to the remaining units available for sale. We receive cash deposits from home builders for purchases of vacant developed lots from community development projects. These earnest money deposits are released to the home builders as lots are developed and sold. Income producing properties are carried at cost less accumulated depreciation computed using the straight-line method over their estimated useful lives. We have agreements with utility or improvement districts, principally in Texas, whereby we agree to convey to the district's water, sewer and other infrastructure-related assets we have constructed in connection with projects within their jurisdiction. The reimbursement for these assets ranges from 70 to 90 percent of allowable cost as defined by the district. The transfer is consummated and we receive payment when the districts have a sufficient tax base to support funding of their bonds. The cost we incur in constructing these assets is included in capitalized development costs, and upon collection, we remove the assets from capitalized development costs. We provide an allowance to reflect our past experiences related to claimed allowable development costs. Impairment of Real Estate Long-Lived Assets We review real estate long-lived assets held for use for impairment when events or circumstances indicate that their carrying value may not be recoverable. Impairment exists if the carrying amount of the long-lived asset is not recoverable from the undiscounted cash flows expected from its use and eventual disposition. We determine the amount of the impairment loss by comparing the carrying value of the long-lived asset to its estimated fair value. In the absence of quoted market prices, we determine estimated fair value generally based on the present value of future probability weighted cash flows expected from the sale of the long-lived asset. Non-cash impairment charges related to our owned and consolidated real estate assets are included in cost of real estate sales and other. Revenue Real Estate We recognize revenue from sales of real estate when a sale is consummated, the buyer’s initial investment is adequate, any receivables are probable of collection, the usual risks and rewards of ownership have been transferred to the buyer, and we do not have significant continuing involvement with the real estate sold. If we determine that the earnings process is not complete, we defer recognition of any gain until earned. We recognize revenue from hotel room sales and other guest services when rooms are occupied and other guest services have been rendered. We recognize rental revenues from our multifamily properties when earned in accordance with the terms of the respective leases on a straight-line basis for the period of occupancy. We recognize construction revenues on multifamily projects that we develop as a general contractor. Construction revenues are recognized as costs are incurred plus fixed fee earned. We are reimbursed for costs paid to subcontractors plus we may earn a development and construction management fee on multifamily projects we develop, both of which are included in commercial and income producing properties revenue. On multifamily projects where our fee is based on a fixed fee plus guaranteed maximum price contract, any cost overruns incurred during construction, as compared to the original budget, will reduce the net fee generated on these projects. Any excess cost overruns estimated over the net fee generated are recognized in the period in which they become evident. At year-end 2015, we are not a general contractor on any of the multifamily projects currently under construction and we do not anticipate to be a general contractor on any new multifamily projects. We exclude from revenue amounts we collect from utility or improvement districts related to the conveyance of water, sewer and other infrastructure related assets. We also exclude from revenue amounts we collect for timber sold on land being developed. These proceeds reduce capitalized development costs. We exclude from revenue amounts we collect from customers that represent sales tax or other taxes that are based on the sale. These amounts are included in other accrued expenses until paid. Oil and Gas We recognize revenue as oil and gas is produced and sold. There are a significant amount of oil and gas properties which we do not operate and, therefore, revenue is typically recorded in the month of production based on an estimate of our share of volumes produced and prices realized. We obtain the most current available production data from the operators and price indices for each well to estimate the accrual of revenue. Obtaining production data on a timely basis for some wells is not feasible; therefore we utilize past production receipts and estimated sales price information to estimate accrual of working interest revenue on all other non-operated wells each month. Revisions to such estimates are recorded as actual results become known. We review accounts receivable periodically and reduce the carrying amount by a valuation allowance that reflects our best estimate of the amount that may not be collectible. A majority of our sales are made under contractual arrangements with terms that are considered to be usual and customary in the oil and gas industry. The contracts are for periods of up to five years with prices determined upon a percentage of pre-determined and published monthly index price. The terms of these contracts have not had an effect on how we recognize revenue. We recognize revenue from mineral bonus payments received as a result of leasing our owned mineral interests to others when we have received an executed agreement with the exploration company transferring the rights to any oil or gas it may find and requiring drilling be done within a specified period, the payment has been collected, and we have no obligation to refund the payment. We recognize revenue from delay rentals received if drilling has not started within the specified period and when the payment has been collected. We recognize revenue from mineral royalties when the minerals have been delivered to the buyer, the value is determinable, and we are reasonably sure of collection. Other Natural Resources We recognize revenue from timber sales upon passage of title, which occurs at delivery; when the price is fixed and determinable; and we are reasonably sure of collection. We recognize revenue from recreational leases on the straight-line basis over the lease term. We recognize revenue from the sale of water rights or groundwater reservation agreements upon receipt of an executed agreement and payment has been collected and all conditions to the agreement have been met and we have no further performance obligations to meet. The water delivery revenues will be recognized as water is being delivered and metered at the delivery point. Share-Based Compensation We use the Black-Scholes option pricing model for stock options, Monte Carlo simulation pricing model for market-leveraged stock units and for stock options with market conditions, grant date fair value for equity-settled awards and period-end fair value for cash-settled awards. We expense share-based awards ratably over the vesting period or earlier based on retirement eligibility. Timber We carry timber at cost less the cost of timber cut. We expense the cost of timber cut based on the relationship of the timber carrying value to the estimated volume of recoverable timber multiplied by the amount of timber cut. We include the cost of timber cut in cost of other natural resources in the income statement. We determine the estimated volume of recoverable timber using statistical information and other data related to growth rates and yields gathered from physical observations, models and other information gathering techniques. Changes in yields are generally due to adjustments in growth rates and similar matters and are accounted for prospectively as changes in estimates. We capitalize reforestation costs incurred in developing viable seedling plantations (up to two years from planting), such as site preparation, seedlings, planting, fertilization, insect and wildlife control, and herbicide application. We expense all other costs, such as property taxes and costs of forest management personnel, as incurred. Once the seedling plantation is viable, we expense all costs to maintain the viable plantations, such as fertilization, herbicide application, insect and wildlife control, and thinning, as incurred. We own directly or through ventures about 89,000 acres of non-core timberland and undeveloped land, primarily in Georgia. The non-cash cost of timber cut and sold is $250,000 in 2015 , $371,000 in 2014 and $609,000 in 2013 and is included in depreciation, depletion and amortization in our statement of cash flows.

Pending Accounting Pronouncemen

Pending Accounting Pronouncements	12 Months Ended
	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Pending Accounting Pronouncements	Pending Accounting Pronouncements Pending Accounting Standards In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , requiring an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The updated standard will replace most existing revenue recognition guidance in U.S. GAAP when it becomes effective and permits the use of either the retrospective or cumulative effect transition method. Early adoption is not permitted. The updated standard becomes effective for annual and interim periods beginning after December 15, 2016. In July 2015, the FASB decided to defer the effective date of the new standard by one year. This deferral results in the updated standard being effective after December 15, 2017. We have not yet selected a transition method and we are currently evaluating the effect that the updated standard will have on our earnings, financial position and disclosures. In January 2015, the FASB issued ASU 2015-01, Income Statement - Extraordinary and Unusual Items (Subtopic 225-20), which eliminates the concept of extraordinary items from U.S. GAAP. The updated standard is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015. Early adoption is permitted, provided that the guidance is applied from the beginning of the fiscal year of adoption. The adoption of this guidance is not expected to have an impact on our financial statements and related disclosures. In February 2015, the FASB issued ASU 2015-02, Consolidation: Amendments to the Consolidation Analysis (Topic 810) , requiring entities to evaluate whether they should consolidate certain legal entities. All legal entities are subject to reevaluation under the revised consolidation model. The revised consolidation model: (1) modifies the evaluation of whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities, (2) eliminates the presumption that a general partner should consolidate a limited partnership, (3) affects the consolidation analysis of reporting entities that are involved with VIEs, and (4) provides a scope exception from consolidation guidance for reporting entities with interests in certain legal entities. The updated standard is effective for financial statements issued for annual and interim periods beginning after December 15, 2015. Early adoption is permitted. The updated standard may be applied retrospectively or using a modified retrospective approach by recording a cumulative-effect adjustment to equity as of the beginning of the fiscal year of adoption. The adoption of this guidance is not expected to have an impact on our financial statements and related disclosures. In April 2015, the FASB issued ASU 2015-03, Interest – Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs, as part of its initiative to reduce complexity in accounting standards. To simplify presentation of debt issuance costs, the amendments in this update require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. In August 2015, the FASB issued ASU 2015-15, Interest-Imputation of Interest (Subtopic 835-30), Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements - Amendments to SEC Paragraphs Pursuant to Staff Announcement at June 18, 2015 EITF Meeting (SEC Update), which allows an entity to defer and present debt issuance costs as an asset and subsequently amortize the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. The updated standards are effective for financial statements issued for annual and interim periods beginning after December 15, 2015. The updated standards are not expected to materially impact our financial position or disclosures. In April 2015, the FASB issued ASU 2015-05, Customer's Accounting for Fees Paid in a Cloud Computing Arrangement (Subtopic 350-40), in order to provide clarification on whether a cloud computing arrangement includes a software license. If a software license is included, the customer should account for the license consistent with its accounting of other software licenses. If a software license is not included, the arrangement should be accounted for as a service contract. The update is effective for reporting periods beginning after December 15, 2015. Early adoption is permitted. We are currently evaluating the effect the updated standard will have on our financial position and disclosures. In June 2015, the FASB issued ASU 2015-10, Technical Corrections and Updates . The amendments in this update cover a wide range of topics in the codification and are generally categorized as follows: Amendments Related to Differences between Original Guidance and the Codification; Guidance Clarification and Reference Corrections; Simplification; and, Minor Improvements. The amendments are effective for fiscal years and interim periods within those fiscal years, beginning after December 15, 2015. Early adoption is permitted. The adoption of this standard is not expected to impact our financial position or results of operations. In November 2015, the FASB issued ASU 2015-17, Income Taxes - Balance Sheet Classification of Deferred Taxes (Subtopic 740). The ASU requires that deferred tax liabilities and assets be classified as noncurrent in a classified statement of financial position. The amendments in this update are effective for fiscal years and interim periods within those fiscal years beginning after December 15, 2016. We do not currently present a classified consolidated balance sheet and therefore this pronouncement will have no impact on our financial statements and related disclosures. 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.

Goodwill and Other Intangible A

Goodwill and Other Intangible Assets	12 Months Ended
	Dec. 31, 2015
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 2015 2014 (In thousands) Goodwill $ 61,164 $ 63,423 Identified intangibles, net 1,964 2,708 $ 63,128 $ 66,131 Goodwill related to oil and gas properties is $57,290,000 and $59,549,000 at year-end 2015 and 2014 . Goodwill associated with our water resources initiatives is $3,874,000 at year-end 2015 and 2014 . The change in goodwill for oil and gas properties is related to goodwill allocated to properties sold in 2015. Identified intangibles include $1,681,000 in indefinite lived groundwater leases associated with our water resources initiatives and $283,000 related to patents with definite lives associated with the Calliope Gas Recovery System, a process to increase natural gas production.

Real Estate

Real Estate	12 Months Ended
	Dec. 31, 2015
Real Estate [Abstract]
Real Estate	Real Estate Real estate consists of: Year-End 2015 Year-End 2014 Carrying Value Accumulated Depreciation Net Carrying Value Carrying Value Accumulated Depreciation Net Carrying Value (In thousands) Entitled, developed and under development projects $ 352,141 $ — $ 352,141 $ 321,273 $ — $ 321,273 Undeveloped land (includes land in entitlement) 98,181 — 98,181 93,182 — 93,182 Commercial Radisson Hotel & Suites 62,889 (29,268 ) 33,621 59,773 (29,062 ) 30,711 Harbor Lakes golf course and country club (a) — — — 2,054 (1,508 ) 546 Income producing properties Eleven 53,896 (2,861 ) 51,035 53,958 (576 ) 53,382 Midtown (a) — — — 33,293 (231 ) 33,062 Dillon 19,987 — 19,987 15,203 — 15,203 Music Row 9,947 — 9,947 7,675 — 7,675 Downtown Edge 12,706 — 12,706 11,856 — 11,856 West Austin 9,097 — 9,097 8,866 — 8,866 $ 618,844 $ (32,129 ) $ 586,715 $ 607,133 $ (31,377 ) $ 575,756 _________________________ (a) Sold in 2015. Our estimated cost of assets for which we expect to be reimbursed by utility and improvement districts were $67,554,000 at year-end 2015 and $65,212,000 at year-end 2014 , including $22,302,000 at year-end 2015 and $31,913,000 at year-end 2014 related to our Cibolo Canyons project near San Antonio. In 2015, we collected $14,751,000 in reimbursements that were previously submitted to these districts. At year-end 2015, our inception to-date submitted and approved reimbursements for the Cibolo Canyons project were $54,376,000 , of which we have collected $34,703,000 . These costs are principally for water, sewer and other infrastructure assets that we have incurred and submitted or will submit to utility or improvement districts for approval and reimbursement. We expect to be reimbursed by utility and improvement districts when these districts achieve adequate tax basis or otherwise have funds available to support payment. In 2014, we received $50,550,000 from Cibolo Canyons special improvement district (CCSID) under 2007 economic development agreements (EDA) related to development of the JW Marriott ® Hill Country Resort & Spa (Resort) at our Cibolo Canyons project near San Antonio, of which $46,500,000 was related to CCSID's issuance of $48,900,000 Hotel Occupancy Tax (HOT) and Sales and Use Tax Revenue Bonds. These bonds are obligations solely of CCSID and are payable from HOT and sales and use taxes levied on the Resort by CCSID. To facilitate the issuance of the bonds, we provided a $6,846,000 letter of credit to the bond trustee as security for certain debt service fund obligations in the event CCSID tax collections are not sufficient to support payment of the bonds in accordance with their terms. The letter of credit must be maintained until the earlier of redemption of the bonds or scheduled bond maturity in 2034. We also entered into an agreement with San Antonio Real Estate (SARE), owner of the Resort, to assign SARE’s senior rights under the EDA 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 to SARE. The surety bond will decrease and gain will be recognized as CCSID makes annual ad valorem tax rebate payments to SARE, which obligation is scheduled to be retired in full by 2020. All future receipts are expected to be recognized as gain in the period collected. We recorded gains of $1,160,000 associated with reduction of surety bond and $425,000 associated with collections from CCSID in 2015. In 2014, we recognized a gain of $6,577,000 associated with bond proceeds after recovery of our full resort investment of $24,067,000 , which was included in entitled, developed and under development projects. The surety bond has a balance of $7,850,000 at year-end 2015. In 2015, we sold Midtown Cedar Hill, a 354 -unit multifamily property we developed in Cedar, Hill, Texas for $42,880,000 , generating segment earnings of $9,265,000 and $18,473,000 in net proceeds after repaying $24,166,000 in outstanding debt. In 2014, we acquired full ownership in CJUF III, RH Holdings LP partnership (the Eleven venture), owner of a 257 -unit multifamily project in Austin in which we previously held a 25 percent interest, for $21,500,000 . The acquisition-date fair value was $55,275,000 , including debt of $23,936,000 . Our investment in the Eleven venture prior to acquiring our partner’s interest was $2,229,000 . We accounted for this transaction as a business combination achieved in stages and as a result, we remeasured our equity method investment in the Eleven venture to its acquisition-date fair value of $9,839,000 and recognized the resulting gain of $7,610,000 in real estate segment earnings. At acquisition, we recorded additions to commercial and income producing properties of $53,917,000 and other assets of $992,000 primarily consisting of the estimated fair value of in-place tenant leases of $865,000 . In addition, we recorded a working capital deficit of $979,000 and debt of $23,936,000 . As a general contractor on guaranteed maximum price contracts associated with two multifamily venture properties, we recognized charges of $1,543,000 in 2015 , $5,111,000 in 2014 and $554,000 in 2013 related to cost overruns. Depreciation expense related to commercial and income producing properties was $6,810,000 in 2015 , $3,319,000 in 2014 and $2,507,000 in 2013 and is included in other operating expense.

Oil and Gas Properties and Equi

Oil and Gas Properties and Equipment, net (Notes)	12 Months Ended
	Dec. 31, 2015
Oil and Gas Properties [Abstract]
Oil and Gas Properties and Equipment, net	Oil and Gas Properties and Equipment, net Net capitalized costs, utilizing the successful efforts method of accounting, related to our oil and gas producing activities are as follows: At Year-End 2015 2014 (In thousands) Unproved leasehold interests $ 19,441 $ 90,446 Proved oil and gas properties 119,414 221,299 Total costs 138,855 311,745 Less accumulated depreciation, depletion and amortization (58,242 ) (48,252 ) $ 80,613 $ 263,493 We review unproved oil and gas properties for impairment based on our current exploration plans and proved oil and gas properties by comparing the expected undiscounted future cash flows at a producing field level to the unamortized capitalized cost of the asset. In 2015, we recognized $164,831,000 in non-cash impairment charges of which $107,140,000 related to our proved properties and $57,691,000 on our unproved leasehold interests principally due to a significant decline in oil prices, drilling results, a change in our plans to develop acreage and increased likelihood that non-core oil and gas assets will be sold. In 2014 , we recognized $32,665,000 in non-cash impairment charges of which $17,130,000 related to our unproved leasehold interests and $15,535,000 on our proved properties principally due to the significant decline in oil prices, drilling results, a change in our plans to develop acreage and increased likelihood that non-core oil and gas assets will be sold. Impairment charges are included in cost of oil and gas producing activities on our consolidated statements of income (loss) and comprehensive income (loss). 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 sales proceeds of $17,800,000 .

Investment in Unconsolidated Ve

Investment in Unconsolidated Ventures	12 Months Ended
	Dec. 31, 2015
Equity Method Investments and Joint Ventures [Abstract]
Investment in Unconsolidated Ventures	Investment in Unconsolidated Ventures At year-end 2015 , we had ownership interests in 20 ventures that we account for using the equity method. 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 2015 2014 2015 2014 2015 2014 2015 2014 (In thousands) 242, LLC (b) $ 26,687 $ 33,021 $ — $ 6,940 $ 24,877 $ 21,789 $ 11,766 $ 10,098 CL Ashton Woods, LP (d) 7,654 13,269 — — 6,084 11,453 3,615 6,015 CL Realty, LLC 7,872 7,960 — — 7,662 7,738 3,831 3,869 CREA FMF Nashville LLC (b) 58,002 40,014 51,028 29,660 4,291 5,987 3,820 5,516 Elan 99, LLC 34,327 10,070 14,721 1 15,838 9,643 14,255 8,679 FMF Littleton LLC 52,528 26,953 22,499 — 24,370 24,435 6,270 6,287 FMF Peakview LLC 48,908 43,638 30,524 23,070 16,828 17,464 3,447 3,575 FOR/SR Forsyth LLC 6,500 — — — 6,500 — 5,850 — HM Stonewall Estates, Ltd. (d) 2,842 3,750 — 669 2,842 3,081 1,294 1,752 LM Land Holdings, LP (d) 32,008 25,561 7,752 4,448 22,751 18,500 9,664 9,322 MRECV DT Holdings LLC 4,215 — — — 4,215 — 3,807 — MRECV Edelweiss LLC 2,237 — — — 2,237 — 2,029 — MRECV Juniper Ridge 3,006 — — — 3,006 — 2,730 — MRECV Meadow Crossing II LLC 728 — — — 728 — 655 — Miramonte Boulder Pass, LLC 12,627 — 5,869 — 5,474 — 5,349 — PSW Communities, LP — 16,045 — 10,515 — 4,415 — 3,924 TEMCO Associates, LLC 5,284 11,756 — — 5,113 11,556 2,557 5,778 Other ventures (e) 4,201 8,453 2,269 26,944 1,922 (25,614 ) 1,514 190 $ 309,626 $ 240,490 $ 134,662 $ 102,247 $ 154,738 $ 110,447 $ 82,453 $ 65,005 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 2015 2014 2013 2015 2014 2013 2015 2014 2013 (In thousands) 242, LLC (b) $ 20,995 $ 5,612 $ 6,269 $ 9,588 $ 2,951 $ 1,512 $ 4,919 $ 1,514 $ 805 CJUF III, RH Holdings (c) — 2,168 120 — (956 ) (652 ) — (956 ) (652 ) CL Ashton Woods, LP (d) 9,820 5,431 9,018 3,881 1,748 2,660 5,000 2,471 4,169 CL Realty, LLC 856 1,573 1,603 424 1,068 1,028 212 534 514 CREA FMF Nashville LLC (b) 1,227 — — (1,696 ) (163 ) — (1,696 ) (163 ) — Elan 99, LLC — — — (49 ) (87 ) — (44 ) (78 ) — FMF Littleton LLC 120 — — (367 ) (239 ) — (92 ) (60 ) — FMF Peakview LLC 2,057 4 1 (1,116 ) (410 ) (252 ) (223 ) (83 ) (50 ) FOR/SR Forsyth LLC — — — — — — — — — HM Stonewall Estates, Ltd. (d) 3,990 1,728 2,922 1,881 613 1,082 952 248 452 LM Land Holdings, LP (d) 10,956 21,980 25,426 8,251 15,520 11,012 3,342 4,827 3,418 MRECV DT Holdings LLC — — — 167 — — — — — MRECV Edelweiss LLC — — — 151 — — 137 — — MRECV Juniper Ridge — — — 106 — — — — — Miramonte Boulder Pass, LLC — — — (250 ) — — (125 ) — — PSW Communities, LP 29,986 — — 2,688 (86 ) — 1,169 (76 ) — TEMCO Associates, LLC 9,485 2,155 630 2,358 494 96 1,179 247 48 Other ventures 36,237 1,792 5,994 33,303 4,835 176 1,278 260 33 $ 125,729 $ 42,443 $ 51,983 $ 59,320 $ 25,288 $ 16,662 $ 16,008 $ 8,685 $ 8,737 _____________________ (a) Total includes current maturities of $39,590,000 at year-end 2015 , of which $6,798,000 is non-recourse to us, and $65,795,000 at year-end 2014 , of which $42,566,000 is non-recourse to us. (b) Includes unamortized deferred gains on real estate contributed by us to ventures. We recognize deferred gains as income as real estate is sold to third parties. Deferred gains of $1,496,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2015 . (c) In 2014, we acquired full ownership in the Eleven venture for $21,500,000 . The acquisition-date fair value was $55,275,000 , including debt of $23,936,000 . Our investment in the Eleven venture prior to acquiring our partner’s interest was $2,229,000 . (d) Includes unrecognized basis difference of $34,000 which is reflected as a reduction of our investment in unconsolidated ventures at year-end 2015 . This difference between estimated fair value of the equity investment and our capital account within the respective ventures at closing will be accreted as income or expense over the life of the investment and included in our share of earnings (loss) from the respective ventures. (e) Our investment in other ventures reflects our ownership interests generally ranging from 40 to 75 percent , excluding venture losses that exceed our investment where we are not obligated to fund those losses. Please read Note 16 — Variable Interest Entities for additional information. In 2015 , we invested $26,349,000 in these ventures and received $24,909,000 in distributions; in 2014 , we invested $14,692,000 in these ventures and received $7,518,000 in distributions; and in 2013 , we invested $857,000 in these ventures and received $9,854,000 in distributions. Distributions include both return of investments and distributions of earnings. We provide construction and development services for some of these ventures for which we receive fees. Fees for these services were $1,856,000 in 2015 , $2,275,000 in 2014 and $1,068,000 in 2013 and are included in real estate revenues.

Receivables

Receivables	12 Months Ended
	Dec. 31, 2015
Receivables [Abstract]
Receivables	Receivables Receivables consist of: At Year-End 2015 2014 (In thousands) Funds held by qualified intermediary for potential 1031 like-kind exchange $ 14,703 $ — Oil and gas revenue accruals 3,745 7,293 Other receivables and accrued interest 2,448 6,505 Other loans secured by real estate, average interest rate of 11.31% at year-end 2015 and 4.41% at year-end 2014 2,130 1,737 Oil and gas joint interest billing receivables 867 5,738 Loan secured by real estate — 3,574 23,893 24,847 Allowance for bad debts (237 ) (258 ) $ 23,656 $ 24,589 In 2015, funds held by qualified intermediary are related to proceeds received from selling 6,915 acres of undeveloped land pending completion of a potential like-kind exchange. In 2011, we acquired a non-performing loan that was secured by a lien on developed and undeveloped real estate located near Houston designated for single-family residential and commercial development. In 2015, the loan was paid in full and we received principal payments of $4,394,000 and interest payments of $49,000 . Estimated accretable yield is as follows: At Year-End 2015 2014 (In thousands) Beginning of year $ 839 $ 8,908 Change in accretable yield due to change in timing of estimated cash flows 30 (166 ) Interest income recognized (869 ) (7,903 ) $ — $ 839 Other loans secured by real estate generally are secured by a deed of trust and due within three years .

Debt

Debt	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Debt	Debt Debt consists of: At Year-End 2015 2014 (In thousands) 8.50% senior secured notes due 2022 230,560 250,000 3.75% convertible senior notes due 2020, net of discount 106,762 103,194 6.00% tangible equity units, net of discount 8,768 17,154 Secured promissory notes — average interest rates of 3.42% at year-end 2015 and 3.17% at year-end 2014 15,400 15,400 Other indebtedness due through 2018 at variable and fixed interest rates ranging from 2.19% to 5.50% 28,292 46,996 $ 389,782 $ 432,744 At year-end 2015 , our senior secured credit facility provides for a $300,000,000 revolving line of credit maturing May 15, 2017 . The revolving line of credit may be prepaid at any time without penalty. The revolving line of credit includes a $100,000,000 sublimit for letters of credit, of which $15,899,000 is outstanding at year-end 2015 . Total borrowings under our senior secured credit facility (including the face amount of letters of credit) may not exceed a borrowing base formula. At year-end 2015 , we had $284,101,000 in net unused borrowing capacity under our senior credit facility. Under the terms of our senior secured credit facility, at our option, we can borrow at LIBOR plus 4.0 percent or at the alternate base rate plus 3.0 percent . The alternate base rate is the highest of (i) KeyBank National Association’s base rate, (ii) the federal funds effective rate plus 0.5 percent or (iii) 30 day LIBOR plus 1 percent . Borrowings under the senior secured credit facility are or may be secured by (a) mortgages on the timberland, high value timberland and portions of raw entitled land, as well as pledges of other rights including certain oil and gas operating properties, (b) assignments of current and future leases, rents and contracts, (c) a security interest in our primary operating account, (d) a pledge of the equity interests in current and future material operating subsidiaries and most of our majority-owned joint venture interests, or if such pledge is not permitted, a pledge of the right to distributions from such entities, and (e) a pledge of certain reimbursements payable to us from special improvement district tax collections in connection with our Cibolo Canyons project. The senior secured credit facility provides for releases of real estate and other collateral provided that borrowing base compliance is maintained. Our debt agreements contain financial covenants customary for such agreements including minimum levels of interest coverage and limitations on leverage. In third quarter 2015, we received a waiver of the consolidated tangible net worth maintenance covenant requirement of our senior credit facility. At year-end 2015, our tangible net worth requirement was $379,044,000 plus 85 percent of the aggregate net proceeds received by us from any equity offering, plus 75 percent of all positive net income, on a cumulative basis. At year-end 2015, there were no adjustments to the tangible net worth requirement for net proceeds from equity offerings or positive net income on a cumulative basis. The tangible net worth requirement is recalculated on a quarterly basis. On December 30, 2015, we amended our senior secured credit facility to reduce the interest coverage ratio from 2.50 :1.0 to 2.25 :1.0 for the quarters ending December 31, 2015 and March 31, 2016. Thereafter, the interest coverage ratio returns to 2.50 :1.0. At year-end 2015 , we were in compliance with the financial covenants of these agreements. We may elect to make distributions to stockholders so long as the total leverage ratio is less than 40 percent , the interest coverage ratio is greater than 3.0 :1.0 and available liquidity is not less than $125,000,000 . Effective December 30, 2015, the senior secured credit facility was amended to provide that we may make distributions in an aggregate amount not to exceed $50,000,000 to be funded from up to 65% of the net proceeds from sales of multifamily properties and non-core assets, such as the Radisson Hotel & Suites in Austin, and any oil and gas properties. The amendment provides us the flexibility to repurchase stock or pay a special dividend should our Board of Directors determine that we should do so, though no such decisions have been made at this time. In 2014, we issued $250,000,000 aggregate principal of 8.50% Senior Secured Notes due 2022 (Notes). The Notes will mature on June 1, 2022 and interest on the Notes is payable semiannually at a rate of 8.5 percent per annum in arrears. Net proceeds from issuance of the Notes were used to repay our $200,000,000 senior secured term loan. In December 2015, we purchased $19,440,000 principal amount of Notes at 97% of face value, resulting in a gain of $589,000 on the early extinguishment of the retired Notes, offset by the write-off of unamortized debt issuance costs of $506,000 allocated to the retired Notes. In 2013, we issued $125,000,000 aggregate principal amount of 3.75% convertible senior notes due 2020 (Convertible Notes). Interest on the Convertible Notes is payable semiannually at a rate of 3.75 percent per annum and they mature on March 1, 2020 . The Convertible Notes have an initial conversion rate of 40.8351 per $1,000 principal amount. The initial conversion rate is subject to adjustment upon the occurrence of certain events. Prior to November 1, 2019, the Convertible Notes are convertible only upon certain circumstances, and thereafter are convertible at any time prior to the close of business on the second scheduled trading day prior to maturity. If converted, holders will receive cash, shares of our common stock or a combination thereof at our election. We intend to settle the principal amount of the Convertible Notes in cash upon conversion, with any excess conversion value to be settled in shares of our common stock. At year-end 2015 , unamortized debt discount of our Convertible Notes was $18,238,000 . In 2013, we issued $150,000,000 aggregate principal amount of 6.00% tangible equity units (Units). The total offering was 6,000,000 Units, including 600,000 exercised by the underwriters, each with a stated amount of $25.00 . Each Unit is comprised of (i) a prepaid stock purchase contract to be settled by delivery of a number of shares of our common stock, par value $1.00 per share to be determined pursuant to a purchase contract agreement, and (ii) a senior amortizing note due December 15, 2016 that has an initial principal amount of $4.2522 , bears interest at a rate of 4.50% per annum and has a final installment payment date of December 15, 2016. The actual number of shares we may issue upon settlement of the stock purchase contract will be between 6,547,800 shares (the minimum settlement rate) and 7,857,000 shares (the maximum settlement rate) based on the applicable market value, as defined in the purchase contract agreement associated with issuance of the Units. At year-end 2015 , secured promissory notes include a $15,400,000 loan collateralized by a 413 guest room hotel located in Austin with a carrying value of $33,621,000 . At year-end 2015 , other indebtedness principally include a senior secured construction loan for one multifamily property for $23,936,000 related to a 257 -unit multifamily project in Austin with a carrying value of $51,035,000 at year-end 2015 . The decrease in other indebtedness is principally related to the sale of Midtown Cedar Hill and the payoff of the related debt of $24,166,000 . At year-end 2015 and 2014 , we have $11,034,000 and $15,168,000 in unamortized deferred fees which are included in other assets. Amortization of deferred financing fees was $4,002,000 in 2015 , $3,845,000 in 2014 and $3,050,000 in 2013 and is included in interest expense. Debt maturities during the next five years are: 2016 — $27,973,000 ; 2017 — $551,000 ; 2018 — $23,936,000 ; 2019 — $0 ; 2020 — $106,762,000 and thereafter — $230,560,000 .

Fair Value

Fair Value	12 Months Ended
	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value	Fair Value Fair value is the exchange price that would be the amount received for an asset or paid to transfer a liability in an orderly transaction between market participants. In arriving at a fair value measurement, we use a fair value hierarchy based on three levels of inputs, of which the first two are considered observable and the last unobservable. The three levels of inputs used to establish fair value are the following: • Level 1 — Quoted prices in active markets for identical assets or liabilities; • Level 2 — Inputs other than Level 1 that are observable, either directly or indirectly, such as quoted prices for similar assets or liabilities; quoted prices in markets that are not active; or other inputs that are observable or can be corroborated by observable market data for substantially the full term of the assets or liabilities; and • Level 3 — Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. We elected not to use the fair value option for cash and cash equivalents, accounts receivable, other current assets, variable debt, accounts payable and other current liabilities. The carrying amounts of these financial instruments approximate their fair values due to their short-term nature or variable interest rates. We determine the fair value of fixed rate financial instruments using quoted prices for similar instruments in active markets. Information about our fixed rate financial instruments not measured at fair value follows: Year-End 2015 Year-End 2014 Carrying Amount Fair Value Carrying Amount Fair Value Valuation Technique (In thousands) Recurring Fair Value Measurements: Loan secured by real estate $ — $ — $ 3,574 $ 4,859 Level 2 Fixed rate debt $ (346,090 ) $ (321,653 ) $ (370,348 ) $ (359,131 ) Level 2 Non-financial assets measured at fair value on a non-recurring basis principally include real estate assets, proved oil and gas properties, goodwill and intangible assets, which are measured for impairment. In 2015, we recognized proved properties oil and gas non-cash impairment charges of $107,140,000 primarily in North Dakota, Nebraska and Kansas principally due to a significant decline in oil and gas prices and the likelihood these assets will be sold. The fair value of these properties was determined using Level 3 inputs and income valuation method based on estimated future commodity prices and our various operational assumptions. In instances where a third party bid was received for a combination of proved and unproved properties, an estimate of the allocation of bid prices was performed and fair value was adjusted accordingly. Included in proved oil and gas non-cash impairments were impairments associated with properties that were sold in fourth quarter 2015. In addition, in 2015 we recognized impairments of $57,691,000 for unproved leasehold interests as a result of continued decline in oil prices and our current plans to only allocate capital to these non-core assets to preserve values and optionality for ultimate sale. Fair value of certain unproved leasehold interests that were impaired were based on market comparables or where a third party bid was received for a combination of proved and unproved properties, an estimate of the allocation of fair value was performed which reduced the carrying value of these leasehold interests. In 2015 and 2014, certain real estate assets were remeasured and reported at fair value due to events or circumstances that indicated the carrying value may not be recoverable. We determined estimated fair value based on the present value of future probability weighted cash flows expected from the sale of the long-lived asset or based on a third party appraisal of current value. As a result, we recognized non-cash asset impairment charges of $1,044,000 in 2015 associated with a residential development with golf course and country club property near Fort Worth which was sold in April 2015, one owned project near Atlanta where the remaining lots were sold in August 2015 and one owned entitled project in Atlanta. We had $399,000 non-cash impairment charges in 2014 associated with two owned entitled projects. Year-End 2015 Year-End 2014 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (In thousands) Non-recurring Fair Value Measurements: Proved oil and gas properties $ — $ — $ 39,000 $ 39,000 $ — $ — $ 3,655 $ 3,655 Unproved leasehold interests $ — $ — $ 18,219 $ 18,219 $ — $ — $ — $ — Real estate $ — $ — $ 641 $ 641 $ — $ — $ 970 $ 970

Capital Stock

Capital Stock	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Capital Stock	Capital Stock In 2015, we accelerated the expiration date of our shareholder rights plan from December 11, 2017 to March 13, 2015, resulting in termination of the plan. Please read Note 8 — Debt and Note 11 — Net Income (Loss) per Share for information about shares of common stock that could be issued under our 3.75% convertible senior notes due 2020 and our 6.00% tangible equity units. Please read Note 17 — Share-Based and Long-Term Incentive Compensation for information about additional shares of common stock that could be issued under terms of our share-based compensation plans. At year-end 2015 , personnel of former affiliates held options to purchase 500,798 shares of our common stock. The options have a weighted average exercise price of $28.62 and a weighted average remaining contractual term of one year . At year-end 2015 , the options have an aggregate intrinsic value of $0 . In 2015 , we did not repurchase shares of our common stock. In 2014 , we repurchased 1,491,187 shares of our common stock for $24,595,000 . We have repurchased 3,493,332 shares of our common stock for $54,159,000 since we announced our 2009 strategic initiative of repurchasing up to 20 percent or up to 7,000,000 shares of our common stock.

Net Income per Share

Net Income per Share	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
Net Income (Loss) per Share	Net Income (Loss) per Share Basic and diluted earnings (loss) per share are computed using the two-class method. The two-class method is an earnings allocation formula that determines net income per share for each class of common stock and participating security. We have determined that our 6.00% tangible equity units are participating securities. Per share amounts are computed by dividing earnings available to common shareholders by the weighted average shares outstanding during each period. The computations of basic and diluted earnings (loss) per share are as follows: For the Year 2015 2014 2013 (In thousands) Numerator: Consolidated net income (loss) $ (212,371 ) $ 17,088 $ 35,061 Less: Net (income) attributable to noncontrolling interest (676 ) (505 ) (5,740 ) Income (loss) available for diluted earnings per share $ (213,047 ) $ 16,583 $ 29,321 Less: Undistributed net income allocated to participating securities — (3,018 ) (585 ) Income (loss) available to common shareholders for basic earnings per share $ (213,047 ) $ 13,565 $ 28,736 Denominator: Weighted average common shares outstanding — basic 34,266 35,317 35,365 Weighted average common shares upon conversion of participating securities (a) — 7,857 835 Dilutive effect of stock options, restricted stock and equity-settled awards — 422 613 Total weighted average shares outstanding — diluted 34,266 43,596 36,813 Anti-dilutive awards excluded from diluted weighted average shares outstanding 10,864 2,238 1,803 _____________________ (a) Our earnings per share calculation reflects the weighted average shares issuable upon settlement of the prepaid stock purchase contract component of our 6.00% tangible equity units, issued in 2013. The actual number of shares we may issue upon settlement of the stock purchase contract will be between 6,547,800 shares (the minimum settlement rate) and 7,857,000 shares (the maximum settlement rate) based on the applicable market value, as defined in the purchase contract agreement associated with issuance of the Units. We intend to settle the principal amount of the Convertible Notes in cash upon conversion with any excess conversion value to be settled in shares of our common stock. Therefore, only the amount in excess of the par value of the Convertible Notes will be included in our calculation of diluted net income per share using the treasury stock method. As such, the Convertible Notes have no impact on diluted net income per share until the price of our common stock exceeds the conversion price of the Convertible Notes of $24.49 . The average price of our common stock in 2015 did not exceed the conversion price which resulted in no additional diluted outstanding shares.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes Income tax (expense) benefit consists of: For the Year 2015 2014 2013 (In thousands) Current tax provision: U.S. Federal $ 8,579 $ (5,444 ) $ (6,004 ) State and other 47 (1,569 ) (2,066 ) 8,626 (7,013 ) (8,070 ) Deferred tax provision: U.S. Federal (38,366 ) (2,772 ) 1,148 State and other (2,895 ) 1,128 (286 ) (41,261 ) (1,644 ) 862 Income tax (expense) benefit $ (32,635 ) $ (8,657 ) $ (7,208 ) A reconciliation of the federal statutory rate to the effective income tax rate on continuing operations follows: For the Year 2015 2014 2013 Federal statutory rate (benefit) (35 %) 35 % 35 % State, net of federal benefit (1 ) 1 4 Valuation allowance 54 — — Recognition of previously unrecognized tax benefits — — (15 ) Noncontrolling interests — — (5 ) Goodwill — 1 — Charitable contributions — (1 ) — Oil and gas percentage depletion — (2 ) (2 ) Effective tax rate 18 % 34 % 17 % Our 2015 effective tax rate includes a 54 percent detriment from a valuation allowance recorded against our deferred tax asset and our 2013 effective tax rate includes a 15 percent benefit from recognition of $6,326,000 of previously unrecognized tax benefits upon lapse of the statute of limitations for a previously reserved tax position. Significant components of deferred taxes are: At Year-End 2015 2014 (In thousands) Deferred Tax Assets: Real estate $ 69,594 $ 79,244 Employee benefits 15,752 17,352 Net operating loss carryforwards 13,827 3,012 Oil and gas properties 5,510 — AMT credits 3,620 — Income producing properties — 364 Oil and gas percentage depletion carryforwards 3,616 3,471 Accruals not deductible until paid 911 1,111 Other assets 139 — Gross deferred tax assets 112,969 104,554 Valuation allowance (97,068 ) (384 ) Deferred tax asset net of valuation allowance 15,901 104,170 Deferred Tax Liabilities: Oil and gas properties — (49,905 ) Undeveloped land (7,588 ) (4,937 ) Convertible debt (6,516 ) (7,816 ) Income producing properties (2,257 ) — Timber (577 ) (888 ) Gross deferred tax liabilities (16,938 ) (63,546 ) Net Deferred Tax Asset (Liability) $ (1,037 ) $ 40,624 At year-end 2015, we had approximately $37,500,000 and $43,900,000 of federal and state net operating loss carryforwards. Approximately $7,500,000 of the federal and $2,400,000 of the state net operating loss carryforwards were from our acquisition of Credo at third quarter 2012 and are subject to certain limitations. If not utilized, the federal carryforwards will expire in 2035 and the state carryforwards will expire in 2016 to 2035 . We had approximately $9,800,000 of oil and gas percentage depletion carryforwards of which approximately $9,200,000 were a result of our acquisition of Credo and are subject to certain limitations. The percentage depletion and AMT credit carryforwards do not expire. Our deferred tax asset on oil and gas properties includes the effect of impairments recorded in 2015. Goodwill associated with our acquistion of Credo is not deductible for income tax purposes. The increase in valuation allowance for the year 2015 was principally due to oil and gas impairments. 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, 2015, principally driven by impairments of oil and gas properties. Such evidence limited our ability to consider other subjective evidence, such as our projected future taxable income. The amount of deferred tax asset considered realizable could be adjusted if negative evidence in the form of cumulative losses is no longer present and additional weight is given to subjective evidence, such as our projected future taxable income. We file income tax returns in the U.S. federal jurisdiction and in various state jurisdictions. We are no longer subject to U.S. federal income tax examinations for years before 2012 and state examinations for years before 2011. A reconciliation of the beginning and ending amount of tax benefits not recognized for book purposes is as follows: At Year-End 2015 2014 2013 (In thousands) Balance at beginning of year $ — $ — $ 5,831 Reductions for tax positions of prior years — — — Reductions due to lapse of statute of limitations — — (5,831 ) Balance at end of year that would affect the annual effective tax rate if recognized $ — $ — $ — We recognize interest accrued related to unrecognized tax benefits in income tax expense. In 2015 , 2014 and 2013 , we recognized approximately $0 , $0 and $75,000 in interest expense. At year-end 2015 and 2014 , we have no accrued interest or penalties.

Litigation and Environmental Co

Litigation and Environmental Contingencies	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Litigation and Environmental Contingencies	Litigation and Environmental Contingencies Litigation We are involved in various legal proceedings that arise from time to time in the ordinary course of doing business and believe that adequate reserves have been established for any probable losses. We do not believe that the outcome of any of these proceedings should have a significant adverse effect on our financial position, long-term results of operations or cash flows. It is possible, however, that charges related to these matters could be significant to our results or cash flows in any one accounting period. On October 4, 2014, James Huffman, a former director and CEO of CREDO Petroleum Corporation (Credo), which we acquired in 2012 and is now known as Forestar Petroleum Corporation, filed Huffman vs. Forestar Petroleum Corporation , Case Number 14CV33811, Civil Division, District Court for the City and County of Denver, Colorado. Prior to his retirement from Credo, Huffman participated in an employee compensation program under which he received overriding royalty interests (ORRI) in certain leases or wells in which Credo had an interest. Huffman claims entitlement to ORRI on nearly all North Dakota leases, none of which were assigned by Credo to Huffman prior to his retirement, and to ORRI on several Kansas and Nebraska leases. Huffman is seeking to have ORRI assigned to him. We believe Huffman’s claims are without merit and are vigorously defending the case. We are unable to estimate a possible loss or range of possible loss for this matter because of, among other factors, (i) significant unresolved questions of fact, including the time period covered by Huffman’s claims, (ii) discovery remaining to be conducted by both parties; (iii) impact of our counterclaims against Huffman, and (iv) any other factors that may have a material effect on the litigation. 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. We own 288 acres near Antioch, California, portions of which were sites of a former paper manufacturing operation that are in remediation. We have received certificates of completion on all but one 80 acre tract, a portion of which includes subsurface contamination. In 2015, we increased our reserves for environmental remediation by $689,000 due to additional testing and remediation requirements by state regulatory agencies. At year-end 2015, our accrued liability to complete remediation activities was $682,000 , which is included in other accrued expenses. It is possible that remediation or monitoring activities could be required in addition to those included within our estimate, but we are unable to determine the scope, timing or extent of such activities. We have asset retirement obligations related to the abandonment and site restoration requirements that result from the acquisition, construction and development of oil and gas properties. We record the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. Accretion expense related to the asset retirement obligation and depletion expense related to capitalized asset retirement cost is included in cost of oil and gas producing activities on our consolidated statements of income (loss) and comprehensive income (loss). At year-end 2015 , our asset retirement obligation was $1,758,000 , which is included in other liabilities.

Commitments and Other Contingen

Commitments and Other Contingencies	12 Months Ended
	Dec. 31, 2015
Leases [Abstract]
Commitments and Other Contingencies	Commitments and Other Contingencies We lease facilities and equipment under non-cancelable long-term operating lease agreements. In addition, we have various obligations under other office space and equipment leases of less than one year. Rent expense on facilities and equipment was $3,872,000 in 2015 , $2,617,000 in 2014 and $2,374,000 in 2013 . Future minimum rental commitments under non-cancelable operating leases having a remaining term in excess of one year are: 2016 — $2,696,000 ; 2017 — $2,738,000 ; 2018 — $1,706,000 ; 2019 — $170,000 ; 2020 — $174,000 and thereafter — $59,000 . We have two years remaining on groundwater leases of about 20,000 acres. At year-end 2015 , the remaining contractual obligation for these groundwater leases is $1,009,000 . We lease approximately 32,000 square feet of office space in Austin, Texas, which we occupy as our corporate headquarters. The remaining contractual obligation for this lease is $4,212,000 . We also lease office space in several other locations in support of our business operations with approximately 21,000 square feet in Denver, Colorado. The total remaining contractual obligations for these leases is $2,269,000 . We may provide performance bonds and letters of credit on behalf of certain ventures that would be drawn on due to failure to satisfy construction obligations as general contractor or for failure to timely deliver streets and utilities in accordance with local codes and ordinances. Unallocated Severance-related Costs In connection with the departures of our former CEO and CFO in September 2015, we recorded severance-related charges of $3,314,000 which are included in general and administrative expense on our consolidated statements of income (loss) and comprehensive income (loss). We paid $2,732,000 of these severance-related charges in fourth quarter 2015 with the balance to be paid in 2016. Oil and Gas Restructuring Costs In connection with review of strategic alternatives with respect to our oil and gas business and the determination it is a non-core business that we will be exiting over time, we offered retention bonuses to key personnel provided they remained our employees through December 2015 . We expensed retention bonus costs over the retention period. In 2015, we incurred severance expenses related to staff reductions, paid a portion of the 2014 accrual under written severance agreements and incurred costs associated with closure of our Fort Worth office. Office closure costs include a $1,750,000 lease termination charge and $391,000 for write off of leasehold improvements which were partially offset by a deferred lease credit of $364,000 . These restructuring costs are included in other operating expense on our consolidated statements of income (loss) and comprehensive income (loss). We may incur additional costs related to our initiatives to exit non-core oil and gas assets. The following table summarizes activity related to liabilities associated with our oil and gas restructuring activities in 2015: Employee-Related Costs Lease Termination Charge Total (In thousands) Balance at year-end 2014 $ (2,367 ) $ — $ (2,367 ) Additions (2,047 ) (1,750 ) (3,797 ) Payments 3,365 1,750 5,115 Balance at year-end 2015 $ (1,049 ) $ — $ (1,049 )

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2015
Segment Reporting [Abstract]
Segment Information	Segment Information We manage our operations through three business segments: real estate, oil and gas and other natural resources. 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, primarily a hotel and our multifamily properties. Oil and gas is an independent oil and gas exploration, development and production operation and manages our owned and leased mineral interests. Other natural resources manages our timber, recreational leases and water resource initiatives. 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 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 2015 , 2014 and 2013 , no single customer accounted for more than 10 percent of our total revenues, other than the customers associated with the sale of our multifamily projects Midtown Cedar Hill and Promesa in 2015 and 2013. Real Estate Oil and Gas Other Natural Resources Items Not Allocated to Segments Total (In thousands) For the year or at year-end 2015 Revenues $ 202,830 $ 52,939 $ 6,652 $ — $ 262,421 Depreciation, depletion and amortization 7,605 28,774 540 8,166 45,085 Equity in earnings of unconsolidated ventures 15,582 275 151 — 16,008 Income (loss) before taxes 67,678 (184,396 ) (608 ) (63,086 ) (a) (180,412 ) Total assets 691,406 144,436 19,106 125,565 980,513 Investment in unconsolidated ventures 82,453 — — — 82,453 Capital expenditures (b) 13,644 49,776 745 242 64,407 For the year or at year-end 2014 Revenues $ 213,112 $ 84,300 $ 9,362 $ — $ 306,774 Depreciation, depletion and amortization 3,741 29,442 497 8,035 41,715 Equity in earnings of unconsolidated ventures 8,068 586 31 — 8,685 Income (loss) before taxes 96,906 (22,686 ) 5,499 (54,479 ) (a) 25,240 Total assets 654,774 342,703 22,531 238,191 1,258,199 Investment in unconsolidated ventures 65,005 — — — 65,005 Capital expenditures (b) 28,980 103,385 5,817 616 138,798 For the year or at year-end 2013 Revenues $ 248,011 $ 72,313 $ 10,721 $ — $ 331,045 Depreciation, depletion and amortization 3,117 19,552 651 6,660 29,980 Equity in earnings of unconsolidated ventures 8,089 592 56 — 8,737 Income (loss) before taxes 68,454 18,859 6,507 (57,291 ) (a) 36,529 Total assets 582,802 312,553 23,478 253,319 1,172,152 Investment in unconsolidated ventures 41,147 — — — 41,147 Capital expenditures (b) 7,265 97,696 2,720 216 107,897 _____________________ (a) Items not allocated to segments consist of: For the Year 2015 2014 2013 (In thousands) General and administrative expense $ (24,802 ) $ (21,229 ) $ (20,597 ) Share-based and long-term incentive compensation expense (4,474 ) (3,417 ) (16,809 ) Interest expense (34,066 ) (30,286 ) (20,004 ) Other corporate non-operating income 256 453 119 $ (63,086 ) $ (54,479 ) $ (57,291 ) (b) Consists of expenditures for oil and gas properties and equipment, commercial and income producing properties, property, plant and equipment and reforestation of timber.

Variable Interest Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Variable Interest Entities	Variable Interest Entities 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. Generally accepted accounting principles require consolidation of 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 we are the primary beneficiary and must consolidate a VIE. We perform this review initially at the time we enter into venture agreements and continuously reassess to see if we are the primary beneficiary of a VIE. At year-end 2015 , we have two VIEs. We account for these VIEs using the equity method and we are not the primary beneficiary. Although we have certain rights regarding major decisions, we do not have the power to direct the activities that are most significant to the economic performance of these VIEs. At year-end 2015 , these VIEs have total assets of $62,187,000 , substantially all of which represent developed and undeveloped real estate and total liabilities of $55,989,000 , which includes $2,269,000 of borrowings classified as current maturities. These amounts are included in the summarized balance sheet information for ventures accounted for using the equity method in Note 6 — Investment in Unconsolidated Ventures . At year-end 2015 , our investment is $5,322,000 and is included in investment in unconsolidated ventures. In 2015 , we contributed $148,000 to these VIEs. Our maximum exposure to loss related to one of these VIEs is estimated at $3,780,000 , which exceeds our investment as we have a nominal general partner interest and could be held responsible for its liabilities. The maximum exposure to loss represents the maximum loss that we could be required to recognize assuming all the ventures’ assets (principally real estate) are worthless, without consideration of the probability of a loss or of any actions we may take to mitigate any such loss. In 2014, we acquired our partner's noncontrolling interests in the Lantana partnerships for $7,971,000 . Prior to acquisition of the noncontrolling interests, we were the primary beneficiary of all but one of the Lantana partnerships which were VIEs and consolidated in our financial statements. We adjusted the carrying amount of noncontrolling interests to reflect the change in our ownership interest in the partnerships. The difference between the consideration paid and the carrying amount of the noncontrolling interests acquired is recognized as an adjustment to additional paid in capital attributable to Forestar, net of deferred taxes of $1,729,000 .

Share-Based Compensation

Share-Based Compensation	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2013 (In thousands) Cash-settled awards $ (3,127 ) $ (3,710 ) $ 7,774 Equity-settled awards 5,026 5,168 4,281 Restricted stock (8 ) (25 ) 538 Stock options 2,355 1,984 4,216 Total share-based compensation $ 4,246 $ 3,417 $ 16,809 Deferred cash 228 — — $ 4,474 $ 3,417 $ 16,809 Share-based and long-term incentive compensation expense is included in: For the Year 2015 2014 2013 (In thousands) General and administrative $ 2,451 $ 1,001 $ 7,779 Other operating 2,023 2,416 9,030 $ 4,474 $ 3,417 $ 16,809 Excluded from share-based compensation expense in the table above are fees earned by directors in the amount of $1,203,000 for 2015, $906,000 for 2014 and $876,000 for 2013 for which they elected to defer payment until retirement in the form of share-settled units. These expenses are included in general and administrative expense on our consolidated statements of income (loss) and comprehensive income (loss). Share-Based Compensation The fair value of awards granted to retirement-eligible employees and expensed at the date of grant was $517,000 in 2015 , $760,000 in 2014 and $590,000 in 2013 . Unrecognized share-based compensation expense related to non-vested equity-settled awards, restricted stock and stock options is $5,109,000 at year-end 2015 . The weighted average period over which this amount will be recognized is estimated to be two years. We did not capitalize any share-based compensation in 2015 , 2014 or 2013 . In 2015 and 2014 , we issued 288,089 and 215,561 shares out of our treasury stock associated with vesting of stock-based awards or exercise of stock options, net of 51,521 and 55,238 shares withheld having a value of $762,000 and $1,043,000 for payroll taxes in connection with vesting of stock-based awards or exercise of stock options which are reflected in financing activities in our consolidated statements of cash flows. A summary of awards granted under our 2007 Stock Incentive Plan follows: Cash-settled awards Cash-settled awards granted to our employees in the form of restricted stock units or stock appreciation rights generally vest over three to four years from the date of grant and generally provide for accelerated vesting upon death, disability or if there is a change in control. Vesting for some restricted stock unit awards is also conditioned upon achievement of a minimum one percent annualized return on assets over a three -year period. Cash-settled stock appreciation rights have a ten -year term, generally become exercisable ratably over four years and provide for accelerated or continued vesting upon retirement, death, disability or if there is a change in control. Stock appreciation rights were granted with an exercise price equal to the market value of our stock on the date of grant. Cash-settled awards granted to our directors in the form of restricted stock units are fully vested at the time of grant and payable upon retirement. The following table summarizes the activity of cash-settled restricted stock unit awards in 2015 : Equivalent Units Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 185 $18.49 Granted 60 13.26 Vested (117 ) 18.26 Forfeited (11 ) 18.83 Non-vested at end of period 117 16.00 The weighted average grant date fair value of cash-settled restricted stock unit awards was $18.96 per unit for 2014 and $18.70 per unit for 2013. The fair value of cash-settled restricted stock unit awards settled was $2,469,000 in 2015, $2,286,000 in 2014, and $3,780,000 in 2013. The aggregate current value of non-vested awards is $1,286,000 at year-end 2015 based on a year-end stock price of $10.94 . The following table summarizes the activity of cash-settled stock appreciation rights in 2015 : 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 458 $12.54 4 $1,732 Granted 90 14.08 Exercised (39 ) 9.29 Forfeited (22 ) 15.00 Balance at end of period 487 12.97 4 404 Exercisable at end of period 414 12.77 3 404 The intrinsic value of cash-settled stock appreciation rights settled was $206,000 in 2015 , $1,181,000 in 2014 and $3,458,000 in 2013 . The fair value of accrued cash-settled awards at year-end 2015 and year-end 2014 were $3,757,000 and $9,560,000 and is included in other liabilities in our consolidated balance sheets. Equity-settled awards Equity-settled awards granted to our employees include restricted stock units (RSU), which vest after three years from the date of grant, market-leveraged stock units (MSU), which vest after three years from date of grant and performance stock units (PSU), which generally vest after three years from the date of grant if certain performance goals are met. Equity settled awards in the form of restricted stock units granted to our directors are fully vested at time of grant and settled upon retirement. The following table summarizes the activity of equity-settled awards in 2015 : Equivalent Units Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 710 $ 19.24 Granted 395 12.99 Vested (340 ) 14.23 Forfeited (134 ) 18.18 Non-vested at end of period 631 18.25 In 2015, we granted 234,000 MSU awards. These awards will be settled in common stock based upon our stock price performance over three years from the date of grant. The number of shares to be issued could range from a high of 351,000 shares if our stock price increases by 50 percent or more, to 117,000 shares if our stock price decreases by 50 percent , or could be zero if our stock price decreases by more than 50 percent , the minimum threshold performance. We estimate the grant date fair value of MSU awards using a Monte Carlo simulation pricing model and the following assumptions: For the Year 2015 2014 2013 Expected stock price volatility 32.9 % 42.2 % 42.2 % Risk-free interest rate 1.0 % 0.7 % 0.4 % Expected dividend yield — % — % — % Weighted average grant date fair value of MSU awards (per unit) $ 15.11 $ 20.38 $ 21.09 The weighted average grant date fair value of equity-settled awards (RSU, MSU, PSU) per unit in 2015, 2014 and 2013 was $12.99 , $19.18 and $20.21 . The fair value of equity-settled awards settled was $4,451,000 , $3,119,000 and $8,000 in 2015, 2014 and 2013. Unrecognized share-based compensation expense related to non-vested equity-settled awards is $3,258,000 at year-end 2015 . The weighted average period over which this amount will be recognized is estimated to be two years . Restricted stock awards Restricted stock awards generally vest over three years , typically if we achieve a minimum one percent annualized return on assets over such three -year period. The following table summarizes the activity of restricted stock awards in 2015 : Restricted Shares Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 17 $ 17.56 Granted — — Vested (7 ) 14.59 Forfeited (6 ) 19.00 Non-vested at end of period 4 20.55 The fair value of our restricted stock awards settled in 2015, 2014 and 2013 was $88,000 , $341,000 and $3,002,000 . Unrecognized share-based compensation expense related to non-vested restricted stock awards is $14,000 at year-end 2015 . The weighted average period over which this amount will be recognized is estimated to be one year . Stock options Stock options have a ten -year term, generally become exercisable ratably over four years and provide for accelerated or continued vesting upon retirement, death, disability or if there is a change in control. In 2015 and 2013, options were granted with an exercise price equal to the market value of our stock on the date of grant. We did not grant any options in 2014. The following table summarizes the activity of stock option awards in 2015 : Options Outstanding Weighted Average Exercise Price Weighted Average Remaining Contractual Term Aggregate Intrinsic Value (Current Value Less Exercise Price) (In thousands) (Per share) (In years) (In thousands) Balance at beginning of period 1,861 $ 20.74 6 $ 643 Granted 413 13.86 Exercised — — Forfeited (103 ) 18.01 Balance at end of period 2,171 19.56 5 156 Exercisable at end of period 1,687 20.83 4 156 We estimate the grant date fair value of stock options that do not have a market condition using the Black-Scholes option pricing model and the following assumptions: For the Year 2015 2013 Expected stock price volatility 45.6 % 66.8 % Risk-free interest rate 1.8 % 1.4 % Expected life of options (years) 6 6 Expected dividend yield — % — % Weighted average grant date fair value of options (per share) $ 6.51 $ 11.47 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 utilizes our historical volatility for a period corresponding to the expected life of the options. Stock option awards granted in third quarter 2015 in connection with management promotions have a ten -year term, vest ratably over three years and are exercisable only when our stock price exceeds $17.50 per share. We estimated the fair value of these options with market conditions using Monte Carlo simulation pricing model and the following assumptions: For the Year 2015 Expected stock price volatility 61.4 % Risk-free interest rate 2.2 % Expected dividend yield — % Weighted average grant date fair value of options (per share) $ 7.87 The fair value of vested stock options was $0 in 2015 , $21,000 in 2014 and $1,355,000 in 2013 . The intrinsic value of options exercised was $0 in 2015 , $568,000 in 2014 and $562,000 in 2013 . Unrecognized share-based compensation expense related to non-vested stock options is $1,837,000 at year-end 2015 . The weighted average period over which this amount will be recognized is estimated to be two years . Pre-Spin Awards Certain of our employees participated in Temple-Inland’s share-based compensation plans. In conjunction with our 2007 spin-off, these awards were equitably adjusted into separate awards of the common stock of Temple-Inland and the spin-off entities. The intrinsic value of pre-spin awards exercised was $24,000 in 2015, $352,000 in 2014 and $1,382,000 in 2013. Pre-spin stock option awards to our employees to purchase our common stock have a ten -year term, generally become exercisable ratably over four years and provide for accelerated or continued vesting upon retirement, death, disability or if there is a change in control. At year-end 2015 , there were 44,000 pre-spin awards outstanding and exercisable on our stock with a weighted average exercise price of $28.89 and weighted average remaining term of one year . Long-Term Incentive Compensation In 2015, we granted $587,000 of long-term incentive compensation in the form of deferred cash compensation. Deferred cash will be paid out after the earlier of three years or the employee's retirement eligibility date and the expense is recognized ratably over the vesting period. The accrued liability was $225,000 at year-end 2015 and is included in other liabilities.

Retirement Plans

Retirement Plans	12 Months Ended
	Dec. 31, 2015
Compensation and Retirement Disclosure [Abstract]
Retirement Plans	Retirement Plans Our defined contribution retirement plans include a 401(k) plan, which is funded, and a supplemental plan for certain employees, which is unfunded. The expense of our defined contribution retirement plans was $1,255,000 in 2015 , $1,651,000 in 2014 and $1,456,000 in 2013 . The unfunded liability for our supplemental plan was $802,000 at year-end 2015 and $715,000 at year-end 2014 and is included in other liabilities.

Supplemental Oil and Gas Disclo

Supplemental Oil and Gas Disclosures (Unaudited)	12 Months Ended
	Dec. 31, 2015
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). We lease our mineral interests, principally in Texas and Louisiana, to third-party entities for the exploration and production of oil and gas. When we lease our mineral interests, we may negotiate a lease bonus payment and we retain a royalty interest and may take an additional participation in production, including a working interest in which we pay a share of the costs to drill, complete and operate a well and receive a proportionate share of the production revenues. We engaged independent petroleum engineers, Netherland, Sewell & Associates, Inc., to assist in preparing estimates of our proved oil and gas reserves, all of which are located in the U.S., and future net cash flows as of year-end 2015 , 2014 and 2013 . These estimates were based on the economic and operating conditions existing at year-end 2015 , 2014 and 2013 . Proved developed reserves are those quantities of petroleum from existing wells and facilities, which by analysis of geosciences and engineering data, can be estimated with reasonable certainty to be commercially recoverable, from a given date forward for known reservoirs and under defined economic conditions, operating methods and government regulations. SEC rules require disclosure of proved reserves using the twelve-month average beginning-of-month price (which we refer to as the average price) for the year. These same average prices also are used in calculating the amount of (and changes in) future net cash inflows related to the standardized measure of discounted future net cash flows. For 2015 , 2014 and 2013 , the average spot price per barrel of oil based on the West Texas Intermediate Crude price is $50.28 , $94.99 and $96.91 and the average price per MMBTU of gas based on the Henry Hub spot market is $2.59 , $4.35 and $3.67 . All prices were then adjusted for quality, transportation fees and regional price differentials. The process of estimating proved reserves and future net cash flows is complex involving decisions and assumptions in evaluating the available engineering and geologic data and prices for oil and gas and the cost to produce these reserves and other factors, many of which are beyond our control. As a result, these estimates are imprecise and should be expected to change as future information becomes available. These changes could be significant. In addition, this information should not be construed as being the current fair market value of our proved reserves. Estimated Quantities of Proved Oil and Gas Reserves Estimated quantities of proved oil and gas reserves are summarized as follows: Reserves Oil (a) (Barrels) Gas (Mcf) (In thousands) Consolidated entities: Year-end 2012 3,220 11,722 Revisions of previous estimates 182 1,243 Extensions and discoveries 3,085 2,046 Acquisitions 35 531 Production (698 ) (1,912 ) Year-end 2013 5,824 13,630 Revisions of previous estimates 608 293 Extensions and discoveries 2,191 774 Acquisitions 85 31 Sales (105 ) (218 ) Production (931 ) (1,861 ) Year-end 2014 7,672 12,649 Revisions of previous estimates (855 ) (1,675 ) Extensions and discoveries 224 173 Acquisitions — — Sales (704 ) (1,223 ) Production (1,158 ) (1,967 ) Year-end 2015 5,179 7,957 Our share of ventures accounted for using the equity method: Year-end 2012 — 2,572 Revisions of previous estimates — 7 Production — (247 ) Year-end 2013 — 2,332 Revisions of previous estimates — (382 ) Production — (199 ) Year-end 2014 — 1,751 Revisions of previous estimates — (320 ) Production — (168 ) Year-end 2015 — 1,263 Total consolidated and our share of equity method ventures: Year-end 2013 Proved developed reserves 3,893 13,717 Proved undeveloped reserves 1,931 2,245 Total Year-end 2013 5,824 15,962 Year-end 2014 Proved developed reserves 5,269 12,599 Proved undeveloped reserves 2,403 1,801 Total Year-end 2014 7,672 14,400 Year-end 2015 Proved developed reserves 5,179 9,220 Proved undeveloped reserves — — Total Year-end 2015 5,179 9,220 _____________________ (a) Includes natural gas liquids (NGLs). We do not have any estimated reserves of synthetic oil, synthetic gas or products of other non-renewable natural resources that are intended to be upgraded into synthetic oil and gas. 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 have no barrels of oil equivalent (BOE) of proved undeveloped (PUD) reserves based on our plan to exit non-core oil and gas working interest assets compared with 2,703,000 BOE of PUD reserves at year-end 2014. In 2014, increases in extensions and discoveries of 2,191,000 barrels were primarily associated with new reserves in the Bakken/Three Forks formations. An estimated 694,000 barrels of these extensions and discoveries were associated with new producing wells while a further 913,000 barrels of proved undeveloped reserves were added during 2014. Approximately 105,000 barrels of oil and 218,000 Mcf of gas reserves located primarily in Oklahoma were sold during the year. We realized a net positive revision of previous estimates of 608,000 barrels which is primarily driven by improved drilling results in the Bakken/Three Forks formation yielding higher average estimated ultimate recoverable quantities of proved reserves per well. In 2013, increase in gas prices accounted for about 1,243,000 Mcf of upward revisions in gas reserves for our consolidated entities. In 2015 , 2014 and 2013 , 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 36 new well additions in 2015 , 106 new well additions in 2014 and 88 new well additions in 2013 . Capitalized Costs Relating to Oil and Gas Producing Activities Capitalized costs related to our oil and gas producing activities are as follows: At Year-End 2015 2014 (In thousands) Consolidated entities: Unproved oil and gas properties $ 19,441 $ 90,446 Proved oil and gas properties 119,414 221,299 Total costs 138,855 311,745 Less accumulated depreciation, depletion and amortization (58,242 ) (48,252 ) $ 80,613 $ 263,493 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 2015 2014 2013 (In thousands) Consolidated entities: Acquisition costs Proved properties $ — $ 2,001 $ — Unproved properties 4,832 25,666 35,806 Exploration costs 17,922 39,399 10,486 Development costs 27,609 40,277 54,538 $ 50,363 $ 107,343 $ 100,830 We have not incurred any costs for our share in ventures accounted for using the equity method. In 2015, acquisition of leasehold interests, exploration expenses, and development costs have decreased as a result of our increased focus on exiting and selling our leasehold working interests. Standardized Measure of Discounted Future Net Cash Flows Estimates of future cash flows from proved oil and gas reserves are shown in the following table. Estimated income taxes are calculated by applying the appropriate tax rates to the estimated future pre-tax net cash flows less depreciation of the tax basis of properties and the statutory depletion allowance. At Year-End 2015 2014 2013 (In thousands) Consolidated entities: Future cash inflows $ 216,588 $ 665,657 $ 544,098 Future production and development costs (93,623 ) (271,735 ) (231,801 ) Future income tax expenses (22,218 ) (106,002 ) (77,361 ) Future net cash flows 100,747 287,920 234,936 10% annual discount for estimated timing of cash flows (33,951 ) (124,079 ) (99,383 ) Standardized measure of discounted future net cash flows $ 66,796 $ 163,841 $ 135,553 Our share in ventures accounted for using the equity method: Future cash inflows $ 2,283 $ 6,186 $ 4,765 Future production and development costs (245 ) (664 ) (512 ) Future income tax expenses (774 ) (2,098 ) (1,616 ) Future net cash flows 1,264 3,424 2,637 10% annual discount for estimated timing of cash flows (562 ) (1,649 ) (1,337 ) Standardized measure of discounted future net cash flows $ 702 $ 1,775 $ 1,300 Total consolidated and our share of equity method ventures $ 67,498 $ 165,616 $ 136,853 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 2012 $ 106,543 $ 1,413 $ 107,956 Changes resulting from: Net change in sales prices and production costs 23,422 415 23,837 Net change in future development costs (2,897 ) — (2,897 ) Sales of oil and gas, net of production costs (56,559 ) (801 ) (57,360 ) Net change due to extensions and discoveries 54,539 — 54,539 Net change due to acquisition of reserves 1,160 — 1,160 Net change due to revisions of quantity estimates 8,673 6 8,679 Previously estimated development costs incurred 4,124 — 4,124 Accretion of discount 13,540 228 13,768 Net change in timing and other (718 ) (31 ) (749 ) Net change in income taxes (16,274 ) 70 (16,204 ) Aggregate change for the year 29,010 (113 ) 28,897 Year-end 2013 135,553 1,300 136,853 Changes resulting from: Net change in sales prices and production costs (1,064 ) 1,571 507 Net change in future development costs 1,308 — 1,308 Sales of oil and gas, net of production costs (63,192 ) (787 ) (63,979 ) Net change due to extensions and discoveries 58,228 — 58,228 Net change due to acquisition of reserves 2,778 — 2,778 Net change due to divestitures of reserves (5,804 ) — (5,804 ) Net change due to revisions of quantity estimates 15,303 (343 ) 14,960 Previously estimated development costs incurred 15,497 — 15,497 Accretion of discount 18,067 210 18,277 Net change in timing and other 4,198 115 4,313 Net change in income taxes (17,031 ) (291 ) (17,322 ) Aggregate change for the year 28,288 475 28,763 Year-end 2014 163,841 1,775 165,616 Changes resulting from: Net change in sales prices and production costs (136,536 ) (1,112 ) (137,648 ) Net change in future development costs 92 — 92 Sales of oil and gas, net of production costs (31,732 ) (428 ) (32,160 ) Net change due to extensions and discoveries 11,747 — 11,747 Net change due to acquisition of reserves — — — Net change due to divestitures of reserves (15,855 ) (15,855 ) Net change due to revisions of quantity estimates (15,164 ) (267 ) (15,431 ) Previously estimated development costs incurred 15,096 — 15,096 Accretion of discount 22,600 286 22,886 Net change in timing and other 4,018 (210 ) 3,808 Net change in income taxes 48,689 658 49,347 Aggregate change for the year (97,045 ) (1,073 ) (98,118 ) Year-end 2015 $ 66,796 $ 702 $ 67,498 Results of Operations for Oil and Gas Producing Activities Our royalty interests are contractually defined and based on a percentage of production at prevailing market prices. We receive our percentage of production in cash. Similarly, for operating properties our working interests and the associated net revenue interests are contractually defined and we pay our proportionate share of the capital and operating costs to develop and operate the well and we market our share of the production. Our revenues fluctuate based on changes in the market prices for oil and gas, the decline in production from existing wells, and other factors affecting oil and gas exploration and production activities, including the cost of development and production. Information about the results of operations of our oil and gas interests follows: For the Year 2015 2014 2013 (In thousands) Consolidated entities Revenues $ 51,553 $ 82,919 $ 69,036 Production costs (19,820 ) (19,727 ) (12,477 ) Exploration costs (11,864 ) (17,416 ) (10,486 ) Depreciation, depletion, amortization (28,774 ) (29,442 ) (19,552 ) Non-cash impairment of proved oil and gas properties and unproved leasehold interests (164,831 ) (32,665 ) (473 ) Oil and gas administrative expenses (11,700 ) (17,000 ) (14,407 ) Accretion expense (144 ) (121 ) (94 ) Income tax expenses 14,717 13,398 (3,471 ) Results of operations (170,863 ) (20,054 ) 8,076 Our share in ventures accounted for using the equity method: Revenues $ 428 $ 786 $ 801 Production costs (102 ) (105 ) (123 ) Oil and gas administrative expenses (51 ) (95 ) (86 ) Income tax expenses 21 (235 ) (178 ) Results of operations $ 296 $ 351 $ 414 Total results of operations $ (170,567 ) $ (19,703 ) $ 8,490 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, 2015
Quarterly Financial Information Disclosure [Abstract]
Summary of Quarterly Results of Operations (Unaudited)	Summary of Quarterly Results of Operations (Unaudited) Summarized quarterly financial results for 2015 and 2014 follows: First Quarter (a) Second Quarter (a) Third Quarter (a) Fourth Quarter (a) (In thousands, except per share amounts) 2015 Total revenues $ 47,805 $ 57,430 $ 43,168 $ 114,018 Gross profit (loss) 17,289 (35,009 ) (69,572 ) 8,341 Operating income (loss) (7,737 ) (52,714 ) (94,751 ) (9,482 ) Equity in earnings of unconsolidated ventures 3,045 5,584 2,909 4,470 Income (loss) before taxes (12,596 ) (55,062 ) (100,095 ) (11,983 ) Net income (loss) attributable to Forestar Group Inc. (8,158 ) (34,507 ) (164,216 ) (6,166 ) Net income (loss) per share — basic $ (0.24 ) $ (1.01 ) $ (4.79 ) $ (0.18 ) Net income (loss) per share — diluted $ (0.24 ) $ (1.01 ) $ (4.79 ) $ (0.18 ) 2014 Total revenues $ 84,605 $ 83,013 $ 58,840 $ 80,316 Gross profit (loss) 35,025 33,261 19,606 (6,259 ) Operating income (loss) 15,883 26,942 12,716 (16,783 ) Equity in earnings of unconsolidated ventures 991 958 2,016 4,720 Income (loss) before taxes 13,665 22,799 7,994 (18,713 ) Net income (loss) attributable to Forestar Group Inc. 8,334 14,822 5,227 (11,800 ) Net income (loss) per share — basic $ 0.20 $ 0.34 $ 0.12 $ (0.34 ) Net income (loss) per share — diluted $ 0.19 $ 0.34 $ 0.12 $ (0.34 ) _____________________ (a) Non-cash impairment charges for 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) 2015 $ 7 $ 45,938 $ 81,240 $ 37,646 2014 755 584 735 30,591

Consolidated Real Estate and Ac

Consolidated Real Estate and Accumulated Depreciation	12 Months Ended
	Dec. 31, 2015
SEC Schedule III, Real Estate and Accumulated Depreciation Disclosure [Abstract]
Consolidated Real Estate and Accumulated Depreciation	Forestar Group Inc. Schedule III — Consolidated Real Estate and Accumulated Depreciation Year-End 2015 (In thousands) Initial Cost to Company Costs Capitalized Subsequent to Acquisition Gross Amount Carried at End of Period Description Encumbrances Land Buildings & Improvements Improvements less Cost of Sales and Other Carrying Costs (a) Land & Land Improvements Buildings & Improvements Total Accumulated Depreciation Date of Construction Date Acquired Entitled, Developed, and Under Development Projects: ARIZONA Pima County Dove Mountain $ 5,860 $ 3 $ 5,863 $ 5,863 2015 CALIFORNIA Contra Costa County San Joaquin River 12,225 (3,310 ) 8,915 8,915 (b) COLORADO Douglas County Pinery West 7,308 3,691 10,999 10,999 2006 2006 Weld County Buffalo Highlands 3,001 547 3,548 3,548 2006 2005 Johnstown Farms 2,749 4,024 $ 188 6,961 6,961 2002 2002 Stonebraker 3,878 (1,469 ) 2,409 2,409 2005 2005 GEORGIA Cobb County West Oaks 1,669 232 1,901 1,901 2015 2015 Paulding County Harris Place 265 (111 ) 154 154 2012 Seven Hills 2,964 145 3,109 3,109 2012 MISSOURI Clay County Somerbrook 3,061 (218 ) 13 2,856 2,856 2003 2001 NORTH CAROLINA Mecklenburg County Walden 12,085 345 12,430 12,430 2015 SOUTH CAROLINA Lancaster County Ansley Park 5,089 574 5,663 5,663 2015 York County Habersham 3,877 3,072 239 7,188 7,188 2014 2013 Initial Cost to Company Costs Capitalized Subsequent to Acquisition Gross Amount Carried at End of Period Description Encumbrances Land Buildings & Improvements Improvements less Cost of Sales and Other Carrying Costs (a) Land & Land Improvements Buildings & Improvements Total Accumulated Depreciation Date of Construction Date Acquired TENNESEE Williamson County Morgan Farms $ 6,841 $ (552 ) $ 166 $ 6,455 $ 6,455 2013 2013 Vickery Park 3,575 560 4,135 4,135 2015 Weatherford Estates 856 1,603 2,459 2,459 2015 2014 Wilson County Beckwith Crossing 1,294 2,519 3,813 3,813 2015 2014 TEXAS Bastrop County Hunter’s Crossing 3,613 5,180 358 9,151 9,151 2001 2001 The Colony 8,726 15,206 161 24,093 24,093 1999 1999 Bexar County Cibolo Canyons 17,305 40,243 1,202 58,750 58,750 2004 1986 Calhoun County Caracol $ 2,237 8,603 3,688 2,047 14,338 14,338 2006 2006 Collin County Lakes of Prosper 8,951 (3,550 ) 180 5,581 5,581 2012 Maxwell Creek 9,904 (7,946 ) 635 2,593 2,593 2000 2000 Parkside 2,177 3,661 5,838 5,838 2014 2013 Timber Creek 7,282 9,137 16,419 16,419 2007 2007 Village Park 4,772 (4,765 ) 45 52 52 2012 Comal County Oak Creek Estates 1,921 2,314 175 4,410 4,410 2006 2005 Dallas County Stoney Creek 12,822 2,783 49 15,654 15,654 2007 2007 Denton County Lantana 27,673 (7,382 ) 20,291 20,291 2000 1999 River's Edge 1,227 381 1,608 1,608 2014 The Preserve at Pecan Creek 5,855 (3,905 ) 436 2,386 2,386 2006 2005 Fort Bend County Summer Lakes 4,269 968 5,237 5,237 2013 2012 Summer Park 4,804 57 4,861 4,861 2013 2012 Willow Creek Farms 459 3,479 (311 ) 90 3,258 3,258 2012 2012 Harris County Barrington 8,950 (7,062 ) 1,888 1,888 2011 City Park 1,659 3,946 1,463 1,641 7,050 7,050 2002 2001 Imperial Forest 5,345 819 6,164 6,164 2015 2014 Initial Cost to Company Costs Capitalized Subsequent to Acquisition Gross Amount Carried at End of Period Description Encumbrances Land Buildings & Improvements Improvements less Cost of Sales and Other Carrying Costs (a) Land & Land Improvements Buildings & Improvements Total Accumulated Depreciation Date of Construction Date Acquired Hays County Arrowhead Ranch $ 12,856 $ 6,537 $ 19,393 $ 19,393 2015 2007 Nueces County Tortuga Dunes 12,080 9,670 21,750 21,750 2006 Tarrant County Summer Creek Ranch 2,887 (1,601 ) 1,286 1,286 2012 The Bar C Ranch 1,365 3,258 $ 32 4,655 4,655 2012 Williamson County La Conterra 4,024 (2,790 ) 293 1,527 1,527 2006 Westside at Buttercup Creek 13,149 (13,586 ) 488 51 51 1993 1993 Other 8,443 (4,097 ) 653 4,999 4,999 Total Entitled, Developed, and Under Development Projects $ 4,355 $ 283,025 $ — $ 60,025 $ 9,091 $ 352,141 $ — $ 352,141 $ — Undeveloped Land and Land in Entitlement: CALIFORNIA Los Angeles County Land In Entitlement Process $ 3,950 $ 19,564 $ 23,514 $ 23,514 1997 GEORGIA Bartow County Undeveloped Land 4,057 (2,440 ) 1,617 1,617 (b) Carroll County Undeveloped Land 13,564 2,580 16,144 16,144 (b) Cherokee County Undeveloped Land 6,043 536 6,579 6,579 (b) Coweta County Undeveloped Land 3,089 1,343 4,432 4,432 (b) Dawson County Undeveloped Land 2,228 3,381 5,609 5,609 (b) Gilmer County Undeveloped Land 2,748 (62 ) 2,686 2,686 (b) Haralson County Undeveloped Land 195 88 283 283 (b) Lumpkin County Undeveloped Land 3,015 (93 ) 2,922 2,922 (b) Paulding County Undeveloped Land 7,494 7,494 7,494 (b) 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 Pickens County Undeveloped Land $ 3,150 $ (108 ) $ 3,042 $ 3,042 (b) Polk County Undeveloped Land 2,354 (198 ) 2,156 2,156 (b) TEXAS Bexar County Undeveloped Land 3,036 3,036 3,036 (b) Harris County Land in Entitlement Process 685 1,151 1,836 1,836 (b) Other Undeveloped Land 9,170 7,661 16,831 16,831 (b) Total Undeveloped Land and Land in Entitlement $ — $ 61,742 $ — $ 36,439 $ — $ 98,181 $ — $ 98,181 $ — Income Producing Properties: NORTH CAROLINA Mecklenburg County Dillon $ 5,779 $ 14,208 $ 19,987 $ 19,987 2012 TENNESSEE Davidson County Music Row 6,607 3,340 9,947 9,947 2014 TEXAS Travis County Eleven $ 23,936 7,940 $ 45,956 — 7,940 $ 45,956 53,896 $ (2,861 ) 2013 2014 Downtown Edge 11,202 1,504 12,706 12,706 2014 Radisson Hotel & Suites 15,400 10,603 52,286 — 62,889 62,889 (29,268 ) (b) West Austin 7,275 1,822 9,097 9,097 2014 Total Income Producing Properties $ 39,336 $ 38,803 $ 56,559 $ 73,160 $ — $ 59,677 $ 108,845 $ 168,522 $ (32,129 ) Total $ 43,691 $ 383,570 $ 56,559 $ 169,624 $ 9,091 $ 509,999 $ 108,845 $ 618,844 $ (32,129 ) _____________________ (a) We do not capitalize carrying costs until development begins. (b) The acquisition date is not available. Reconciliation of real estate: 2015 2014 2013 (In thousands) Balance at beginning of year $ 607,133 $ 547,530 $ 545,370 Amounts capitalized 124,633 214,184 111,428 Amounts retired or adjusted (112,922 ) (154,581 ) (109,268 ) Balance at close of period $ 618,844 $ 607,133 $ 547,530 Reconciliation of accumulated depreciation: 2015 2014 2013 (In thousands) Balance at beginning of year $ (31,377 ) $ (28,066 ) $ (28,220 ) Depreciation expense (6,810 ) (3,319 ) (2,185 ) Amounts retired or adjusted 6,058 8 2,339 Balance at close of period $ (32,129 ) $ (31,377 ) $ (28,066 )

(Notes)

(Notes)	12 Months Ended
	Dec. 31, 2015
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events On January 28, 2016, we announced that our multifamily business is non-core. As a result, we plan to opportunistically exit our multifamily portfolio and no longer allocate capital to new communities in this business. On February 4, 2016, we entered into a Purchase and Sale Agreement to sell the Radisson Hotel & Suites in Austin for $130,000,000 . This transaction is subject to normal closing conditions and is expected to close in second quarter 2016. On March 1, 2016, we sold our remaining Kansas and Nebraska oil and gas properties for $21,000,000 , with a $2,000,000 contingency payment if the WTI oil price exceeds $60 Bbl for 60 consecutive trading days within one year following closing. We will incur an additional loss related to the sale of Kansas and Nebraska oil and gas properties due to allocation of goodwill on a relative fair value basis to the disposal group that constitutes a business.

Summary of Significant Accoun30

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation Our consolidated financial statements include the accounts of Forestar Group Inc., all subsidiaries, ventures and other entities in which we have a controlling interest. We account for our investment in other entities in which we have significant influence over operations and financial policies using the equity method (we recognize our share of the entities’ income or loss and any preferential returns and treat distributions as a reduction of our investment). We eliminate all material intercompany accounts and transactions. Noncontrolling interests in consolidated pass-through entities are recognized before income taxes. We prepare our financial statements in accordance with generally accepted accounting principles in the United States, which require us to make estimates and assumptions about future events. Actual results can, and probably will, differ from those we currently estimate. Examples of significant estimates include those related to allocating costs to real estate, measuring long-lived assets for impairment, oil and gas revenue accruals, capital expenditure and lease operating expense accruals associated with our oil and gas production activities, oil and gas reserves and depletion of our oil and gas properties.
Cash and Cash Equivalents	Cash and Cash Equivalents Cash and cash equivalents include cash and other short-term instruments with original maturities of three months or less. At year-end 2015 and 2014 , restricted cash was $200,000 and $217,000 and is included in other assets.
Cash Flows	Cash Flows Expenditures for the acquisition and development of single-family and multifamily real estate that we intend to develop for sale are classified as operating activities. Expenditures for the acquisition and development of properties to be held and operated, investment in oil and gas properties and equipment, and business acquisitions are classified as investing activities. Our accrued capital expenditures for unproved leasehold acquisitions and drilling and completion costs at year-end 2015 and 2014 were $7,033,000 and $19,405,000 and are included in other accrued expenses in our consolidated balance sheets. These oil and gas property additions will be reflected as cash used for investing activities in the period the accrued payables are settled.
Capitalized Software	Capitalized Software We capitalize purchased software costs as well as the direct internal and external costs associated with software we develop for our own use. We amortize these capitalized costs using the straight-line method over estimated useful lives generally ranging from three to five years . The carrying value of capitalized software was $237,000 at year-end 2015 and $1,188,000 at year-end 2014 and is included in other assets. The amortization of these capitalized costs was $996,000 in 2015 , $1,067,000 in 2014 and $1,593,000 in 2013 and is included in general and administrative and operating expenses.
Environmental and Asset Retirement Obligations	Environmental and Asset Retirement Obligations We recognize environmental remediation liabilities on an undiscounted basis when environmental assessments or remediation are probable and we can reasonably estimate the cost. We adjust these liabilities as further information is obtained or circumstances change. Our asset retirement obligations are related to the abandonment and site restoration requirements that result from the acquisition, construction and development of our oil and gas properties. We record the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. Accretion expense related to the asset retirement obligation and depletion expense related to capitalized asset retirement cost is included in cost of oil and gas producing activities on our consolidated statements of income (loss). The following summarizes the changes in asset retirement obligations: Year-End 2015 2014 (In thousands) Beginning balance $ 1,807 $ 1,483 Additions 65 314 Property dispositions (119 ) (230 ) Change in estimate — 118 Liabilities settled (139 ) — Accretion expense 144 122 $ 1,758 $ 1,807
Fair Value Measurements	Fair Value Measurements Financial instruments for which we did not elect the fair value option include cash and cash equivalents, accounts and notes receivables, other assets, long-term debt, accounts payable and other liabilities. With the exception of long-term notes receivable and debt, the carrying amounts of these financial instruments approximate their fair values due to their short-term nature or variable interest rates.
Goodwill and Other Intangible Assets	Goodwill and Other Intangible Assets We record goodwill when the purchase price of a business acquisition exceeds the estimated fair value of net identified tangible and intangible assets acquired. We do not amortize goodwill or other indefinite lived intangible assets. Instead, we measure these assets for impairment based on the estimated fair values at least annually or more frequently if impairment indicators exist. We perform the annual impairment measurement in the fourth quarter of each year. Intangible assets with finite useful lives are amortized over their estimated useful lives. In 2015 , we performed our annual goodwill impairment evaluation and concluded that goodwill was not impaired as the estimated fair value exceeded the carrying value.
Income Taxes	Income Taxes We provide deferred income taxes using current tax rates for temporary differences between the financial accounting carrying value of assets and liabilities and their tax accounting carrying values. We recognize and value income tax exposures for the various taxing jurisdictions where we operate based on laws, elections, commonly accepted tax positions, and management estimates. We include tax penalties and interest in income tax expense. We provide a valuation allowance for any deferred tax asset that is not likely to be recoverable in future periods. When we believe a tax position is supportable but the outcome uncertain, we include the item in our tax return but do not recognize the related benefit in our provision for taxes. Instead, we record a reserve for unrecognized tax benefits, which represents our expectation of the most likely outcome considering the technical merits and specific facts of the position. Changes to liabilities are only made when an event occurs that changes the most likely outcome, such as settlement with the relevant tax authority, expiration of statutes of limitations, changes in tax law, or recent court rulings.
Owned Mineral Interests	Owned Mineral Interests When we lease our mineral interests to third-party exploration and production entities, we retain a royalty interest and may take an additional participation in production, including a working interest. Mineral interests and working interests related to our owned mineral interests are included in oil and gas properties and equipment on our balance sheet, net of accumulated depletion.
Oil and Gas Properties	Oil and Gas Properties We use the successful efforts method of accounting for our oil and gas producing activities. Costs to acquire mineral interests leased, costs to drill and complete development of oil and gas wells and related asset retirement costs are capitalized. Costs to drill exploratory wells are capitalized pending determination of whether the wells have proved reserves and if determined incapable of producing commercial quantities of oil and gas these costs are expensed as dry hole costs. At year-end 2014, we had $8,575,000 in capitalized exploratory well costs pending determination of proved reserves, of which $8,454,000 was charged to expense in 2015 with the remaining capitalized based on determination of proved reserves. At year-end 2015 , we have no capitalized exploratory well costs pending determination of proved reserves. Exploration costs include dry hole costs, geological and geophysical costs, expired unproved leasehold costs and seismic studies, and are expensed as incurred. Production costs incurred to maintain wells and related equipment are charged to expense as incurred. Depreciation and depletion of producing oil and gas properties is calculated using the units-of-production method. Proved developed reserves are used to compute unit rates for unamortized tangible and intangible drilling and completion costs. Proved reserves are used to compute unit rates for unamortized acquisition of proved leasehold costs. Unit-of-production amortization rates are revised whenever there is an indication of the need for revision but at least once a year and those revisions are accounted for prospectively as changes in accounting estimates. Impairment of Oil and Gas Properties We evaluate our oil and gas properties, including facilities and equipment, for impairment whenever events or changes in circumstances indicate that the carrying value of an asset may not be recoverable. We estimate the expected undiscounted future cash flows of our oil and gas properties and compare such undiscounted future cash flows to the carrying amount of the oil and gas properties to determine if the carrying amount is recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, we will adjust the carrying amount of the oil and gas properties to fair value. The factors used to determine fair value are subject to our judgment and expertise and include, but are not limited to, recent sales prices of comparable properties, the present value of future cash flows, net of estimated operating and development costs using estimates of proved reserves, future commodity pricing, future production estimates, anticipated capital expenditures, and various discount rates commensurate with the risk and current market conditions associated with realizing the expected cash flows projected. Because of the uncertainty inherent in these factors, we cannot predict when or if future impairment charges for proved properties will be recorded. The assessment of unproved leasehold properties to determine any possible impairment requires significant judgment. We assess our unproved leasehold properties periodically for impairment on a property-by-property basis based on remaining lease terms, drilling results or future plans to develop acreage. Impairment expense for proved and unproved oil and gas properties are included in costs of oil and gas producing activities.
Operating Leases	Operating Leases We occupy office space in various locations under operating leases. The lease agreements may contain rent escalation clauses, construction allowances and/or contingent rent provisions. We expense operating leases ratably over the shorter of the useful life or the lease term. For scheduled rent escalation clauses, we recognize the base rent expense on a straight-line basis and record the difference between the recognized rent expense and the amounts payable under the lease as deferred lease credits included in other liabilities in the consolidated balance sheets. Deferred lease credits are amortized over the lease term. For construction allowances, we record leasehold improvement assets included in property and equipment in the consolidated balance sheets amortized over the shorter of their economic lives or the lease term. The related deferred lease credits are amortized as a reduction of rent expense over the lease term.
Property and Equipment	Property and Equipment We carry property and equipment at cost less accumulated depreciation. We capitalize the cost of significant additions and improvements, and we expense the cost of repairs and maintenance. We capitalize interest costs incurred on major construction projects. We depreciate these assets using the straight-line method over their estimated useful lives as follows: Estimated Year-End Useful Lives 2015 2014 (In thousands) Buildings and building improvements 10 to 40 years $ 4,044 $ 4,461 Property and equipment 2 to 10 years 12,230 14,084 16,274 18,545 Less: accumulated depreciation (5,542 ) (6,918 ) $ 10,732 $ 11,627 Depreciation expense of property and equipment was $1,067,000 in 2015 , $903,000 in 2014 and $1,028,000 in 2013 .
Real Estate	Real Estate We carry real estate at the lower of cost or fair value less cost to sell. We capitalize interest costs once development begins, and we continue to capitalize throughout the development period. We also capitalize infrastructure, improvements, amenities, and other development costs incurred during the development period. We determine the cost of real estate sold using the relative sales value method. When we sell real estate from projects that are not finished, we include in the cost of real estate sold estimates of future development costs through completion, allocated based on relative sales values. These estimates of future development costs are reevaluated at least annually, with any adjustments being allocated prospectively to the remaining units available for sale. We receive cash deposits from home builders for purchases of vacant developed lots from community development projects. These earnest money deposits are released to the home builders as lots are developed and sold. Income producing properties are carried at cost less accumulated depreciation computed using the straight-line method over their estimated useful lives. We have agreements with utility or improvement districts, principally in Texas, whereby we agree to convey to the district's water, sewer and other infrastructure-related assets we have constructed in connection with projects within their jurisdiction. The reimbursement for these assets ranges from 70 to 90 percent of allowable cost as defined by the district. The transfer is consummated and we receive payment when the districts have a sufficient tax base to support funding of their bonds. The cost we incur in constructing these assets is included in capitalized development costs, and upon collection, we remove the assets from capitalized development costs. We provide an allowance to reflect our past experiences related to claimed allowable development costs. Impairment of Real Estate Long-Lived Assets We review real estate long-lived assets held for use for impairment when events or circumstances indicate that their carrying value may not be recoverable. Impairment exists if the carrying amount of the long-lived asset is not recoverable from the undiscounted cash flows expected from its use and eventual disposition. We determine the amount of the impairment loss by comparing the carrying value of the long-lived asset to its estimated fair value. In the absence of quoted market prices, we determine estimated fair value generally based on the present value of future probability weighted cash flows expected from the sale of the long-lived asset. Non-cash impairment charges related to our owned and consolidated real estate assets are included in cost of real estate sales and other.
Revenue	Revenue Real Estate We recognize revenue from sales of real estate when a sale is consummated, the buyer’s initial investment is adequate, any receivables are probable of collection, the usual risks and rewards of ownership have been transferred to the buyer, and we do not have significant continuing involvement with the real estate sold. If we determine that the earnings process is not complete, we defer recognition of any gain until earned. We recognize revenue from hotel room sales and other guest services when rooms are occupied and other guest services have been rendered. We recognize rental revenues from our multifamily properties when earned in accordance with the terms of the respective leases on a straight-line basis for the period of occupancy. We recognize construction revenues on multifamily projects that we develop as a general contractor. Construction revenues are recognized as costs are incurred plus fixed fee earned. We are reimbursed for costs paid to subcontractors plus we may earn a development and construction management fee on multifamily projects we develop, both of which are included in commercial and income producing properties revenue. On multifamily projects where our fee is based on a fixed fee plus guaranteed maximum price contract, any cost overruns incurred during construction, as compared to the original budget, will reduce the net fee generated on these projects. Any excess cost overruns estimated over the net fee generated are recognized in the period in which they become evident. At year-end 2015, we are not a general contractor on any of the multifamily projects currently under construction and we do not anticipate to be a general contractor on any new multifamily projects. We exclude from revenue amounts we collect from utility or improvement districts related to the conveyance of water, sewer and other infrastructure related assets. We also exclude from revenue amounts we collect for timber sold on land being developed. These proceeds reduce capitalized development costs. We exclude from revenue amounts we collect from customers that represent sales tax or other taxes that are based on the sale. These amounts are included in other accrued expenses until paid. Oil and Gas We recognize revenue as oil and gas is produced and sold. There are a significant amount of oil and gas properties which we do not operate and, therefore, revenue is typically recorded in the month of production based on an estimate of our share of volumes produced and prices realized. We obtain the most current available production data from the operators and price indices for each well to estimate the accrual of revenue. Obtaining production data on a timely basis for some wells is not feasible; therefore we utilize past production receipts and estimated sales price information to estimate accrual of working interest revenue on all other non-operated wells each month. Revisions to such estimates are recorded as actual results become known. We review accounts receivable periodically and reduce the carrying amount by a valuation allowance that reflects our best estimate of the amount that may not be collectible. A majority of our sales are made under contractual arrangements with terms that are considered to be usual and customary in the oil and gas industry. The contracts are for periods of up to five years with prices determined upon a percentage of pre-determined and published monthly index price. The terms of these contracts have not had an effect on how we recognize revenue. We recognize revenue from mineral bonus payments received as a result of leasing our owned mineral interests to others when we have received an executed agreement with the exploration company transferring the rights to any oil or gas it may find and requiring drilling be done within a specified period, the payment has been collected, and we have no obligation to refund the payment. We recognize revenue from delay rentals received if drilling has not started within the specified period and when the payment has been collected. We recognize revenue from mineral royalties when the minerals have been delivered to the buyer, the value is determinable, and we are reasonably sure of collection. Other Natural Resources We recognize revenue from timber sales upon passage of title, which occurs at delivery; when the price is fixed and determinable; and we are reasonably sure of collection. We recognize revenue from recreational leases on the straight-line basis over the lease term.
Share-Based Compensation	Share-Based Compensation We use the Black-Scholes option pricing model for stock options, Monte Carlo simulation pricing model for market-leveraged stock units and for stock options with market conditions, grant date fair value for equity-settled awards and period-end fair value for cash-settled awards. We expense share-based awards ratably over the vesting period or earlier based on retirement eligibility.
Timber	Timber We carry timber at cost less the cost of timber cut. We expense the cost of timber cut based on the relationship of the timber carrying value to the estimated volume of recoverable timber multiplied by the amount of timber cut. We include the cost of timber cut in cost of other natural resources in the income statement. We determine the estimated volume of recoverable timber using statistical information and other data related to growth rates and yields gathered from physical observations, models and other information gathering techniques. Changes in yields are generally due to adjustments in growth rates and similar matters and are accounted for prospectively as changes in estimates. We capitalize reforestation costs incurred in developing viable seedling plantations (up to two years from planting), such as site preparation, seedlings, planting, fertilization, insect and wildlife control, and herbicide application. We expense all other costs, such as property taxes and costs of forest management personnel, as incurred. Once the seedling plantation is viable, we expense all costs to maintain the viable plantations, such as fertilization, herbicide application, insect and wildlife control, and thinning, as incurred. We own directly or through ventures about 89,000 acres of non-core timberland and undeveloped land, primarily in Georgia. The non-cash cost of timber cut and sold is $250,000 in 2015 , $371,000 in 2014 and $609,000 in 2013 and is included in depreciation, depletion and amortization in our statement of cash flows.
New and Pending Accounting Pronouncements	Pending Accounting Pronouncements Pending Accounting Standards In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , requiring an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The updated standard will replace most existing revenue recognition guidance in U.S. GAAP when it becomes effective and permits the use of either the retrospective or cumulative effect transition method. Early adoption is not permitted. The updated standard becomes effective for annual and interim periods beginning after December 15, 2016. In July 2015, the FASB decided to defer the effective date of the new standard by one year. This deferral results in the updated standard being effective after December 15, 2017. We have not yet selected a transition method and we are currently evaluating the effect that the updated standard will have on our earnings, financial position and disclosures. In January 2015, the FASB issued ASU 2015-01, Income Statement - Extraordinary and Unusual Items (Subtopic 225-20), which eliminates the concept of extraordinary items from U.S. GAAP. The updated standard is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015. Early adoption is permitted, provided that the guidance is applied from the beginning of the fiscal year of adoption. The adoption of this guidance is not expected to have an impact on our financial statements and related disclosures. In February 2015, the FASB issued ASU 2015-02, Consolidation: Amendments to the Consolidation Analysis (Topic 810) , requiring entities to evaluate whether they should consolidate certain legal entities. All legal entities are subject to reevaluation under the revised consolidation model. The revised consolidation model: (1) modifies the evaluation of whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities, (2) eliminates the presumption that a general partner should consolidate a limited partnership, (3) affects the consolidation analysis of reporting entities that are involved with VIEs, and (4) provides a scope exception from consolidation guidance for reporting entities with interests in certain legal entities. The updated standard is effective for financial statements issued for annual and interim periods beginning after December 15, 2015. Early adoption is permitted. The updated standard may be applied retrospectively or using a modified retrospective approach by recording a cumulative-effect adjustment to equity as of the beginning of the fiscal year of adoption. The adoption of this guidance is not expected to have an impact on our financial statements and related disclosures. In April 2015, the FASB issued ASU 2015-03, Interest – Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs, as part of its initiative to reduce complexity in accounting standards. To simplify presentation of debt issuance costs, the amendments in this update require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. In August 2015, the FASB issued ASU 2015-15, Interest-Imputation of Interest (Subtopic 835-30), Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements - Amendments to SEC Paragraphs Pursuant to Staff Announcement at June 18, 2015 EITF Meeting (SEC Update), which allows an entity to defer and present debt issuance costs as an asset and subsequently amortize the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. The updated standards are effective for financial statements issued for annual and interim periods beginning after December 15, 2015. The updated standards are not expected to materially impact our financial position or disclosures. In April 2015, the FASB issued ASU 2015-05, Customer's Accounting for Fees Paid in a Cloud Computing Arrangement (Subtopic 350-40), in order to provide clarification on whether a cloud computing arrangement includes a software license. If a software license is included, the customer should account for the license consistent with its accounting of other software licenses. If a software license is not included, the arrangement should be accounted for as a service contract. The update is effective for reporting periods beginning after December 15, 2015. Early adoption is permitted. We are currently evaluating the effect the updated standard will have on our financial position and disclosures. In June 2015, the FASB issued ASU 2015-10, Technical Corrections and Updates . The amendments in this update cover a wide range of topics in the codification and are generally categorized as follows: Amendments Related to Differences between Original Guidance and the Codification; Guidance Clarification and Reference Corrections; Simplification; and, Minor Improvements. The amendments are effective for fiscal years and interim periods within those fiscal years, beginning after December 15, 2015. Early adoption is permitted. The adoption of this standard is not expected to impact our financial position or results of operations. In November 2015, the FASB issued ASU 2015-17, Income Taxes - Balance Sheet Classification of Deferred Taxes (Subtopic 740). The ASU requires that deferred tax liabilities and assets be classified as noncurrent in a classified statement of financial position. The amendments in this update are effective for fiscal years and interim periods within those fiscal years beginning after December 15, 2016. We do not currently present a classified consolidated balance sheet and therefore this pronouncement will have no impact on our financial statements and related disclosures. 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.

Summary of Significant Accoun31

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Schedule of Change in Asset Retirement Obligation	The following summarizes the changes in asset retirement obligations: Year-End 2015 2014 (In thousands) Beginning balance $ 1,807 $ 1,483 Additions 65 314 Property dispositions (119 ) (230 ) Change in estimate — 118 Liabilities settled (139 ) — Accretion expense 144 122 $ 1,758 $ 1,807
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 2015 2014 (In thousands) Buildings and building improvements 10 to 40 years $ 4,044 $ 4,461 Property and equipment 2 to 10 years 12,230 14,084 16,274 18,545 Less: accumulated depreciation (5,542 ) (6,918 ) $ 10,732 $ 11,627

Goodwill and Other Intangible32

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 (In thousands) Goodwill $ 61,164 $ 63,423 Identified intangibles, net 1,964 2,708 $ 63,128 $ 66,131

Real Estate (Tables)

Real Estate (Tables)	12 Months Ended
	Dec. 31, 2015
Real Estate [Abstract]
Real Estate	Real estate consists of: Year-End 2015 Year-End 2014 Carrying Value Accumulated Depreciation Net Carrying Value Carrying Value Accumulated Depreciation Net Carrying Value (In thousands) Entitled, developed and under development projects $ 352,141 $ — $ 352,141 $ 321,273 $ — $ 321,273 Undeveloped land (includes land in entitlement) 98,181 — 98,181 93,182 — 93,182 Commercial Radisson Hotel & Suites 62,889 (29,268 ) 33,621 59,773 (29,062 ) 30,711 Harbor Lakes golf course and country club (a) — — — 2,054 (1,508 ) 546 Income producing properties Eleven 53,896 (2,861 ) 51,035 53,958 (576 ) 53,382 Midtown (a) — — — 33,293 (231 ) 33,062 Dillon 19,987 — 19,987 15,203 — 15,203 Music Row 9,947 — 9,947 7,675 — 7,675 Downtown Edge 12,706 — 12,706 11,856 — 11,856 West Austin 9,097 — 9,097 8,866 — 8,866 $ 618,844 $ (32,129 ) $ 586,715 $ 607,133 $ (31,377 ) $ 575,756

Oil and Gas Properties and Eq34

Oil and Gas Properties and Equipment, net (Tables)	12 Months Ended
	Dec. 31, 2015
Oil and Gas Properties [Abstract]
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]	Net capitalized costs, utilizing the successful efforts method of accounting, related to our oil and gas producing activities are as follows: At Year-End 2015 2014 (In thousands) Unproved leasehold interests $ 19,441 $ 90,446 Proved oil and gas properties 119,414 221,299 Total costs 138,855 311,745 Less accumulated depreciation, depletion and amortization (58,242 ) (48,252 ) $ 80,613 $ 263,493

Investment in Unconsolidated 35

Investment in Unconsolidated Ventures (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2015 2014 2015 2014 2015 2014 (In thousands) 242, LLC (b) $ 26,687 $ 33,021 $ — $ 6,940 $ 24,877 $ 21,789 $ 11,766 $ 10,098 CL Ashton Woods, LP (d) 7,654 13,269 — — 6,084 11,453 3,615 6,015 CL Realty, LLC 7,872 7,960 — — 7,662 7,738 3,831 3,869 CREA FMF Nashville LLC (b) 58,002 40,014 51,028 29,660 4,291 5,987 3,820 5,516 Elan 99, LLC 34,327 10,070 14,721 1 15,838 9,643 14,255 8,679 FMF Littleton LLC 52,528 26,953 22,499 — 24,370 24,435 6,270 6,287 FMF Peakview LLC 48,908 43,638 30,524 23,070 16,828 17,464 3,447 3,575 FOR/SR Forsyth LLC 6,500 — — — 6,500 — 5,850 — HM Stonewall Estates, Ltd. (d) 2,842 3,750 — 669 2,842 3,081 1,294 1,752 LM Land Holdings, LP (d) 32,008 25,561 7,752 4,448 22,751 18,500 9,664 9,322 MRECV DT Holdings LLC 4,215 — — — 4,215 — 3,807 — MRECV Edelweiss LLC 2,237 — — — 2,237 — 2,029 — MRECV Juniper Ridge 3,006 — — — 3,006 — 2,730 — MRECV Meadow Crossing II LLC 728 — — — 728 — 655 — Miramonte Boulder Pass, LLC 12,627 — 5,869 — 5,474 — 5,349 — PSW Communities, LP — 16,045 — 10,515 — 4,415 — 3,924 TEMCO Associates, LLC 5,284 11,756 — — 5,113 11,556 2,557 5,778 Other ventures (e) 4,201 8,453 2,269 26,944 1,922 (25,614 ) 1,514 190 $ 309,626 $ 240,490 $ 134,662 $ 102,247 $ 154,738 $ 110,447 $ 82,453 $ 65,005
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 2015 2014 2013 2015 2014 2013 2015 2014 2013 (In thousands) 242, LLC (b) $ 20,995 $ 5,612 $ 6,269 $ 9,588 $ 2,951 $ 1,512 $ 4,919 $ 1,514 $ 805 CJUF III, RH Holdings (c) — 2,168 120 — (956 ) (652 ) — (956 ) (652 ) CL Ashton Woods, LP (d) 9,820 5,431 9,018 3,881 1,748 2,660 5,000 2,471 4,169 CL Realty, LLC 856 1,573 1,603 424 1,068 1,028 212 534 514 CREA FMF Nashville LLC (b) 1,227 — — (1,696 ) (163 ) — (1,696 ) (163 ) — Elan 99, LLC — — — (49 ) (87 ) — (44 ) (78 ) — FMF Littleton LLC 120 — — (367 ) (239 ) — (92 ) (60 ) — FMF Peakview LLC 2,057 4 1 (1,116 ) (410 ) (252 ) (223 ) (83 ) (50 ) FOR/SR Forsyth LLC — — — — — — — — — HM Stonewall Estates, Ltd. (d) 3,990 1,728 2,922 1,881 613 1,082 952 248 452 LM Land Holdings, LP (d) 10,956 21,980 25,426 8,251 15,520 11,012 3,342 4,827 3,418 MRECV DT Holdings LLC — — — 167 — — — — — MRECV Edelweiss LLC — — — 151 — — 137 — — MRECV Juniper Ridge — — — 106 — — — — — Miramonte Boulder Pass, LLC — — — (250 ) — — (125 ) — — PSW Communities, LP 29,986 — — 2,688 (86 ) — 1,169 (76 ) — TEMCO Associates, LLC 9,485 2,155 630 2,358 494 96 1,179 247 48 Other ventures 36,237 1,792 5,994 33,303 4,835 176 1,278 260 33 $ 125,729 $ 42,443 $ 51,983 $ 59,320 $ 25,288 $ 16,662 $ 16,008 $ 8,685 $ 8,737 _____________________ (a) Total includes current maturities of $39,590,000 at year-end 2015 , of which $6,798,000 is non-recourse to us, and $65,795,000 at year-end 2014 , of which $42,566,000 is non-recourse to us. (b) Includes unamortized deferred gains on real estate contributed by us to ventures. We recognize deferred gains as income as real estate is sold to third parties. Deferred gains of $1,496,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2015 . (c) In 2014, we acquired full ownership in the Eleven venture for $21,500,000 . The acquisition-date fair value was $55,275,000 , including debt of $23,936,000 . Our investment in the Eleven venture prior to acquiring our partner’s interest was $2,229,000 . (d) Includes unrecognized basis difference of $34,000 which is reflected as a reduction of our investment in unconsolidated ventures at year-end 2015 . This difference between estimated fair value of the equity investment and our capital account within the respective ventures at closing will be accreted as income or expense over the life of the investment and included in our share of earnings (loss) from the respective ventures. (e) Our investment in other ventures reflects our ownership interests generally ranging from 40 to 75 percent , excluding venture losses that exceed our investment where we are not obligated to fund those losses. Please read Note 16 — Variable Interest Entities for additional information.

Receivables (Tables)

Receivables (Tables)	12 Months Ended
	Dec. 31, 2015
Receivables [Abstract]
Receivables	Receivables consist of: At Year-End 2015 2014 (In thousands) Funds held by qualified intermediary for potential 1031 like-kind exchange $ 14,703 $ — Oil and gas revenue accruals 3,745 7,293 Other receivables and accrued interest 2,448 6,505 Other loans secured by real estate, average interest rate of 11.31% at year-end 2015 and 4.41% at year-end 2014 2,130 1,737 Oil and gas joint interest billing receivables 867 5,738 Loan secured by real estate — 3,574 23,893 24,847 Allowance for bad debts (237 ) (258 ) $ 23,656 $ 24,589
Estimated Accretable Yield	Estimated accretable yield is as follows: At Year-End 2015 2014 (In thousands) Beginning of year $ 839 $ 8,908 Change in accretable yield due to change in timing of estimated cash flows 30 (166 ) Interest income recognized (869 ) (7,903 ) $ — $ 839

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Debt	Debt consists of: At Year-End 2015 2014 (In thousands) 8.50% senior secured notes due 2022 230,560 250,000 3.75% convertible senior notes due 2020, net of discount 106,762 103,194 6.00% tangible equity units, net of discount 8,768 17,154 Secured promissory notes — average interest rates of 3.42% at year-end 2015 and 3.17% at year-end 2014 15,400 15,400 Other indebtedness due through 2018 at variable and fixed interest rates ranging from 2.19% to 5.50% 28,292 46,996 $ 389,782 $ 432,744

Fair Value (Tables)

Fair Value (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 Year-End 2014 Carrying Amount Fair Value Carrying Amount Fair Value Valuation Technique (In thousands) Recurring Fair Value Measurements: Loan secured by real estate $ — $ — $ 3,574 $ 4,859 Level 2 Fixed rate debt $ (346,090 ) $ (321,653 ) $ (370,348 ) $ (359,131 ) Level 2
Carrying Value of Assets	Year-End 2015 Year-End 2014 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total (In thousands) Non-recurring Fair Value Measurements: Proved oil and gas properties $ — $ — $ 39,000 $ 39,000 $ — $ — $ 3,655 $ 3,655 Unproved leasehold interests $ — $ — $ 18,219 $ 18,219 $ — $ — $ — $ — Real estate $ — $ — $ 641 $ 641 $ — $ — $ 970 $ 970

Net Income (Loss) per Share (Ta

Net Income (Loss) per Share (Tables)	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
Earnings Attributable to Common Shareholders and Weighted Average Common Shares Outstanding	For the Year 2015 2014 2013 (In thousands) Numerator: Consolidated net income (loss) $ (212,371 ) $ 17,088 $ 35,061 Less: Net (income) attributable to noncontrolling interest (676 ) (505 ) (5,740 ) Income (loss) available for diluted earnings per share $ (213,047 ) $ 16,583 $ 29,321 Less: Undistributed net income allocated to participating securities — (3,018 ) (585 ) Income (loss) available to common shareholders for basic earnings per share $ (213,047 ) $ 13,565 $ 28,736 Denominator: Weighted average common shares outstanding — basic 34,266 35,317 35,365 Weighted average common shares upon conversion of participating securities (a) — 7,857 835 Dilutive effect of stock options, restricted stock and equity-settled awards — 422 613 Total weighted average shares outstanding — diluted 34,266 43,596 36,813 Anti-dilutive awards excluded from diluted weighted average shares outstanding 10,864 2,238 1,803 _____________________ (a) Our earnings per share calculation reflects the weighted average shares issuable upon settlement of the prepaid stock purchase contract component of our 6.00% tangible equity units, issued in 2013.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Income Tax Expense	Income tax (expense) benefit consists of: For the Year 2015 2014 2013 (In thousands) Current tax provision: U.S. Federal $ 8,579 $ (5,444 ) $ (6,004 ) State and other 47 (1,569 ) (2,066 ) 8,626 (7,013 ) (8,070 ) Deferred tax provision: U.S. Federal (38,366 ) (2,772 ) 1,148 State and other (2,895 ) 1,128 (286 ) (41,261 ) (1,644 ) 862 Income tax (expense) benefit $ (32,635 ) $ (8,657 ) $ (7,208 )
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 2015 2014 2013 Federal statutory rate (benefit) (35 %) 35 % 35 % State, net of federal benefit (1 ) 1 4 Valuation allowance 54 — — Recognition of previously unrecognized tax benefits — — (15 ) Noncontrolling interests — — (5 ) Goodwill — 1 — Charitable contributions — (1 ) — Oil and gas percentage depletion — (2 ) (2 ) Effective tax rate 18 % 34 % 17 %
Significant Components of Deferred Taxes	Significant components of deferred taxes are: At Year-End 2015 2014 (In thousands) Deferred Tax Assets: Real estate $ 69,594 $ 79,244 Employee benefits 15,752 17,352 Net operating loss carryforwards 13,827 3,012 Oil and gas properties 5,510 — AMT credits 3,620 — Income producing properties — 364 Oil and gas percentage depletion carryforwards 3,616 3,471 Accruals not deductible until paid 911 1,111 Other assets 139 — Gross deferred tax assets 112,969 104,554 Valuation allowance (97,068 ) (384 ) Deferred tax asset net of valuation allowance 15,901 104,170 Deferred Tax Liabilities: Oil and gas properties — (49,905 ) Undeveloped land (7,588 ) (4,937 ) Convertible debt (6,516 ) (7,816 ) Income producing properties (2,257 ) — Timber (577 ) (888 ) Gross deferred tax liabilities (16,938 ) (63,546 ) Net Deferred Tax Asset (Liability) $ (1,037 ) $ 40,624
Reconciliation of Beginning and Ending Amount of Tax Benefits Not Recognized for Book Purposes	A reconciliation of the beginning and ending amount of tax benefits not recognized for book purposes is as follows: At Year-End 2015 2014 2013 (In thousands) Balance at beginning of year $ — $ — $ 5,831 Reductions for tax positions of prior years — — — Reductions due to lapse of statute of limitations — — (5,831 ) Balance at end of year that would affect the annual effective tax rate if recognized $ — $ — $ —

Commitments and Other Conting41

Commitments and Other Contingencies Restructuring (Tables)	12 Months Ended
	Dec. 31, 2015
Restructuring and Related Activities [Abstract]
Restructuring and Related Costs [Table Text Block]	The following table summarizes activity related to liabilities associated with our oil and gas restructuring activities in 2015: Employee-Related Costs Lease Termination Charge Total (In thousands) Balance at year-end 2014 $ (2,367 ) $ — $ (2,367 ) Additions (2,047 ) (1,750 ) (3,797 ) Payments 3,365 1,750 5,115 Balance at year-end 2015 $ (1,049 ) $ — $ (1,049 )

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2015
Segment Reporting [Abstract]
Segment Revenues and Earnings	Real Estate Oil and Gas Other Natural Resources Items Not Allocated to Segments Total (In thousands) For the year or at year-end 2015 Revenues $ 202,830 $ 52,939 $ 6,652 $ — $ 262,421 Depreciation, depletion and amortization 7,605 28,774 540 8,166 45,085 Equity in earnings of unconsolidated ventures 15,582 275 151 — 16,008 Income (loss) before taxes 67,678 (184,396 ) (608 ) (63,086 ) (a) (180,412 ) Total assets 691,406 144,436 19,106 125,565 980,513 Investment in unconsolidated ventures 82,453 — — — 82,453 Capital expenditures (b) 13,644 49,776 745 242 64,407 For the year or at year-end 2014 Revenues $ 213,112 $ 84,300 $ 9,362 $ — $ 306,774 Depreciation, depletion and amortization 3,741 29,442 497 8,035 41,715 Equity in earnings of unconsolidated ventures 8,068 586 31 — 8,685 Income (loss) before taxes 96,906 (22,686 ) 5,499 (54,479 ) (a) 25,240 Total assets 654,774 342,703 22,531 238,191 1,258,199 Investment in unconsolidated ventures 65,005 — — — 65,005 Capital expenditures (b) 28,980 103,385 5,817 616 138,798 For the year or at year-end 2013 Revenues $ 248,011 $ 72,313 $ 10,721 $ — $ 331,045 Depreciation, depletion and amortization 3,117 19,552 651 6,660 29,980 Equity in earnings of unconsolidated ventures 8,089 592 56 — 8,737 Income (loss) before taxes 68,454 18,859 6,507 (57,291 ) (a) 36,529 Total assets 582,802 312,553 23,478 253,319 1,172,152 Investment in unconsolidated ventures 41,147 — — — 41,147 Capital expenditures (b) 7,265 97,696 2,720 216 107,897 _____________________ (a) Items not allocated to segments consist of: For the Year 2015 2014 2013 (In thousands) General and administrative expense $ (24,802 ) $ (21,229 ) $ (20,597 ) Share-based and long-term incentive compensation expense (4,474 ) (3,417 ) (16,809 ) Interest expense (34,066 ) (30,286 ) (20,004 ) Other corporate non-operating income 256 453 119 $ (63,086 ) $ (54,479 ) $ (57,291 ) (b) Consists of expenditures for oil and gas properties and equipment, commercial and income producing properties, property, plant and equipment and reforestation of timber.

Share-Based Compensation (Table

Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2013 (In thousands) Cash-settled awards $ (3,127 ) $ (3,710 ) $ 7,774 Equity-settled awards 5,026 5,168 4,281 Restricted stock (8 ) (25 ) 538 Stock options 2,355 1,984 4,216 Total share-based compensation $ 4,246 $ 3,417 $ 16,809 Deferred cash 228 — — $ 4,474 $ 3,417 $ 16,809
Share-Based Compensation Expense (Income) Included in Operating Expense	Share-based and long-term incentive compensation expense is included in: For the Year 2015 2014 2013 (In thousands) General and administrative $ 2,451 $ 1,001 $ 7,779 Other operating 2,023 2,416 9,030 $ 4,474 $ 3,417 $ 16,809
Summarized Activity of Cash-Settled Restricted Stock Unit Awards	The following table summarizes the activity of cash-settled restricted stock unit awards in 2015 : Equivalent Units Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 185 $18.49 Granted 60 13.26 Vested (117 ) 18.26 Forfeited (11 ) 18.83 Non-vested at end of period 117 16.00
Summarized Activity of Cash-Settled Stock Appreciation Rights	The following table summarizes the activity of cash-settled stock appreciation rights in 2015 : 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 458 $12.54 4 $1,732 Granted 90 14.08 Exercised (39 ) 9.29 Forfeited (22 ) 15.00 Balance at end of period 487 12.97 4 404 Exercisable at end of period 414 12.77 3 404
Summarized Activity of Equity-Settled Awards	The following table summarizes the activity of equity-settled awards in 2015 : Equivalent Units Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 710 $ 19.24 Granted 395 12.99 Vested (340 ) 14.23 Forfeited (134 ) 18.18 Non-vested at end of period 631 18.25
Schedule of Fair Value Assumptions of MSU Awards	We estimate the grant date fair value of MSU awards using a Monte Carlo simulation pricing model and the following assumptions: For the Year 2015 2014 2013 Expected stock price volatility 32.9 % 42.2 % 42.2 % Risk-free interest rate 1.0 % 0.7 % 0.4 % Expected dividend yield — % — % — % Weighted average grant date fair value of MSU awards (per unit) $ 15.11 $ 20.38 $ 21.09
Summarized Activity of Restricted Stock Awards	The following table summarizes the activity of restricted stock awards in 2015 : Restricted Shares Weighted Average Grant Date Fair Value (In thousands) (Per unit) Non-vested at beginning of period 17 $ 17.56 Granted — — Vested (7 ) 14.59 Forfeited (6 ) 19.00 Non-vested at end of period 4 20.55
Summarized Activity of Stock Option Awards	The following table summarizes the activity of stock option awards in 2015 : Options Outstanding Weighted Average Exercise Price Weighted Average Remaining Contractual Term Aggregate Intrinsic Value (Current Value Less Exercise Price) (In thousands) (Per share) (In years) (In thousands) Balance at beginning of period 1,861 $ 20.74 6 $ 643 Granted 413 13.86 Exercised — — Forfeited (103 ) 18.01 Balance at end of period 2,171 19.56 5 156 Exercisable at end of period 1,687 20.83 4 156
Schedule of Fair Value Assumptions of Stock Options	We estimated the fair value of these options with market conditions using Monte Carlo simulation pricing model and the following assumptions: For the Year 2015 Expected stock price volatility 61.4 % Risk-free interest rate 2.2 % Expected dividend yield — % Weighted average grant date fair value of options (per share) $ 7.87 We estimate the grant date fair value of stock options that do not have a market condition using the Black-Scholes option pricing model and the following assumptions: For the Year 2015 2013 Expected stock price volatility 45.6 % 66.8 % Risk-free interest rate 1.8 % 1.4 % Expected life of options (years) 6 6 Expected dividend yield — % — % Weighted average grant date fair value of options (per share) $ 6.51 $ 11.47

Supplemental Oil and Gas Disc44

Supplemental Oil and Gas Disclosures (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2015
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 2012 3,220 11,722 Revisions of previous estimates 182 1,243 Extensions and discoveries 3,085 2,046 Acquisitions 35 531 Production (698 ) (1,912 ) Year-end 2013 5,824 13,630 Revisions of previous estimates 608 293 Extensions and discoveries 2,191 774 Acquisitions 85 31 Sales (105 ) (218 ) Production (931 ) (1,861 ) Year-end 2014 7,672 12,649 Revisions of previous estimates (855 ) (1,675 ) Extensions and discoveries 224 173 Acquisitions — — Sales (704 ) (1,223 ) Production (1,158 ) (1,967 ) Year-end 2015 5,179 7,957 Our share of ventures accounted for using the equity method: Year-end 2012 — 2,572 Revisions of previous estimates — 7 Production — (247 ) Year-end 2013 — 2,332 Revisions of previous estimates — (382 ) Production — (199 ) Year-end 2014 — 1,751 Revisions of previous estimates — (320 ) Production — (168 ) Year-end 2015 — 1,263 Total consolidated and our share of equity method ventures: Year-end 2013 Proved developed reserves 3,893 13,717 Proved undeveloped reserves 1,931 2,245 Total Year-end 2013 5,824 15,962 Year-end 2014 Proved developed reserves 5,269 12,599 Proved undeveloped reserves 2,403 1,801 Total Year-end 2014 7,672 14,400 Year-end 2015 Proved developed reserves 5,179 9,220 Proved undeveloped reserves — — Total Year-end 2015 5,179 9,220
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]	Net capitalized costs, utilizing the successful efforts method of accounting, related to our oil and gas producing activities are as follows: At Year-End 2015 2014 (In thousands) Unproved leasehold interests $ 19,441 $ 90,446 Proved oil and gas properties 119,414 221,299 Total costs 138,855 311,745 Less accumulated depreciation, depletion and amortization (58,242 ) (48,252 ) $ 80,613 $ 263,493
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 2015 2014 2013 (In thousands) Consolidated entities: Acquisition costs Proved properties $ — $ 2,001 $ — Unproved properties 4,832 25,666 35,806 Exploration costs 17,922 39,399 10,486 Development costs 27,609 40,277 54,538 $ 50,363 $ 107,343 $ 100,830
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 2015 2014 2013 (In thousands) Consolidated entities: Future cash inflows $ 216,588 $ 665,657 $ 544,098 Future production and development costs (93,623 ) (271,735 ) (231,801 ) Future income tax expenses (22,218 ) (106,002 ) (77,361 ) Future net cash flows 100,747 287,920 234,936 10% annual discount for estimated timing of cash flows (33,951 ) (124,079 ) (99,383 ) Standardized measure of discounted future net cash flows $ 66,796 $ 163,841 $ 135,553 Our share in ventures accounted for using the equity method: Future cash inflows $ 2,283 $ 6,186 $ 4,765 Future production and development costs (245 ) (664 ) (512 ) Future income tax expenses (774 ) (2,098 ) (1,616 ) Future net cash flows 1,264 3,424 2,637 10% annual discount for estimated timing of cash flows (562 ) (1,649 ) (1,337 ) Standardized measure of discounted future net cash flows $ 702 $ 1,775 $ 1,300 Total consolidated and our share of equity method ventures $ 67,498 $ 165,616 $ 136,853
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 2012 $ 106,543 $ 1,413 $ 107,956 Changes resulting from: Net change in sales prices and production costs 23,422 415 23,837 Net change in future development costs (2,897 ) — (2,897 ) Sales of oil and gas, net of production costs (56,559 ) (801 ) (57,360 ) Net change due to extensions and discoveries 54,539 — 54,539 Net change due to acquisition of reserves 1,160 — 1,160 Net change due to revisions of quantity estimates 8,673 6 8,679 Previously estimated development costs incurred 4,124 — 4,124 Accretion of discount 13,540 228 13,768 Net change in timing and other (718 ) (31 ) (749 ) Net change in income taxes (16,274 ) 70 (16,204 ) Aggregate change for the year 29,010 (113 ) 28,897 Year-end 2013 135,553 1,300 136,853 Changes resulting from: Net change in sales prices and production costs (1,064 ) 1,571 507 Net change in future development costs 1,308 — 1,308 Sales of oil and gas, net of production costs (63,192 ) (787 ) (63,979 ) Net change due to extensions and discoveries 58,228 — 58,228 Net change due to acquisition of reserves 2,778 — 2,778 Net change due to divestitures of reserves (5,804 ) — (5,804 ) Net change due to revisions of quantity estimates 15,303 (343 ) 14,960 Previously estimated development costs incurred 15,497 — 15,497 Accretion of discount 18,067 210 18,277 Net change in timing and other 4,198 115 4,313 Net change in income taxes (17,031 ) (291 ) (17,322 ) Aggregate change for the year 28,288 475 28,763 Year-end 2014 163,841 1,775 165,616 Changes resulting from: Net change in sales prices and production costs (136,536 ) (1,112 ) (137,648 ) Net change in future development costs 92 — 92 Sales of oil and gas, net of production costs (31,732 ) (428 ) (32,160 ) Net change due to extensions and discoveries 11,747 — 11,747 Net change due to acquisition of reserves — — — Net change due to divestitures of reserves (15,855 ) (15,855 ) Net change due to revisions of quantity estimates (15,164 ) (267 ) (15,431 ) Previously estimated development costs incurred 15,096 — 15,096 Accretion of discount 22,600 286 22,886 Net change in timing and other 4,018 (210 ) 3,808 Net change in income taxes 48,689 658 49,347 Aggregate change for the year (97,045 ) (1,073 ) (98,118 ) Year-end 2015 $ 66,796 $ 702 $ 67,498
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 2015 2014 2013 (In thousands) Consolidated entities Revenues $ 51,553 $ 82,919 $ 69,036 Production costs (19,820 ) (19,727 ) (12,477 ) Exploration costs (11,864 ) (17,416 ) (10,486 ) Depreciation, depletion, amortization (28,774 ) (29,442 ) (19,552 ) Non-cash impairment of proved oil and gas properties and unproved leasehold interests (164,831 ) (32,665 ) (473 ) Oil and gas administrative expenses (11,700 ) (17,000 ) (14,407 ) Accretion expense (144 ) (121 ) (94 ) Income tax expenses 14,717 13,398 (3,471 ) Results of operations (170,863 ) (20,054 ) 8,076 Our share in ventures accounted for using the equity method: Revenues $ 428 $ 786 $ 801 Production costs (102 ) (105 ) (123 ) Oil and gas administrative expenses (51 ) (95 ) (86 ) Income tax expenses 21 (235 ) (178 ) Results of operations $ 296 $ 351 $ 414 Total results of operations $ (170,567 ) $ (19,703 ) $ 8,490
Consolidated Entities [Member]
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]	Capitalized costs related to our oil and gas producing activities are as follows: At Year-End 2015 2014 (In thousands) Consolidated entities: Unproved oil and gas properties $ 19,441 $ 90,446 Proved oil and gas properties 119,414 221,299 Total costs 138,855 311,745 Less accumulated depreciation, depletion and amortization (58,242 ) (48,252 ) $ 80,613 $ 263,493

Summary of Quarterly Results 45

Summary of Quarterly Results of Operations (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Summary of Quarterly Results of Operations	Summarized quarterly financial results for 2015 and 2014 follows: First Quarter (a) Second Quarter (a) Third Quarter (a) Fourth Quarter (a) (In thousands, except per share amounts) 2015 Total revenues $ 47,805 $ 57,430 $ 43,168 $ 114,018 Gross profit (loss) 17,289 (35,009 ) (69,572 ) 8,341 Operating income (loss) (7,737 ) (52,714 ) (94,751 ) (9,482 ) Equity in earnings of unconsolidated ventures 3,045 5,584 2,909 4,470 Income (loss) before taxes (12,596 ) (55,062 ) (100,095 ) (11,983 ) Net income (loss) attributable to Forestar Group Inc. (8,158 ) (34,507 ) (164,216 ) (6,166 ) Net income (loss) per share — basic $ (0.24 ) $ (1.01 ) $ (4.79 ) $ (0.18 ) Net income (loss) per share — diluted $ (0.24 ) $ (1.01 ) $ (4.79 ) $ (0.18 ) 2014 Total revenues $ 84,605 $ 83,013 $ 58,840 $ 80,316 Gross profit (loss) 35,025 33,261 19,606 (6,259 ) Operating income (loss) 15,883 26,942 12,716 (16,783 ) Equity in earnings of unconsolidated ventures 991 958 2,016 4,720 Income (loss) before taxes 13,665 22,799 7,994 (18,713 ) Net income (loss) attributable to Forestar Group Inc. 8,334 14,822 5,227 (11,800 ) Net income (loss) per share — basic $ 0.20 $ 0.34 $ 0.12 $ (0.34 ) Net income (loss) per share — diluted $ 0.19 $ 0.34 $ 0.12 $ (0.34 ) _____________________ (a) Non-cash impairment charges for 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) 2015 $ 7 $ 45,938 $ 81,240 $ 37,646 2014 755 584 735 30,591

Summary of Significant Accoun46

Summary of Significant Accounting Policies - Additional Information (Detail) a in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)a	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Significant Accounting Policies [Line Items]
Capitalized Exploratory Well Costs	$ 0	$ 8,575,000
Capitalized Exploratory Well Cost, Charged to Expense	8,454,000
Capital Expenditures Incurred but Not yet Paid	7,033,000	19,405,000
Restricted cash and cash equivalents	$ 200,000	217,000
Contractual Period Of Sale Contracts	5 years
Non-Oil And Gas Properties [Member]
Significant Accounting Policies [Line Items]
Depreciation expense of property and equipment	$ 1,067,000	903,000	$ 1,028,000
Minimum [Member]
Significant Accounting Policies [Line Items]
Reimbursement range on water, sewer and other infrastructure-related assets	70.00%
Maximum [Member]
Significant Accounting Policies [Line Items]
Reimbursement range on water, sewer and other infrastructure-related assets	90.00%
Capitalize reforestation costs	2 years
Computer Software, Intangible Asset [Member]
Significant Accounting Policies [Line Items]
Carrying value of capitalized software	$ 237,000	1,188,000
Capitalized software amortization	$ 996,000	1,067,000	1,593,000
Computer Software, Intangible Asset [Member] | Minimum [Member]
Significant Accounting Policies [Line Items]
Useful life range	3 years
Computer Software, Intangible Asset [Member] | Maximum [Member]
Significant Accounting Policies [Line Items]
Useful life range	5 years
Georgia [Member]
Significant Accounting Policies [Line Items]
Timber owned directly or through ventures | a	89
Depletion	$ 250,000	$ 371,000	$ 609,000

Summary of Significant Accoun47

Summary of Significant Accounting Policies - Schedule of Change in Asset Retirement Obligation (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation [Roll Forward]
Beginning balance	$ 1,807	$ 1,483
Accretion expense	144	122
Additions	65	314
Asset Retirement Obligation, Liabilities Settled	(119)	(230)
Asset Retirement Obligation, Revision of Estimate	0	118
Asset Retirement Obligation, Cash Paid to Settle	139	0
Ending balance	$ 1,758	$ 1,807

Summary of Significant Accoun48

Summary of Significant Accounting Policies - Estimated Useful Lives of Property Plant and Equipment (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Property plant and equipment, gross	$ 16,274	$ 18,545
Less: accumulated depreciation	(5,542)	(6,918)
Property Plant And Equipment, Net	10,732	11,627
Building and Building Improvements [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment, gross	4,044	4,461
Property and Equipment [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment, gross	$ 12,230	$ 14,084
Minimum [Member] | Building and Building Improvements [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment, useful life	10 years
Minimum [Member] | Property and Equipment [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment, useful life	2 years
Maximum [Member] | Building and Building Improvements [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment, useful life	40 years
Maximum [Member] | Property and Equipment [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment, useful life	10 years

Goodwill and Other Intangible49

Goodwill and Other Intangible Assets - Carrying Value of Goodwill and Other Intangible Assets (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	$ 61,164	$ 63,423
Identified intangibles, net	1,964	2,708
Total	$ 63,128	$ 66,131

Goodwill and Other Intangible50

Goodwill and Other Intangible Assets - Additional Information (Detail) - USD ($)	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2010
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Goodwill acquired on acquisition	$ 61,164,000	$ 63,423,000
Oil and Gas Properties [Member]
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Goodwill acquired on acquisition	57,290,000	59,549,000
Water Resources Company [Member]
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Goodwill acquired on acquisition		3,874,000
Water Resources Company [Member] | Groundwater Leases [Member]
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Identified intangible assets			$ 1,681,000
Patents [Member] | Credo [Member]
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Identified intangibles, net	$ 283,000
Multi Family Property [Member] | Austin, Texas [Member]
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Identified intangibles, net		$ 865,000

Real Estate - Real Estate (Deta

Real Estate - Real Estate (Detail) - USD ($) $ in Thousands	Dec. 31, 2015		Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Real Estate Properties [Line Items]
Accumulated depreciation	$ (32,129)		$ (31,377)	$ (28,066)	$ (28,220)
SEC Schedule III, Real Estate, Gross	618,844		607,133	$ 547,530	$ 545,370
Total Real Estate	586,715		575,756
West Austin [Member]
Real Estate Properties [Line Items]
Carrying value	9,097		8,866
Accumulated depreciation	0		0
Net carrying value	9,097		8,866
Downtown Edge [Member]
Real Estate Properties [Line Items]
Carrying value	12,706		11,856
Accumulated depreciation	0		0
Net carrying value	12,706		11,856
Music Row [Member]
Real Estate Properties [Line Items]
Carrying value	9,947		7,675
Accumulated depreciation	0		0
Net carrying value	9,947		7,675
Dillon [Member]
Real Estate Properties [Line Items]
Carrying value	19,987		15,203
Accumulated depreciation	0		0
Net carrying value	19,987		15,203
Midtown [Member]
Real Estate Properties [Line Items]
Carrying value	0	[1]	33,293
Accumulated depreciation	0	[1]	(231)
Net carrying value	0	[1]	33,062
Eleven [Member]
Real Estate Properties [Line Items]
Carrying value	53,896		53,958
Accumulated depreciation	(2,861)		(576)
Net carrying value	51,035		53,382
Harbor Lakes [Member]
Real Estate Properties [Line Items]
Carrying value	0	[1]	2,054
Accumulated depreciation	0	[1]	(1,508)
Net carrying value	0	[1]	546
Radisson Hotel [Member]
Real Estate Properties [Line Items]
Carrying value	62,889		59,773
Accumulated depreciation	(29,268)		(29,062)
Net carrying value	33,621		30,711
Undeveloped land (includes land in entitlement) [Member] [Member]
Real Estate Properties [Line Items]
Carrying value	98,181		93,182
Accumulated depreciation	0		0
Net carrying value	98,181		93,182
Entitled, developed and under development projects [Member]
Real Estate Properties [Line Items]
Carrying value	352,141		321,273
Accumulated depreciation	0		0
Net carrying value	$ 352,141		$ 321,273
[1]	Sold in 2015.

Real Estate - Additional Inform

Real Estate - Additional Information (Detail)	12 Months Ended				108 Months Ended
	Dec. 31, 2015USD ($)Property		Dec. 31, 2014USD ($)Property	Dec. 31, 2013USD ($)	Dec. 31, 2015USD ($)Property		Sep. 30, 2014USD ($)
Real Estate Properties [Line Items]
Costs relate to water, sewer and other infrastructure assets					$ 54,376,000
Recovery of direct costs	$ (15,176,000)		$ (66,047,000)	$ (9,945,000)
GAIN ON SALE OF ASSETS	879,000		38,038,000	5,161,000
Investment in resort development	586,715,000		575,756,000		586,715,000
General Contractor Costs	1,543,000		5,111,000	554,000
Non-cash asset impairment charges	108,184,000		15,934,000	1,790,000
Payments to Acquire and Develop Real Estate	107,988,000		114,694,000	106,609,000
Cibolo Canyons Project [Member]
Real Estate Properties [Line Items]
Recovery of direct costs					34,703,000
Payments Received From Special Improvement District	425,000
GAIN ON SALE OF ASSETS	1,160,000		6,577,000
Investment in resort development							$ 24,067,000
Cibolo Canyons Project [Member] | San Antonio Texas [Member]
Real Estate Properties [Line Items]
Cost of asset in developed and under development projects	$ 22,302,000		31,913,000		$ 22,302,000
Multi Family Property [Member] | Austin, Texas [Member]
Real Estate Properties [Line Items]
Carrying value			$ 53,917,000
Number Of Units Of Multifamily Project | Property	257		257		257
Business Combination, Step Acquisition, Equity Interest in Acquiree, Percentage			25.00%
Payments to Acquire Businesses and Interest in Affiliates			$ 21,500,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net			55,275,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt			23,936,000
Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value			2,229,000
Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value			9,839,000
Business Combination, Step Acquisition, Equity Interest in Acquiree, Remeasurement Gain			7,610,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Prepaid Expense and Other Assets			992,000
Identified intangibles, net			865,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Working Capital			979,000
Consolidated Properties [Member]
Real Estate Properties [Line Items]
Recovery of direct costs	$ 14,751,000
Utility and Improvement District [Member]
Real Estate Properties [Line Items]
Cost of asset in developed and under development projects	67,554,000		65,212,000		$ 67,554,000
Income Producing Properties [Member] | Land, Buildings and Improvements [Member]
Real Estate Properties [Line Items]
Depreciation expense, related to commercial and income producing properties	6,810,000		3,319,000	$ 2,507,000
Real Estate [Member]
Real Estate Properties [Line Items]
Non-cash asset impairment charges	1,044,000		399,000
Bonds [Member] | Cibolo Canyons Project [Member]
Real Estate Properties [Line Items]
Payments Received From Special Improvement District	46,500,000		50,550,000
Debt Instrument, Face Amount	48,900,000				48,900,000
Letters of Credit Outstanding, Amount	6,846,000				6,846,000
Surety Bond for Bond Trustee	7,850,000				7,850,000
Midtown [Member]
Real Estate Properties [Line Items]
Carrying value	$ 0	[1]	$ 33,293,000		$ 0	[1]
Number Of Units Of Multifamily Project | Property	354				354
Real Estate Property Sale Price	$ 42,880,000
Segment Earnings From Sale of Multifamily Property	9,265,000
Proceeds from sale of multifamily property	18,473,000
Repayments of Debt	$ 24,166,000
[1]	Sold in 2015.

Oil and Gas Properties and Eq53

Oil and Gas Properties and Equipment, net (Details)	3 Months Ended								12 Months Ended
	Dec. 31, 2015USD ($)aWell	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Sep. 30, 2014USD ($)	Jun. 30, 2014USD ($)	Mar. 31, 2014USD ($)	Dec. 31, 2015USD ($)aWell	Dec. 31, 2014USD ($)
Impairment of Oil and Gas Properties	$ 37,646,000	$ 81,240,000	$ 45,938,000	$ 7,000	$ 30,591,000	$ 735,000	$ 584,000	$ 755,000	$ 164,831,000	$ 32,665,000
Impairment of Leasehold									57,691,000	17,130,000
Impairment of Oil and Gas Properties									107,140,000	$ 15,535,000
Loss on Disposition of Proved Property									706,000
Proceeds from Sale of Oil and Gas Property and Equipment									$ 17,800,000
Transaction [Domain]
Gas and Oil Area, Undeveloped, Net | a	109,000								109,000
Productive Oil Wells, Number of Wells, Gross | Well	39								39
Productive Oil Wells, Number of Wells, Net | Well	7								7

Oil and Gas Properties and Eq54

Oil and Gas Properties and Equipment, net Properties and Equipment, net - Net Capitalized Costs Related to Oil and Gas Producing Activities (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Oil and Gas Properties [Abstract]
Unproved oil and gas properties	$ 19,441	$ 90,446
Proved Oil and Gas Property, Successful Effort Method	119,414	221,299
Total costs	138,855	311,745
Oil and Gas Property, Successful Effort Method, Accumulated Depreciation, Depletion and Amortization	(58,242)	(48,252)
Oil and Gas Property, Successful Effort Method, Net	$ 80,613	$ 263,493

Investment In Unconsolidated 55

Investment In Unconsolidated Ventures - Additional Information (Detail)		12 Months Ended
		Dec. 31, 2015USD ($)PropertyVenture	Dec. 31, 2014USD ($)Property	Dec. 31, 2013USD ($)
Payments to Acquire Additional Interest in Subsidiaries		$ 0	$ 7,971,000	$ 0
Noncontrolling interests		0	2,904,000	2,907,000
Investment in unconsolidated ventures		$ 82,453,000	65,005,000	41,147,000
Number of ventures under ownership interest using equity method | Venture		20
Payments to Acquire Interest in Joint Venture		$ 0	20,155,000
Distributions		24,909,000	7,518,000	9,854,000
Fees for services		1,856,000	2,275,000	1,068,000
Equity Method Investee [Member]
Payments to Acquire Interest in Joint Venture		26,349,000	14,692,000	857,000
FMF Littleton [Member]
Construction Loan	[1]	22,499,000
Investment in unconsolidated ventures		6,270,000	6,287,000
CREA FMF [Member]
Investment in unconsolidated ventures	[2]	3,820,000	5,516,000
Elan 99 LLC [Member]
Investment in unconsolidated ventures		14,255,000	8,679,000
Construction Loans [Member] | CREA FMF [Member] | Nashville, Tennessee [Member]
Construction Loan	[1],[2]	51,028,000
Construction Loans [Member] | Elan 99 LLC [Member] | Houston, Texas [Member]
Construction Loan	[1]	$ 14,721,000
Multi Family Property [Member]
Payments to Acquire Interest in Joint Venture				$ 0
Multi Family Property [Member] | Austin, Texas [Member]
Payments to Acquire Additional Interest in Subsidiaries			$ 21,500,000
Number Of Units Of Multifamily Project | Property		257	257
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net			$ 55,275,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt			23,936,000
Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value			$ 2,229,000
[1]	Total includes current maturities of $39,590,000 at year-end 2015, of which $6,798,000 is non-recourse to us, and $65,795,000 at year-end 2014, of which $42,566,000 is non-recourse to us.
[2]	Includes unamortized deferred gains on real estate contributed by us to ventures. We recognize deferred gains as income as real estate is sold to third parties. Deferred gains of $1,496,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2015.

Investment In Unconsolidated 56

Investment In Unconsolidated Ventures - Summarized Balance Sheet Information (Detail) - USD ($)		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule of Equity Method Investments [Line Items]
Venture Assets		$ 309,626,000	$ 240,490,000
Venture Borrowings	[1]	134,662,000	102,247,000
Venture Equity		154,738,000	110,447,000
Investment in unconsolidated ventures		82,453,000	65,005,000	$ 41,147,000
242, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	[2]	26,687,000	33,021,000
Venture Borrowings	[1],[2]	0	6,940,000
Venture Equity	[2]	24,877,000	21,789,000
Investment in unconsolidated ventures	[2]	11,766,000	10,098,000
Elan 99 LLC [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets		34,327,000	10,070,000
Venture Borrowings	[1]		1,000
Venture Equity		15,838,000	9,643,000
Investment in unconsolidated ventures		14,255,000	8,679,000
CL Ashton Woods [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	[3]	7,654,000	13,269,000
Venture Borrowings	[1],[3]	0	0
Venture Equity	[3]	6,084,000	11,453,000
Investment in unconsolidated ventures	[3]	3,615,000	6,015,000
CL Realty [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets		7,872,000	7,960,000
Venture Borrowings	[1]	0	0
Venture Equity		7,662,000	7,738,000
Investment in unconsolidated ventures		3,831,000	3,869,000
CREA FMF [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	[2]	58,002,000	40,014,000
Venture Borrowings	[1],[2]		29,660,000
Venture Equity	[2]	4,291,000	5,987,000
Investment in unconsolidated ventures	[2]	3,820,000	5,516,000
FMF Littleton [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets		52,528,000	26,953,000
Construction Loan	[1]	22,499,000
Venture Borrowings	[1]		0
Venture Equity		24,370,000	24,435,000
Investment in unconsolidated ventures		6,270,000	6,287,000
FMF Peakview [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets		48,908,000	43,638,000
Venture Borrowings	[1]	30,524,000	23,070,000
Venture Equity		16,828,000	17,464,000
Investment in unconsolidated ventures		3,447,000	3,575,000
FOR/SR Forsyth LLC [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets		6,500,000	0
Venture Borrowings		0	0
Venture Equity		6,500,000	0
Investment in unconsolidated ventures		5,850,000	0
HM Stonewall Estates [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	[3]	2,842,000	3,750,000
Venture Borrowings	[1],[3]	0	669,000
Venture Equity	[3]	2,842,000	3,081,000
Investment in unconsolidated ventures	[3]	1,294,000	1,752,000
LM Land Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	[3]	32,008,000	25,561,000
Venture Borrowings	[1],[3]	7,752,000	4,448,000
Venture Equity	[3]	22,751,000	18,500,000
Investment in unconsolidated ventures	[3]	9,664,000	9,322,000
MRECV DT Holdings LLC [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets		4,215,000	0
Venture Borrowings	[1]	0	0
Venture Equity		4,215,000	0
Investment in unconsolidated ventures		3,807,000	0
MRECV Edelweiss LLC [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets		2,237,000	0
Venture Borrowings	[1]	0	0
Venture Equity		2,237,000	0
Investment in unconsolidated ventures		2,029,000	0
MRECV Juniper Ridge LLC [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets		3,006,000	0
Venture Borrowings	[1]	0	0
Venture Equity		3,006,000	0
Investment in unconsolidated ventures		2,730,000	0
MRECV Meadow Crossing II LLC [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets		728,000	0
Venture Borrowings	[1]	0	0
Venture Equity		728,000	0
Investment in unconsolidated ventures		655,000	0
Miramonte Boulder Pass, LLC [Member] [Domain]
Schedule of Equity Method Investments [Line Items]
Venture Assets		12,627,000	0
Venture Borrowings	[1]	5,869,000	0
Venture Equity		5,474,000	0
Investment in unconsolidated ventures		5,349,000	0
PSW Communities [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets		0	16,045,000
Venture Borrowings	[1]	0	10,515,000
Venture Equity		0	4,415,000
Investment in unconsolidated ventures		0	3,924,000
Temco [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets		5,284,000	11,756,000
Venture Borrowings	[1]	0	0
Venture Equity		5,113,000	11,556,000
Investment in unconsolidated ventures		2,557,000	5,778,000
Other Ventures [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	[4]	4,201,000	8,453,000
Venture Borrowings	[1],[4]	2,269,000	26,944,000
Venture Equity	[4]	1,922,000	(25,614,000)
Investment in unconsolidated ventures	[4]	$ 1,514,000	$ 190,000
[1]	Total includes current maturities of $39,590,000 at year-end 2015, of which $6,798,000 is non-recourse to us, and $65,795,000 at year-end 2014, of which $42,566,000 is non-recourse to us.
[2]	Includes unamortized deferred gains on real estate contributed by us to ventures. We recognize deferred gains as income as real estate is sold to third parties. Deferred gains of $1,496,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2015.
[3]	Includes unrecognized basis difference of $34,000 which is reflected as a reduction of our investment in unconsolidated ventures at year-end 2015. This difference between estimated fair value of the equity investment and our capital account within the respective ventures at closing will be accreted as income or expense over the life of the investment and included in our share of earnings (loss) from the respective ventures.
[4]	Our investment in other ventures reflects our ownership interests generally ranging from 40 to 75 percent, excluding venture losses that exceed our investment where we are not obligated to fund those losses. Please read Note 16 — Variable Interest Entities for additional information.

Investment In Unconsolidated 57

Investment In Unconsolidated Ventures - Summarized Income Statement Information (Detail) - USD ($) $ in Thousands		3 Months Ended																12 Months Ended
		Dec. 31, 2015	[1]	Sep. 30, 2015	[1]	Jun. 30, 2015	[1]	Mar. 31, 2015	[1]	Dec. 31, 2014	[1]	Sep. 30, 2014	[1]	Jun. 30, 2014	[1]	Mar. 31, 2014	[1]	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule of Equity Method Investments [Line Items]
Revenues																		$ 125,729	$ 42,443	$ 51,983
Earnings (Loss)																		59,320	25,288	16,662
Our share of earnings (loss)		$ 4,470		$ 2,909		$ 5,584		$ 3,045		$ 4,720		$ 2,016		$ 958		$ 991		16,008	8,685	8,737
242, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Revenues	[2]																	20,995	5,612	6,269
Earnings (Loss)	[2]																	9,588	2,951	1,512
Our share of earnings (loss)	[2]																	4,919	1,514	805
CJUF III, RH Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Revenues	[3]																	0	2,168	120
Earnings (Loss)	[3]																	0	(956)	(652)
Our share of earnings (loss)	[3]																	0	(956)	(652)
CL Ashton Woods [Member]
Schedule of Equity Method Investments [Line Items]
Revenues	[4]																	9,820	5,431	9,018
Earnings (Loss)	[4]																	3,881	1,748	2,660
Our share of earnings (loss)	[4]																	5,000	2,471	4,169
CL Realty [Member]
Schedule of Equity Method Investments [Line Items]
Revenues																		856	1,573	1,603
Earnings (Loss)																		424	1,068	1,028
Our share of earnings (loss)																		212	534	514
CREA FMF [Member]
Schedule of Equity Method Investments [Line Items]
Revenues	[2]																	1,227	0	0
Earnings (Loss)	[2]																	(1,696)	(163)	0
Our share of earnings (loss)	[2]																	(1,696)	(163)	0
Elan 99 LLC [Member]
Schedule of Equity Method Investments [Line Items]
Revenues																		0	0	0
Earnings (Loss)																		(49)	(87)	0
Our share of earnings (loss)																		(44)	(78)	0
FMF Littleton [Member]
Schedule of Equity Method Investments [Line Items]
Revenues																		120	0	0
Earnings (Loss)																		(367)	(239)	0
Our share of earnings (loss)																		(92)	(60)	0
FMF Peakview [Member]
Schedule of Equity Method Investments [Line Items]
Revenues																		2,057	4	1
Earnings (Loss)																		(1,116)	(410)	(252)
Our share of earnings (loss)																		(223)	(83)	(50)
FOR/SR Forsyth LLC [Member]
Schedule of Equity Method Investments [Line Items]
Revenues																		0	0	0
Earnings (Loss)																		0	0	0
Our share of earnings (loss)																		0	0	0
HM Stonewall Estates [Member]
Schedule of Equity Method Investments [Line Items]
Revenues	[4]																	3,990	1,728	2,922
Earnings (Loss)	[4]																	1,881	613	1,082
Our share of earnings (loss)	[4]																	952	248	452
LM Land Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Revenues	[4]																	10,956	21,980	25,426
Earnings (Loss)	[4]																	8,251	15,520	11,012
Our share of earnings (loss)	[4]																	3,342	4,827	3,418
MRECV DT Holdings LLC [Member]
Schedule of Equity Method Investments [Line Items]
Revenues																		0	0	0
Earnings (Loss)																		167	0	0
Our share of earnings (loss)																		0	0	0
MRECV Edelweiss LLC [Member]
Schedule of Equity Method Investments [Line Items]
Revenues																		0	0	0
Earnings (Loss)																		151	0	0
Our share of earnings (loss)																		137	0	0
MRECV Juniper Ridge LLC [Member]
Schedule of Equity Method Investments [Line Items]
Revenues																		0	0	0
Earnings (Loss)																		106	0	0
Our share of earnings (loss)																		0	0	0
Miramonte Boulder Pass, LLC [Member] [Domain]
Schedule of Equity Method Investments [Line Items]
Revenues																		0	0	0
Earnings (Loss)																		(250)	0	0
Our share of earnings (loss)																		(125)	0	0
PSW Communities [Member]
Schedule of Equity Method Investments [Line Items]
Revenues																		29,986	0	0
Earnings (Loss)																		2,688	(86)	0
Our share of earnings (loss)																		1,169	(76)	0
Temco [Member]
Schedule of Equity Method Investments [Line Items]
Revenues																		9,485	2,155	630
Earnings (Loss)																		2,358	494	96
Our share of earnings (loss)																		1,179	247	48
Other Ventures [Member]
Schedule of Equity Method Investments [Line Items]
Revenues																		36,237	1,792	5,994
Earnings (Loss)																		33,303	4,835	176
Our share of earnings (loss)																		$ 1,278	$ 260	$ 33
[1]	Non-cash impairment charges for unproved leasehold interests and proved oil and gas properties included in our quarterly financial results are as follows: First Quarter Second Quarter Third Quarter FourthQuarter (In thousands)2015$7 $45,938 $81,240 $37,6462014755 584 735 30,591
[2]	Includes unamortized deferred gains on real estate contributed by us to ventures. We recognize deferred gains as income as real estate is sold to third parties. Deferred gains of $1,496,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2015.
[3]	In 2014, we acquired full ownership in the Eleven venture for $21,500,000. The acquisition-date fair value was $55,275,000, including debt of $23,936,000. Our investment in the Eleven venture prior to acquiring our partner’s interest was $2,229,000.
[4]	Includes unrecognized basis difference of $34,000 which is reflected as a reduction of our investment in unconsolidated ventures at year-end 2015. This difference between estimated fair value of the equity investment and our capital account within the respective ventures at closing will be accreted as income or expense over the life of the investment and included in our share of earnings (loss) from the respective ventures.

Investment In Unconsolidated 58

Investment In Unconsolidated Ventures - Summarized Income Statement Information (Footnotes) (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Schedule of Equity Method Investments [Line Items]
Reduction in investment	$ 34
242, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Reduction in investment	$ 1,496
Other Ventures [Member] | Minimum [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	40.00%
Other Ventures [Member] | Maximum [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	75.00%
Equity Method Investments [Member]
Schedule of Equity Method Investments [Line Items]
Long-term Debt, Current Maturities	$ 39,590	$ 65,795
Equity Method Investments [Member] | Non-recourse Debt [Member]
Schedule of Equity Method Investments [Line Items]
Long-term Debt, Current Maturities	$ 6,798	$ 42,566

Receivables - Receivables (Deta

Receivables - Receivables (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	$ 23,893	$ 24,847
Oil and gas joint interest billing receivables	867	5,738
Allowance for bad debts	(237)	(258)
Receivables, net	23,656	24,589
Loan secured by real estate [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	0	3,574
Other loans secured by real estate [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	$ 2,130	$ 1,737
Average Interest Rates	11.31%	4.41%
Oil and gas revenue accrual receivable [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	$ 3,745	$ 7,293
Other receivables and accrued interest [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	$ 2,448	$ 6,505

Receivables - Additional Inform

Receivables - Additional Information (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)a	Dec. 31, 2014USD ($)
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts and Notes Receivables	$ 23,893	$ 24,847
Due period of notes receivable as secured by deed of trust	3 years
Funds held by qualified intermediary [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts and Notes Receivables	$ 14,703	0
Area of Land | a	6,915
Loan secured by real estate [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts and Notes Receivables	$ 0	3,574
Principal amount of loan received	4,394
Interest amount of loan received	49
Other loans secured by real estate [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts and Notes Receivables	$ 2,130	$ 1,737

Receivables - Estimated Accreta

Receivables - Estimated Accretable Yield (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Receivables [Abstract]
Beginning of period	$ 839	$ 8,908
Change in accretable yield due to change in timing of estimated cash flows	30	(166)
Interest income recognized	(869)	(7,903)
End of period	$ 0	$ 839

Debt - Schedule of Debt (Detail

Debt - Schedule of Debt (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Line of Credit Facility [Line Items]
Debt	$ 389,782	$ 432,744
6% Tangible Equity Units [Member]
Line of Credit Facility [Line Items]
Debt	8,768	17,154
Term Loan Facility [Member] | Senior Secured Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt		200,000
Senior Notes [Member]
Line of Credit Facility [Line Items]
Debt	230,560	250,000
Convertible Debt [Member]
Line of Credit Facility [Line Items]
Debt	106,762	103,194
Secured Promissory Notes [Member]
Line of Credit Facility [Line Items]
Debt	15,400	15,400
Other Indebtedness [Member]
Line of Credit Facility [Line Items]
Debt	$ 28,292	$ 46,996

Debt - Debt (Detail)

Debt - Debt (Detail)	Feb. 26, 2013	Dec. 31, 2015	Dec. 31, 2014
Convertible Debt [Member]
Line of Credit Facility [Line Items]
Average interest rate		3.75%	3.75%
Debt Instrument, Maturity Date	Mar. 1, 2020
6% Tangible Equity Units [Member]
Line of Credit Facility [Line Items]
Average interest rate		6.00%	6.00%
Secured Promissory Notes [Member]
Line of Credit Facility [Line Items]
Average interest rate		3.42%	3.17%
Other Indebtedness [Member]
Line of Credit Facility [Line Items]
Variable and fixed interest rates ranging, minimum		2.19%
Variable and fixed interest rates ranging, maximum		5.50%
Senior Notes [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Maturity Date	Jun. 1, 2022
Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Expiration Date		May 15, 2017
Senior Secured Credit Facility [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Average interest rate		8.50%	8.50%
Second Amended Senior Secured Credit Facility [Member] [Member] | Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Expiration Date		Sep. 14, 2017
Second Amended Senior Secured Credit Facility [Member] [Member] | Revolving Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Maturity Date		Sep. 14, 2015
6% Tangible Equity Units [Member] | Senior Notes [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Expiration Date		Dec. 15, 2016

Debt - Additional Information (

Debt - Additional Information (Detail)	Nov. 27, 2013USD ($)sharesUnit$ / shares$ / Unit	Feb. 26, 2013USD ($)	Dec. 31, 2015USD ($)PropertyRoom$ / shares		Dec. 31, 2014USD ($)Property$ / shares	Dec. 31, 2013USD ($)	Apr. 01, 2016	Mar. 31, 2016	Sep. 30, 2015
Line of Credit Facility [Line Items]
NetIncomePercentageRequiredforNetWorthCompliance			75.00%
MinimumNetWorthPercentageRequiredForCompliance			85.00%
Common stock, par value | $ / shares			$ 1		$ 1
Debt			$ 389,782,000		$ 432,744,000
Repayments of Long-term Debt			58,220,000		225,481,000	$ 106,076,000
Deferred Finance Costs, Net			11,034,000		15,168,000
Amortization of deferred financing fees			4,002,000		$ 3,845,000	$ 3,050,000
Debt Maturities 2016			27,973,000
Debt Maturities 2017			551,000
Debt Maturities 2018			23,936,000
Debt Maturities 2019			0
Debt Maturities 2020			106,762,000
Debt Maturities thereafter			$ 230,560,000
Austin [Member]
Line of Credit Facility [Line Items]
Guest room hotel | Room			413
Multi Family Property [Member] | Austin, Texas [Member]
Line of Credit Facility [Line Items]
Number Of Units Of Multifamily Project | Property			257		257
Carrying value					$ 53,917,000
Multi Family Development Properties [Member] | Texas [Member]
Line of Credit Facility [Line Items]
Carrying value			$ 51,035,000
6% Tangible Equity Units [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Face Amount	$ 150,000,000
Units issued | Unit	6,000,000
Exercise price of unit | $ / Unit	25
Common stock, par value | $ / shares	$ 1
Interest rate percentage	6.00%
Debt			8,768,000		17,154,000
Revolving Line of Credit [Member] | Sublimit For Letters Of Credit [Member]
Line of Credit Facility [Line Items]
Sublimit for letters of credit under line of credit facility			100,000,000
Term Loan Facility [Member] | Senior Secured Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt					200,000,000
Letter of Credit [Member]
Line of Credit Facility [Line Items]
Sublimit for letters of credit outstanding			15,899,000
Convertible Debt [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Face Amount		$ 125,000,000
Debt Instrument, Maturity Date		Mar. 1, 2020
Interest rate percentage		3.75%
Initial conversion rate		40.8351
Principal amount of initial conversion rate		$ 1,000
Unamortized debt discount			18,238,000
Debt			$ 106,762,000		103,194,000
Senior Notes [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Maturity Date		Jun. 1, 2022
Interest rate percentage			8.50%
Debt			$ 230,560,000		250,000,000
Notes Reduction			$ 19,440,000
Debt Instrument, Redemption Price, Percentage			97.00%
Gains (Losses) on Extinguishment of Debt, before Write off of Deferred Debt Issuance Cost			$ 589,000
Write off of Deferred Debt Issuance Cost			$ 506,000
Senior Notes [Member] | 6% Tangible Equity Units [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Expiration Date			Dec. 15, 2016
Face amount per unit, debt | $ / Unit	4.2522
Interest rate percentage	4.50%
Secured Promissory Notes [Member]
Line of Credit Facility [Line Items]
Debt			$ 15,400,000		15,400,000
Secured Promissory Notes [Member] | Austin [Member]
Line of Credit Facility [Line Items]
Carrying value of multifamily project to secure non recourse loan			33,621,000
Other Indebtedness [Member]
Line of Credit Facility [Line Items]
Debt			28,292,000		46,996,000
Other Indebtedness [Member] | Multi Family Property [Member] | Austin, Texas [Member]
Line of Credit Facility [Line Items]
Debt			23,936,000
Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Minimum liquidity required			$ 125,000,000
Minimum effective leverage ratio exceeded			40.00%
Debt Instrument, Stockholders Distribution Covenant, Interest Coverage Ratio			3
Maximum borrowing capacity under term Loan facility			$ 300,000,000
Line of Credit Facility, Expiration Date			May 15, 2017
Net unused borrowing capacity			$ 284,101,000
Percentage Of Spread On Federal Funds Effective Rate			0.50%
Minimum Net Worth Required for Compliance			$ 379,044,000
Debt Instrument, Covenant, Interest Coverage Ratio			2.25						2.50
Payments of Capital Distribution			$ 50,000,000
Debt Instrument, Distribution Funding, Percentage From Sales of Properties and Non-core Assets			65.00%
Minimum [Member] | 6% Tangible Equity Units [Member]
Line of Credit Facility [Line Items]
Units issued | shares	6,547,800
Maximum [Member] | 6% Tangible Equity Units [Member]
Line of Credit Facility [Line Items]
Units issued | shares	7,857,000
Over-Allotment Option [Member] | 6% Tangible Equity Units [Member]
Line of Credit Facility [Line Items]
Units issued | Unit	600,000
London Interbank Offered Rate (LIBOR) [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate			4.00%
Base Rate [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Percentage Of Variable Spread On Base Rate			3.00%
Thirty Day LIBOR Rate [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Basis Spread on Variable Rate			1.00%
Midtown [Member]
Line of Credit Facility [Line Items]
Number Of Units Of Multifamily Project | Property			354
Proceeds from sale of multifamily property			$ 18,473,000
Carrying value			0	[1]	$ 33,293,000
Repayments of Long-term Debt			$ 24,166,000
Scenario, Forecast [Member] | Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Covenant, Interest Coverage Ratio							2.50	2.25
[1]	Sold in 2015.

Fair Value - Additional Informa

Fair Value - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of Oil and Gas Properties	$ 107,140,000
Asset impairments	108,184,000	$ 15,934,000	$ 1,790,000
Real Estate [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset impairments	$ 1,044,000	$ 399,000

Fair Value - Carrying Value of

Fair Value - Carrying Value of Assets (Detail) - Non-recurring [Member] - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
ProvedOilGasProperty [Member]
Non-Financial Assets and Liabilities:
Real estate	$ 39,000	$ 3,655
ProvedOilGasProperty [Member] | Level 1 [Member]
Non-Financial Assets and Liabilities:
Real estate	0	0
ProvedOilGasProperty [Member] | Level 2 [Member]
Non-Financial Assets and Liabilities:
Real estate	0	0
ProvedOilGasProperty [Member] | Level 3 [Member]
Non-Financial Assets and Liabilities:
Real estate	39,000	3,655
Oil and Gas Properties [Member]
Non-Financial Assets and Liabilities:
Real estate	18,219	0
Oil and Gas Properties [Member] | Level 1 [Member]
Non-Financial Assets and Liabilities:
Real estate	0	0
Oil and Gas Properties [Member] | Level 2 [Member]
Non-Financial Assets and Liabilities:
Real estate	0	0
Oil and Gas Properties [Member] | Level 3 [Member]
Non-Financial Assets and Liabilities:
Real estate	18,219	0
Real Estate [Member]
Non-Financial Assets and Liabilities:
Real estate	641	970
Real Estate [Member] | Level 1 [Member]
Non-Financial Assets and Liabilities:
Real estate	0	0
Real Estate [Member] | Level 2 [Member]
Non-Financial Assets and Liabilities:
Real estate	0	0
Real Estate [Member] | Level 3 [Member]
Non-Financial Assets and Liabilities:
Real estate	$ 641	$ 970

Fair Value - Information About

Fair Value - Information About our Fixed Rate Financial instruments not Measured at Fair Value (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	$ 389,782	$ 432,744
Senior Notes [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	$ 230,560	250,000
Interest rate percentage	8.50%
Reported Value Measurement [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Loan Secured by Real Estate Fair Value	$ 0	3,574
Fixed rate debt, fair value	(346,090)	(370,348)
Estimate of Fair Value Measurement [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Loan Secured by Real Estate Fair Value	0	4,859
Fixed rate debt, fair value	$ (321,653)	$ (359,131)

Capital Stock - (Detail)

Capital Stock - (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Nov. 27, 2013	Feb. 26, 2013
Class of Stock [Line Items]
Number of shares repurchased		1,491,187
Value of share repurchased		$ 24,595,000
Common Stock Repurchased Since Announcement Of Strategic Initiative	3,493,332
Value Of Common Stock Repurchased Since Announcement Of Strategic Initiative	$ 54,159,000
Maximum percentage of shares repurchased under strategic initiative	20.00%
Maximum number of shares repurchased under strategic initiative	7,000,000
Stock Options [Member]
Class of Stock [Line Items]
Options to purchase shares of common stock	1,687,000
Weighted average exercise price	$ 20.83
Weighted average remaining contractual term	4 years
Aggregate intrinsic value	$ 156,000	$ 643,000
Former Affiliated Entity [Member] | Stock Options [Member]
Class of Stock [Line Items]
Options to purchase shares of common stock	500,798
Weighted average exercise price	$ 28.62
Weighted average remaining contractual term	1 year
Aggregate intrinsic value	$ 0
6% Tangible Equity Units [Member]
Class of Stock [Line Items]
Interest rate percentage			6.00%
Convertible Debt [Member]
Class of Stock [Line Items]
Interest rate percentage				3.75%
Preferred Stock [Member]
Class of Stock [Line Items]
Expiry date of rights	Dec. 11, 2017

Net Income (Loss) per Share -

Net Income (Loss) per Share - Earnings Attributable to Common Shareholders and Weighted Average Common Shares Outstanding (Detail) - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Numerator:
Consolidated net income (loss)	$ (212,371)	$ 17,088	$ 35,061
Less: Net (income) attributable to noncontrolling interest	(676)	(505)	(5,740)
Income (loss) available for diluted earnings per share	(213,047)	16,583	29,321
Less: Undistributed net income allocated to participating securities	0	(3,018)	(585)
Income (loss) available to common shareholders for basic earnings per share	$ (213,047)	$ 13,565	$ 28,736
Weighted average common shares outstanding - basic	34,266	35,317	35,365
Weighted average common shares upon conversion of participating securities	0	7,857	835
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	0	422	613
Weighted average common shares outstanding - diluted	34,266	43,596	36,813
Anti-dilutive awards excluded from diluted weighted average shares outstanding	10,864	2,238	1,803

Net Income (Loss) per Share - A

Net Income (Loss) per Share - Additional Information (Details)	Nov. 27, 2013sharesUnit	Dec. 31, 2015$ / shares
6% Tangible Equity Units [Member]
Debt Instrument [Line Items]
Stated interest rate on tangible equity units	6.00%
Units issued | Unit	6,000,000
Convertible Debt [Member]
Debt Instrument [Line Items]
Exercise price of unit | $ / shares		$ 24.49
Minimum [Member] | 6% Tangible Equity Units [Member]
Debt Instrument [Line Items]
Units issued	6,547,800
Maximum [Member] | 6% Tangible Equity Units [Member]
Debt Instrument [Line Items]
Units issued	7,857,000

Income Taxes - Income Tax Expen

Income Taxes - Income Tax Expense (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Current tax provision:
U.S. Federal	$ 8,579	$ (5,444)	$ (6,004)
State and other	47	(1,569)	(2,066)
Total	8,626	(7,013)	(8,070)
Deferred tax provision:
U.S. Federal	(38,366)	(2,772)	1,148
State and other	(2,895)	1,128	(286)
Total	(41,261)	(1,644)	862
Income tax expense	$ (32,635)	$ (8,657)	$ (7,208)

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Federal Statutory Rate to Effective Income Tax Rate on Continuing Operations (Detail)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Federal statutory rate (benefit)	(35.00%)	35.00%	35.00%
State, net of federal benefit	(1.00%)	1.00%	4.00%
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount	54.00%	0.00%	0.00%
Recognition of previously unrecognized tax benefits	0.00%	0.00%	(15.00%)
Noncontrolling interests	0.00%	0.00%	(5.00%)
Effective Income Tax Rate Reconciliation, Disposition of Asset, Percent	0.00%	1.00%	0.00%
Charitable contributions	0.00%	(1.00%)	0.00%
Oil and gas percentage depletion	0.00%	(2.00%)	(2.00%)
Effective tax rate	18.00%	34.00%	17.00%

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating Loss Carryforwards [Line Items]
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount	$ 0.54
Recognition of previously unrecognized tax benefits	(0.00%)	(0.00%)	15.00%
Oil and gas percentage depletion carryforwards	$ 9,800,000
Tax benefits not recognized for book purposes			$ 6,326,000
Recognized interest accrued related to unrecognized tax benefits	0	$ 0	$ 75,000
Accrued interest	0
Credo [Member]
Operating Loss Carryforwards [Line Items]
Oil and gas percentage depletion carryforwards	9,200,000
Domestic Tax Authority [Member]
Operating Loss Carryforwards [Line Items]
Operating loss carry forwards	$ 37,500,000
Expiration date of operating loss carry forwards	Dec. 31, 2035
Domestic Tax Authority [Member] | Credo [Member]
Operating Loss Carryforwards [Line Items]
Operating loss carry forwards	$ 7,500,000
State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating loss carry forwards	43,900,000
State and Local Jurisdiction [Member] | Credo [Member]
Operating Loss Carryforwards [Line Items]
Operating loss carry forwards	$ 2,400,000
Minimum [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Expiration date of operating loss carry forwards	Dec. 31, 2016
Maximum [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Expiration date of operating loss carry forwards	Dec. 31, 2035

Income Taxes - Significant Comp

Income Taxes - Significant Components of Deferred Taxes (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Deferred Tax Assets:
Real estate	$ 69,594	$ 79,244
Employee benefits	15,752	17,352
Net operating loss carryforwards	13,827	3,012
Deferred Tax Assets, Oil And Gas Properties	5,510	0
Deferred Tax Assets, Tax Credit Carryforwards, Alternative Minimum Tax	3,620	0
Income producing properties	0	364
Oil and gas percentage depletion carryforwards	3,616	3,471
Accruals not deductible until paid	911	1,111
Deferred Tax Assets, Other	139	0
Gross deferred tax assets	112,969	104,554
Valuation allowance	(97,068)	(384)
Deferred tax asset net of valuation allowance	15,901	104,170
Deferred Tax Liabilities:
Oil and gas properties	0	(49,905)
Undeveloped land	(7,588)	(4,937)
Convertible debt	(6,516)	(7,816)
Income producing properties	(2,257)	0
Timber	(577)	(888)
Gross deferred tax liabilities	16,938	63,546
Deferred Tax Liabilities, Net	(1,037)	0
Deferred Tax Assets, Net	$ 0	$ 40,624

Income Taxes - Reconciliation75

Income Taxes - Reconciliation of Beginning and Ending Amount of Tax Benefits Not Recognized for Book Purposes (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Balance at beginning of year	$ 0	$ 0	$ 5,831
Reductions for tax positions of prior years	0	0	0
Reductions due to lapse of statute of limitations	0	0	(5,831)
Balance at end of year	$ 0	$ 0	$ 0

Litigation and Environmental 76

Litigation and Environmental Contingencies - Additional Information (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)a	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Commitments and Contingencies Disclosure [Abstract]
Area for which certificate of completion is required | a	288
Portion of site for which certificate not received | a	80
Accrual for Environmental Loss Contingencies, Increase (Decrease) for Revision in Estimates	$ 689
Cost to complete remediation activities	682
Asset Retirement Obligation	$ 1,758	$ 1,807	$ 1,483

Commitments and Other Conting77

Commitments and Other Contingencies (Detail) ft² in Thousands, a in Thousands	3 Months Ended	12 Months Ended
	Dec. 31, 2015USD ($)ft²	Dec. 31, 2015USD ($)aft²	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Dec. 31, 2008ft²
Operating Leased Assets [Line Items]
Restructuring Reserve	$ (1,049,000)	$ (1,049,000)	$ (2,367,000)
operating lease future payments, 2015	2,696,000	2,696,000
operating lease future payments, 2016	2,738,000	2,738,000
operating lease future payments, 2016	1,706,000	1,706,000
operating lease future payments, 2018	170,000	170,000
operating lease future payments, 2019	174,000	174,000
operating lease future payments, thereafter	59,000	59,000
Restructuring Charges		(3,797,000)
Payments for Restructuring		5,115,000
Office Facilities And Other Equipment [Member]
Operating Leased Assets [Line Items]
Lease expense		$ 3,872,000	2,617,000	$ 2,374,000
Ground Water Lease [Member]
Operating Leased Assets [Line Items]
Remaining years of timber lease		2 years
Timber land area taken on lease | a		20
Remaining contractual obligation	1,009,000	$ 1,009,000
Corporate Headquarters [Member]
Operating Leased Assets [Line Items]
Net Rentable Area | ft²					32
Remaining contractual obligation	4,212,000	4,212,000
Other Office Locations [Member]
Operating Leased Assets [Line Items]
Remaining contractual obligation	$ 2,269,000	$ 2,269,000
Other Office Locations [Member] | Texas [Member]
Operating Leased Assets [Line Items]
Net Rentable Area | ft²	21	21
Facility Closing [Member]
Operating Leased Assets [Line Items]
Restructuring Reserve	$ 0	$ 0	0
Restructuring Charges		(1,750,000)
Payments for Restructuring		1,750,000
Special Termination Benefits [Member] | Oil and Gas [Member]
Operating Leased Assets [Line Items]
Restructuring Reserve	(1,049,000)	(1,049,000)	$ (2,367,000)
Restructuring Charges		(2,047,000)
Payments for Restructuring		3,365,000
Other Restructuring [Member] | Leasehold Improvements [Member]
Operating Leased Assets [Line Items]
Restructuring Charges		(391,000)
Deferred Lease Revenue [Member]
Operating Leased Assets [Line Items]
Restructuring Charges		364,000
General and Administrative Expense [Member] | One-time Termination Benefits [Member]
Operating Leased Assets [Line Items]
Restructuring Charges		$ (3,314,000)
General and Administrative Expense [Member] | Special Termination Benefits [Member]
Operating Leased Assets [Line Items]
Payments for Restructuring	$ 2,732,000

Segment Information - Additiona

Segment Information - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2015SegmentCustomer	Dec. 31, 2014Customer
Segment Reporting [Abstract]
Number of business segments | Segment	3
Concentration Risk, Percentage	10.00%
Number of customer who contributed more than 10 percent of revenue | Customer	0	0

Segment Information - Segment R

Segment Information - Segment Revenues and Earnings (Detail) - USD ($) $ in Thousands		3 Months Ended																12 Months Ended
		Dec. 31, 2015		Sep. 30, 2015	[1]	Jun. 30, 2015	[1]	Mar. 31, 2015	[1]	Dec. 31, 2014		Sep. 30, 2014	[1]	Jun. 30, 2014	[1]	Mar. 31, 2014	[1]	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Revenues		$ 114,018	[1]	$ 43,168		$ 57,430		$ 47,805		$ 80,316	[1]	$ 58,840		$ 83,013		$ 84,605		$ 262,421	$ 306,774	$ 331,045
Depreciation, depletion and amortization																		45,085	41,715	29,980
Equity in earnings of unconsolidated ventures		4,470	[1]	$ 2,909		$ 5,584		$ 3,045		4,720	[1]	$ 2,016		$ 958		$ 991		16,008	8,685	8,737
Income (loss) before taxes																		(180,412)	25,240	36,529
Total assets		980,513								1,258,199								980,513	1,258,199	1,172,152
Investment in unconsolidated ventures		82,453								65,005								82,453	65,005	41,147
Capital expenditures	[2]																	64,407	138,798	107,897
Operating Segments [Member] | Real Estate [Member]
Segment Reporting Information [Line Items]
Revenues																		202,830	213,112	248,011
Depreciation, depletion and amortization																		7,605	3,741	3,117
Equity in earnings of unconsolidated ventures																		15,582	8,068	8,089
Income (loss) before taxes																		67,678	96,906	68,454
Total assets		691,406								654,774								691,406	654,774	582,802
Investment in unconsolidated ventures		82,453								65,005								82,453	65,005	41,147
Capital expenditures	[2]																	13,644	28,980	7,265
Operating Segments [Member] | Oil and Gas [Member]
Segment Reporting Information [Line Items]
Revenues																		52,939	84,300	72,313
Depreciation, depletion and amortization																		28,774	29,442	19,552
Equity in earnings of unconsolidated ventures																		275	586	592
Income (loss) before taxes																		(184,396)	(22,686)	18,859
Total assets		144,436								342,703								144,436	342,703	312,553
Investment in unconsolidated ventures		0								0								0	0	0
Capital expenditures	[2]																	49,776	103,385	97,696
Operating Segments [Member] | Other Natural Resources [Member]
Segment Reporting Information [Line Items]
Revenues																		6,652	9,362	10,721
Depreciation, depletion and amortization																		540	497	651
Equity in earnings of unconsolidated ventures																		151	31	56
Income (loss) before taxes																		(608)	5,499	6,507
Total assets		19,106								22,531								19,106	22,531	23,478
Investment in unconsolidated ventures		0								0								0	0	0
Capital expenditures	[2]																	745	5,817	2,720
Items Not Allocated To Segments [Member]
Segment Reporting Information [Line Items]
Revenues																		0	0	0
Depreciation, depletion and amortization																		8,166	8,035	6,660
Equity in earnings of unconsolidated ventures																		0	0	0
Income (loss) before taxes	[3]																	(63,086)	(54,479)	(57,291)
Total assets		125,565								238,191								125,565	238,191	253,319
Investment in unconsolidated ventures		$ 0								$ 0								0	0	0
Capital expenditures	[2]																	$ 242	$ 616	$ 216
[1]	Non-cash impairment charges for unproved leasehold interests and proved oil and gas properties included in our quarterly financial results are as follows: First Quarter Second Quarter Third Quarter FourthQuarter (In thousands)2015$7 $45,938 $81,240 $37,6462014755 584 735 30,591
[2]	Consists of expenditures for oil and gas properties and equipment, commercial and income producing properties, property, plant and equipment and reforestation of timber.
[3]	Items not allocated to segments consist of: For the Year 2015 2014 2013 (In thousands)General and administrative expense$(24,802) $(21,229) $(20,597)Share-based and long-term incentive compensation expense(4,474) (3,417) (16,809)Interest expense(34,066) (30,286) (20,004)Other corporate non-operating income256 453 119 $(63,086) $(54,479) $(57,291)

Segment Information - Items Not

Segment Information - Items Not Allocated to Segments (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Income (loss) before taxes		$ (180,412)	$ 25,240	$ 36,529
Items Not Allocated To Segments [Member]
Segment Reporting Information [Line Items]
Income (loss) before taxes	[1]	(63,086)	(54,479)	(57,291)
Items Not Allocated To Segments [Member] | General and Administrative Expense [Member]
Segment Reporting Information [Line Items]
Income (loss) before taxes		(24,802)	(21,229)	(20,597)
Items Not Allocated To Segments [Member] | Share-based compensation expense [Member]
Segment Reporting Information [Line Items]
Income (loss) before taxes		(4,474)	(3,417)	(16,809)
Items Not Allocated To Segments [Member] | Interest expense [Member]
Segment Reporting Information [Line Items]
Income (loss) before taxes		(34,066)	(30,286)	(20,004)
Items Not Allocated To Segments [Member] | Other corporate non-operating income [Member]
Segment Reporting Information [Line Items]
Income (loss) before taxes		$ 256	$ 453	$ 119
[1]	Items not allocated to segments consist of: For the Year 2015 2014 2013 (In thousands)General and administrative expense$(24,802) $(21,229) $(20,597)Share-based and long-term incentive compensation expense(4,474) (3,417) (16,809)Interest expense(34,066) (30,286) (20,004)Other corporate non-operating income256 453 119 $(63,086) $(54,479) $(57,291)

Variable Interest Entities - Ad

Variable Interest Entities - Additional Information (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)Entity	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Variable Interest Entity [Line Items]
Payments to Acquire Additional Interest in Subsidiaries	$ 0	$ 7,971	$ 0
Deferred Tax Assets, Net	$ 0	40,624
Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Count of VIEs | Entity	2
Variable Interest Entity, Non consolidated, Carrying amount, Assets	$ 62,187
Variable Interest Entity, Nonconsolidated, Carrying Amount, Liabilities	55,989
Variable Interest Entity, Financial or Other Support, Amount	148
Maximum Exposure to loss related to VIEs	3,780
Investment in VIEs	5,322
Noncontrolling Interest [Member]
Variable Interest Entity [Line Items]
Deferred Tax Assets, Net		$ 1,729
Borrowings [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Variable Interest Entity, Nonconsolidated, Carrying Amount, Liabilities	$ 2,269

Share Based Compensation - Comp

Share Based Compensation - Components of Share-Based Compensation Expense (Income) (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	$ 4,246	$ 3,417	$ 16,809
Deferred Compensation Arrangement with Individual, Compensation Expense	228	0	0
Share-Based and Long-Term Incentive Compensation	4,474	3,417	16,809
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	2,355	1,984	4,216
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	(8)	(25)	538
Equity-settled awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	5,026	5,168	4,281
Cash Settled Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	$ (3,127)	$ (3,710)	$ 7,774

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, 2015	Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-Based and Long-Term Incentive Compensation	$ 4,474	$ 3,417	$ 16,809
General and Administrative Expense [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-Based and Long-Term Incentive Compensation	2,451	1,001	7,779
Other Operating Expenses [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-Based and Long-Term Incentive Compensation	$ 2,023	$ 2,416	$ 9,030

Share Based Compensation - Addi

Share Based Compensation - Additional Information (Detail) - USD ($)	3 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation		$ 4,246,000	$ 3,417,000	$ 16,809,000
Share-based Compensation Arrangement by Share-based Payment Award Accelerated Compensation Cost		517,000	$ 760,000	590,000
Unrecognized share-based compensation expense related to non-vested equity-settled awards, restricted stock and stock options		$ 5,109,000
Weighted average period over which amount will be recognized		2 years
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures		288,089	215,561
Vesting of restricted stock awards and exercises of stock options, shares withheld		51,521	55,238
Payroll taxes on restricted stock and stock options		$ 762,000	$ 1,043,000	1,137,000
Stock price of non-vested cash-settled awards		$ 10.94
Financial Instruments Subject to Mandatory Redemption, Settlement Terms, Share Value, Amount, Noncurrent	$ 17.50
Deferred Compensation Arrangement with Individual, Cash Award Granted, Amount		$ 587,000
Deferred Compensation Cash-based Arrangements, Liability, Current and Noncurrent		225,000
Board of Director Fees [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation		1,203,000	906,000	876,000
Cash Settled Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation		(3,127,000)	(3,710,000)	7,774,000
Fair value of vested cash-settled awards		3,757,000	$ 9,560,000
Aggregate current value of non-vested cash-settled awards		$ 1,286,000
Cash Settled Awards [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest		3 years
Cash Settled Awards [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest		4 years
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest		3 years
Restricted Stock Units (RSUs) [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest		3 years
Restricted Stock Units (RSUs) [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest		4 years
Stock Appreciation Rights (SARs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested, weighted average grant date fair value		$ 12.97	$ 12.54
Aggregate current value of non-vested cash-settled restricted stock units		487,000	458,000
Fair value of awards settled in cash		$ 206,000	$ 1,181,000	3,458,000
Period over or after performance stock unit vest		4 years
Share-based Compensation Arrangement by Share-based Payment Award, Expiration Period		10 years
Granted, Equivalent Units		90,000
Market-leveraged stock units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest		3 years
Granted, Equivalent Units		234,000
Number of shares to be issued if stock price increases by fifty percent		351,000
Numbers of shares to be issued if stock price decreases by fifty percent		117,000
Equity-settled awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation		$ 5,026,000	$ 5,168,000	4,281,000
Unrecognized share-based compensation expense related to non-vested equity-settled awards, restricted stock and stock options		$ 3,258,000
Weighted average period over which amount will be recognized		2 years
Nonvested, weighted average grant date fair value		$ 18.25	$ 19.24
Aggregate current value of non-vested cash-settled restricted stock units		631,000	710,000
Fair value of vested cash-settled awards		$ 4,451,000,000	$ 3,119,000,000	8,000,000
Granted, Equivalent Units		395,000
Minimum increases in stock price		50.00%
Percentage of decrease in stock price		50.00%
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation		$ (8,000)	$ (25,000)	538,000
Unrecognized share-based compensation expense related to non-vested equity-settled awards, restricted stock and stock options		$ 14,000
Weighted average period over which amount will be recognized		1 year
Minimum Percent Annualized Return on Assets Vesting for Stock Unit Awards		1.00%
Nonvested, weighted average grant date fair value		$ 20.55	$ 17.56
Aggregate current value of non-vested cash-settled restricted stock units		4,000	17,000
Fair value of vested cash-settled awards		$ 88,000,000	$ 341,000,000	3,002,000,000
Period over or after performance stock unit vest		3 years
Granted, Equivalent Units		0
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation		$ 2,355,000	1,984,000	4,216,000
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested in Period, Fair Value		0	21,000	1,355,000
Unrecognized share-based compensation expense related to non-vested equity-settled awards, restricted stock and stock options		$ 1,837,000
Weighted average period over which amount will be recognized		2 years
Period over or after performance stock unit vest	3 years	4 years
Share-based Compensation Arrangement by Share-based Payment Award, Expiration Period	10 years	10 years
Intrinsic value of options exercised		$ 0	$ 568,000	562,000
Options Outstanding		2,171,000	1,861,000
Weighted average exercise price		$ 20.83
Weighted Average Remaining Contractual Term		5 years	6 years
Aggregate intrinsic value		$ 156,000	$ 643,000
Cash Settled Restricted Stock Unit [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Minimum Percent Annualized Return on Assets Vesting for Stock Unit Awards		1.00%
Nonvested, weighted average grant date fair value		$ 16	$ 18.49
Aggregate current value of non-vested cash-settled restricted stock units		117,000	185,000
Fair value of awards settled in cash		$ 2,469,000	$ 2,286,000	3,780,000
Granted, Equivalent Units		60,000
Performance Stock Units Psu [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest		3 years
Special Performance [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Special Performance Stock Unit awards to be issued		0
Pre Spin Stock Option Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period over or after performance stock unit vest		4 years
Share-based Compensation Arrangement by Share-based Payment Award, Expiration Period		10 years
Options Outstanding		44,000
Weighted average exercise price		$ 28.89
Weighted Average Remaining Contractual Term		1 year
Former Affiliated Entity [Member] | Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Intrinsic value of options exercised		$ 24,000	$ 352,000	$ 1,382,000
Weighted average exercise price		$ 28.62
Aggregate intrinsic value		$ 0

Share Based Compensation - Summ

Share Based Compensation - Summarized Activity of Cash Settled Restricted Stock Unit Awards (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Stock Appreciation Rights (SARs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Balance at beginning of year			458
Granted, Equivalent Units			90
Forfeited, Equivalent Units			(22)
Balance at end of period			487	458
Non-vested at beginning of year, Weighted Average Grant Date Fair Value			$ 12.54
Forfeited, Weighted Average Grant Date Fair Value			15
Non-vested at end of period, Weighted Average Grant Date Fair Value			$ 12.97	$ 12.54
Employee Service Share-based Compensation, Cash Flow Effect, Cash Used to Settle Awards			$ 206	$ 1,181	$ 3,458
Cash Settled Restricted Stock Unit [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Balance at beginning of year			185
Granted, Equivalent Units			60
Vested, Equivalent Units			(117)
Forfeited, Equivalent Units			(11)
Balance at end of period			117	185
Non-vested at beginning of year, Weighted Average Grant Date Fair Value			$ 18.49
Granted, Weighted Average Grant Date Fair Value	$ 18.96	$ 18.70	13.26
Vested, Weighted Average Grant Date Fair Value			18.26
Forfeited, Weighted Average Grant Date Fair Value			18.83
Non-vested at end of period, Weighted Average Grant Date Fair Value			$ 16	$ 18.49
Employee Service Share-based Compensation, Cash Flow Effect, Cash Used to Settle Awards			$ 2,469	$ 2,286	$ 3,780

Share Based Compensation - Su86

Share Based Compensation - Summarized Activity of Cash-Settled Stock Appreciation Rights (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Stock Appreciation Rights (SARs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Fair value of awards settled in cash	$ 206	$ 1,181	$ 3,458
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Outstanding, Weighted Average Remaining Contractual Terms	4 years	4 years
Balance at beginning of year	458
Granted, Rights Outstanding	90
Exercised, Rights Outstanding	(39)
Forfeited, Rights Outstanding	(22)
Balance at end of period	487	458
Exercisable at end of period, Rights Outstanding	414
Non-vested at beginning of year, Weighted Average Grant Date Fair Value	$ 12.54
Granted, Weighted Average Exercise Price	14.08
Exercised, Weighted Average Exercise Price	9.29
Forfeited, Weighted Average Grant Date Fair Value	15
Non-vested at end of period, Weighted Average Grant Date Fair Value	12.97	$ 12.54
Exercisable at end of period, Weighted Average Exercise Price	$ 12.77
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Exercisable Weighted Average Remaining Contractual Term	3 years
Aggregate Intrinsic Value	$ 404	$ 1,732
Exercisable at end of period, Aggregate Intrinsic Value	404
Cash Settled Restricted Stock Unit [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Fair value of awards settled in cash	$ 2,469	$ 2,286	$ 3,780
Balance at beginning of year	185
Granted, Rights Outstanding	60
Forfeited, Rights Outstanding	(11)
Balance at end of period	117	185
Non-vested at beginning of year, Weighted Average Grant Date Fair Value	$ 18.49
Forfeited, Weighted Average Grant Date Fair Value	18.83
Non-vested at end of period, Weighted Average Grant Date Fair Value	$ 16	$ 18.49

Share Based Compensation - Equi

Share Based Compensation - Equity-Settled Awards (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Equity-settled awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value			$ 12.99	$ 19.18	$ 20.21
Balance at beginning of year			710
Granted, Equivalent Units			395
Vested, Equivalent Units			(340)
Forfeited, Equivalent Units			(134)
Balance at end of period			631	710
Non-vested at beginning of year, Weighted Average Grant Date Fair Value			$ 19.24
Granted, Weighted Average Grant Date Fair Value			12.99
Vested, Weighted Average Grant Date Fair Value			14.23
Forfeited, Weighted Average Grant Date Fair Value			18.18
Non-vested at end of period, Weighted Average Grant Date Fair Value			$ 18.25	$ 19.24
Fair value of vested cash-settled awards			$ 4,451,000	$ 3,119,000	$ 8,000
Cash Settled Restricted Stock Unit [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Fair value of awards settled in cash			$ 2,469	$ 2,286	$ 3,780
Balance at beginning of year			185
Granted, Equivalent Units			60
Vested, Equivalent Units			(117)
Forfeited, Equivalent Units			(11)
Balance at end of period			117	185
Non-vested at beginning of year, Weighted Average Grant Date Fair Value			$ 18.49
Granted, Weighted Average Grant Date Fair Value	$ 18.96	$ 18.70	13.26
Vested, Weighted Average Grant Date Fair Value			18.26
Forfeited, Weighted Average Grant Date Fair Value			18.83
Non-vested at end of period, Weighted Average Grant Date Fair Value			$ 16	$ 18.49

Share Based Compensation - Su88

Share Based Compensation - Summarized Activity of Restricted Stock Awards (Detail) - Restricted Stock [Member] - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Fair value of vested cash-settled awards	$ 88,000	$ 341,000	$ 3,002,000
Balance at beginning of year	17
Granted, Equivalent Units	0
Vested, Equivalent Units	(7)
Forfeited, Equivalent Units	(6)
Balance at end of period	4	17
Non-vested at beginning of year, Weighted Average Grant Date Fair Value	$ 17.56
Granted, Weighted Average Grant Date Fair Value	0
Vested, Weighted Average Grant Date Fair Value	14.59
Forfeited, Weighted Average Grant Date Fair Value	19
Non-vested at end of period, Weighted Average Grant Date Fair Value	$ 20.55	$ 17.56

Share Based Compensation - Su89

Share Based Compensation - Summarized Activity of Stock Option Awards (Detail) - Stock Options [Member] - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Balance at beginning of year, Options Outstanding	1,861
Granted, Options Outstanding	413
Exercised, Options Outstanding	0
Forfeited, Options Outstanding	(103)
Balance at end of period, Options Outstanding	2,171	1,861
Exercisable at end of period, Options Outstanding	1,687
Balance at beginning of year, Weighted Average Exercise Price	$ 20.74
Granted, Weighted Average Exercise Price	13.86
Exercised, Weighted Average Exercise Price	0
Forfeited, Weighted Average Exercise Price	18.01
Balance at end of period, Weighted Average Exercise Price	19.56	$ 20.74
Exercisable at end of period, Weighted Average Exercise Price	$ 20.83
Weighted Average Remaining Contractual Term	5 years	6 years
Exercisable at end of period, Weighted Average Remaining Contractual Term	4 years
Aggregate intrinsic value	$ 156	$ 643
Exercisable at end of period, Aggregate Intrinsic Value	$ 156

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, 2015	Dec. 31, 2014	Dec. 31, 2013
Market-leveraged stock units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected stock price volatility	32.90%	42.20%	42.20%
Risk-free interest rate	1.00%	0.70%	0.40%
Expected dividend yield	0.00%	0.00%	0.00%
Weighted average estimated fair value of options at grant date	$ 15.11	$ 20.38	$ 21.09
Stock Options [Member] | Market Condition Vesting [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected stock price volatility	45.60%		66.80%
Risk-free interest rate	1.80%		1.40%
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	$ 6.51		$ 11.47
Management [Member] | Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expected stock price volatility	61.40%
Risk-free interest rate	2.20%
Expected dividend yield	0.00%
Weighted average estimated fair value of options at grant date	$ 7.87

Retirement Plans - Additional I

Retirement Plans - Additional Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Compensation and Retirement Disclosure [Abstract]
Expense of defined contribution retirement plans	$ 1,255	$ 1,651	$ 1,456
Unfunded liability for supplemental plan	$ 802	$ 715

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, 2015Well	Dec. 31, 2015$ / MMBTU	Dec. 31, 2015bbl	Dec. 31, 2015$ / Boe	Dec. 31, 2015Mcf	Dec. 31, 2014Well$ / MMBTU$ / BoebblMcf	Dec. 31, 2013Well$ / MMBTU$ / BoebblMcf
Supplemental Oil And Gas Reserve Information [Line Items]
New well addition | Well		36					106	88
Crude Oil and NGL [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Average spot price | $ / Boe					50.28		94.99	96.91
Natural Gas in Mmbtu [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Average spot price | $ / MMBTU			2.59				4.35	3.67
Consolidated Entities [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates							608	1,243
Oil [Member] | Consolidated Entities [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Extensions and discoveries	[1]			224			2,191	3,085
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place	[1]			704			105
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates	[1]			855			608	182
Oil [Member] | Equity Method Investee [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates	[1]			0			0	0
New PDP Reserves [Member] | Consolidated Entities [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Extensions and discoveries							694
New PUD Reserves [Member] | Consolidated Entities [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Extensions and discoveries							913
Natural Gas [Member] | Consolidated Entities [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Extensions and discoveries | Mcf						173	774	2,046
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place | Mcf						1,223	218
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates				1,995		1,675	293	1,243
Natural Gas [Member] | Equity Method Investee [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates | Mcf						(320)	(382)	7
[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, 2015bblMcf	Dec. 31, 2015bblMcf	Dec. 31, 2014bblMcf	Dec. 31, 2013bblMcf
Oil [Member]
Reserve Quantities [Line Items]
Beginning Balance	[1]	7,672		5,824
Proved developed reserves	[1]	5,179	5,179	5,269	3,893
Proved undeveloped reserves	[1]	0	0	2,403	1,931
Ending Balance	[1]	5,179		7,672	5,824
Natural Gas [Member]
Reserve Quantities [Line Items]
Beginning Balance | Mcf			14,400	15,962
Proved developed reserves | Mcf		9,220	9,220	12,599	13,717
Proved undeveloped reserves | Mcf		0	0	1,801	2,245
Ending Balance | Mcf			9,220	14,400	15,962
Consolidated Entities [Member]
Reserve Quantities [Line Items]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates				(608)	(1,243)
Consolidated Entities [Member] | Oil [Member]
Reserve Quantities [Line Items]
Beginning Balance	[1]	7,672		5,824	3,220
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates	[1]	(855)		(608)	(182)
Extensions and discoveries	[1]	224		2,191	3,085
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place	[1]	(704)		(105)
Acquisitions	[1]	0		85	35
Production	[1]	(1,158)		(931)	(698)
Ending Balance	[1]	5,179		7,672	5,824
Consolidated Entities [Member] | Natural Gas [Member]
Reserve Quantities [Line Items]
Beginning Balance | Mcf			12,649	13,630	11,722
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates		(1,995)	(1,675)	(293)	(1,243)
Extensions and discoveries | Mcf			173	774	2,046
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place | Mcf			(1,223)	(218)
Acquisitions | Mcf			0	31	531
Production | Mcf			(1,967)	(1,861)	(1,912)
Ending Balance | Mcf			7,957	12,649	13,630
Equity Method Investee [Member] | Oil [Member]
Reserve Quantities [Line Items]
Beginning Balance	[1]	0		0	0
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates	[1]	0		0	0
Production	[1]	0		0	0
Ending Balance	[1]	0		0	0
Equity Method Investee [Member] | Natural Gas [Member]
Reserve Quantities [Line Items]
Beginning Balance | Mcf			1,751	2,332	2,572
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates | Mcf			320	382	(7)
Production | Mcf			(168)	(199)	(247)
Ending Balance | Mcf			1,263	1,751	2,332
[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) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Capitalized Costs Relating To Oil And Gas Producing Activities [Line Items]
Total costs	$ 138,855	$ 311,745
Consolidated Entities [Member]
Capitalized Costs Relating To Oil And Gas Producing Activities [Line Items]
Unproved oil and gas properties	19,441	90,446
Proved oil and gas properties	119,414	221,299
Total costs	138,855	311,745
Less accumulated depreciation, depletion and amortization	(58,242)	(48,252)
Net capitalized costs	$ 80,613	$ 263,493

Supplemental Oil and Gas Disc95

Supplemental Oil and Gas Disclosures (Unaudited) - Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves	$ 67,498	$ 165,616	$ 136,853	$ 107,956
Consolidated Entities [Member]
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Cash Inflows	216,588	665,657	544,098
Costs Incurred, Acquisition of Oil and Gas Properties with Proved Reserves	0	2,001	0
Costs Incurred, Acquisition of Unproved Oil and Gas Properties	4,832	25,666	35,806
Exploration costs	17,922	39,399	10,486
Development costs	27,609	40,277	54,538
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities	50,363	107,343	100,830
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Production Costs	93,623	271,735	231,801
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Income Tax Expense	22,218	106,002	77,361
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Net Cash Flows	100,747	287,920	234,936
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Ten Percent Annual Discount for Estimated Timing of Cash Flows	33,951	124,079	99,383
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves	$ 66,796	$ 163,841	$ 135,553	$ 106,543

Supplemental Oil and Gas Disc96

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, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Standardized measure of discounted future net cash flows	$ 67,498	$ 165,616	$ 136,853	$ 107,956
Consolidated Entities [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Cash Inflows	216,588	665,657	544,098
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Production Costs	(93,623)	(271,735)	(231,801)
Future income tax expenses	(22,218)	(106,002)	(77,361)
Future net cash flows	100,747	287,920	234,936
10% annual discount for estimated timing of cash flows	(33,951)	(124,079)	(99,383)
Standardized measure of discounted future net cash flows	66,796	163,841	135,553	106,543
Equity Method Investee [Member]
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Cash Inflows	2,283	6,186	4,765
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Production Costs	(245)	(664)	(512)
Future income tax expenses	(774)	(2,098)	(1,616)
Future net cash flows	1,264	3,424	2,637
10% annual discount for estimated timing of cash flows	(562)	(1,649)	(1,337)
Standardized measure of discounted future net cash flows	$ 702	$ 1,775	$ 1,300	$ 1,413

Supplemental Oil and Gas Disc97

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, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule Of Changes In Standardized Measure Of Discounted Future Net Cash Flows [Line Items]
Beginning Balance	$ 165,616	$ 136,853	$ 107,956
Changes resulting from:
Net change in sales prices and production costs	(137,648)	507	23,837
Net change in future development costs	92	1,308	(2,897)
Sales of oil and gas, net of production costs	(32,160)	(63,979)	(57,360)
Net change due to extensions and discoveries	11,747	58,228	54,539
Increase Due to Purchases of Minerals in Place	0	2,778	1,160
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place	(15,855)	(5,804)
Net change due to revisions of quantity estimates	(15,431)	14,960	8,679
Previously estimated development costs incurred	(15,096)	(15,497)	(4,124)
Accretion of discount	22,886	18,277	13,768
Standardized Measure of Discounted Future Net Cash Flow of Proved Oil and Gas Reserves, Other	3,808	4,313	(749)
Net change in income taxes	49,347	(17,322)	(16,204)
Aggregate change for the year	(98,118)	28,763	28,897
Ending Balance	67,498	165,616	136,853
Consolidated Entities [Member]
Schedule Of Changes In Standardized Measure Of Discounted Future Net Cash Flows [Line Items]
Beginning Balance	163,841	135,553	106,543
Changes resulting from:
Net change in sales prices and production costs	(136,536)	(1,064)	23,422
Net change in future development costs	92	1,308	(2,897)
Sales of oil and gas, net of production costs	(31,732)	(63,192)	(56,559)
Net change due to extensions and discoveries	11,747	58,228	54,539
Increase Due to Purchases of Minerals in Place	0	2,778	1,160
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place	(15,855)	(5,804)
Net change due to revisions of quantity estimates	(15,164)	15,303	8,673
Previously estimated development costs incurred	(15,096)	(15,497)	(4,124)
Accretion of discount	22,600	18,067	13,540
Standardized Measure of Discounted Future Net Cash Flow of Proved Oil and Gas Reserves, Other	4,018	4,198	(718)
Net change in income taxes	48,689	(17,031)	(16,274)
Aggregate change for the year	(97,045)	28,288	29,010
Ending Balance	66,796	163,841	135,553
Equity Method Investee [Member]
Schedule Of Changes In Standardized Measure Of Discounted Future Net Cash Flows [Line Items]
Beginning Balance	1,775	1,300	1,413
Changes resulting from:
Net change in sales prices and production costs	(1,112)	1,571	415
Net change in future development costs	0	0	0
Sales of oil and gas, net of production costs	(428)	(787)	(801)
Net change due to extensions and discoveries	0	0	0
Increase Due to Purchases of Minerals in Place	0	0	0
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place		0
Net change due to revisions of quantity estimates	(267)	(343)	6
Previously estimated development costs incurred	0	0	0
Accretion of discount	286	210	228
Standardized Measure of Discounted Future Net Cash Flow of Proved Oil and Gas Reserves, Other	(210)	115	(31)
Net change in income taxes	658	(291)	70
Aggregate change for the year	(1,073)	475	(113)
Ending Balance	$ 702	$ 1,775	$ 1,300

Supplemental Oil and Gas Disc98

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, 2015	Dec. 31, 2014	Dec. 31, 2013
Consolidated entities
Results of operations	$ (170,567)	$ (19,703)	$ 8,490
Consolidated Entities [Member]
Consolidated entities
Revenues	51,553	82,919	69,036
Production costs	(19,820)	(19,727)	(12,477)
Exploration costs	(11,864)	(17,416)	(10,486)
Depreciation, depletion, amortization	(28,774)	(29,442)	(19,552)
Results of Operations, Impairment of Oil and Gas Properties	(164,831)	(32,665)	(473)
Oil and gas administrative expenses	(11,700)	(17,000)	(14,407)
Results of Operations, Accretion of Asset Retirement Obligations	(144)	(121)	(94)
Income tax expenses	14,717	13,398	(3,471)
Results of operations	(170,863)	(20,054)	8,076
Equity Method Investee [Member]
Consolidated entities
Royalty revenues	428	786	801
Production costs	(102)	(105)	(123)
Oil and gas administrative expenses	(51)	(95)	(86)
Income tax expenses	21	(235)	(178)
Results of operations	$ 296	$ 351	$ 414

Summary of Quarterly Results 99

Summary of Quarterly Results of Operations - Summary of Quarterly Results of Operations (Detail) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended																12 Months Ended
		Dec. 31, 2015		Sep. 30, 2015		Jun. 30, 2015		Mar. 31, 2015		Dec. 31, 2014		Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]
Impairment of Oil and Gas Properties		$ 37,646		$ 81,240		$ 45,938		$ 7		$ 30,591		$ 735		$ 584		$ 755		$ 164,831	$ 32,665
Total revenues		114,018	[1]	43,168	[1]	57,430	[1]	47,805	[1]	80,316	[1]	58,840	[1]	83,013	[1]	84,605	[1]	262,421	306,774	$ 331,045
Gross profit	[1]	8,341		(69,572)		(35,009)		17,289		(6,259)		19,606		33,261		35,025
Operating income (loss)		(9,482)	[1]	(94,751)	[1]	(52,714)	[1]	(7,737)	[1]	(16,783)	[1]	12,716	[1]	26,942	[1]	15,883	[1]	(164,684)	38,758	46,577
Equity in earnings of unconsolidated ventures		4,470	[1]	2,909	[1]	5,584	[1]	3,045	[1]	4,720	[1]	2,016	[1]	958	[1]	991	[1]	16,008	8,685	8,737
Income (loss) before taxes		(11,983)	[1]	(100,095)	[1]	(55,062)	[1]	(12,596)	[1]	(18,713)	[1]	7,994	[1]	22,799	[1]	13,665	[1]	(179,736)	25,745	42,269
Net income (loss) attributable to Forestar Group Inc.		$ (6,166)	[1]	$ (164,216)	[1]	$ (34,507)	[1]	$ (8,158)	[1]	$ (11,800)	[1]	$ 5,227	[1]	$ 14,822	[1]	$ 8,334	[1]	$ (213,047)	$ 16,583	$ 29,321
Net income (loss) per share - basic		$ (0.18)	[1]	$ (4.79)	[1]	$ (1.01)	[1]	$ (0.24)	[1]	$ (0.34)	[1]	$ 0.12	[1]	$ 0.34	[1]	$ 0.20	[1]	$ (6.22)	$ 0.38	$ 0.81
Net income (loss) per share - diluted		$ (0.18)	[1]	$ (4.79)	[1]	$ (1.01)	[1]	$ (0.24)	[1]	$ (0.34)	[1]	$ 0.12	[1]	$ 0.34	[1]	$ 0.19	[1]	$ (6.22)	$ 0.38	$ 0.80
[1]	Non-cash impairment charges for unproved leasehold interests and proved oil and gas properties included in our quarterly financial results are as follows: First Quarter Second Quarter Third Quarter FourthQuarter (In thousands)2015$7 $45,938 $81,240 $37,6462014755 584 735 30,591

Subsequent Events (Details)

Subsequent Events (Details) - Disposal Group, Not Discontinued Operations [Member] - Subsequent Event [Member]	Mar. 01, 2016USD ($)$ / bbl	Feb. 04, 2016USD ($)
Kansas and Nebraska Oil and Gas Properties [Member]
Subsequent Event [Line Items]
Purchase price of properties sold	$ 21,000,000
Contingent payment for properties sold	$ 2,000,000
Minimum WTI oil price for contingent consideration (in US$ per Bbl) | $ / bbl	60
Minimum duration of WTI oil price at $60 per Bbl	60 days
Disposal Group, Including Discontinued Operation, Contingent Consideration, Minimum Oil Price Duration Following Close Period	1 year
Radisson Hotel & Suites, Austin [Member]
Subsequent Event [Line Items]
Purchase price of properties sold		$ 130,000,000

Schedule III - Consolidated Rea

Schedule III - Consolidated Real Estate and Accumulated Depreciation (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 383,570
Buildings & Improvements		56,559
Improvements less Cost of Sales and Other		169,624
Carrying Costs	[1]	9,091
Land & Land Improvements		509,999
Buildings & Improvements		108,845
Total		618,844	$ 607,133	$ 547,530	$ 545,370
Accumulated depreciation		(32,129)	$ (31,377)	$ (28,066)	$ (28,220)
SEC Schedule III, Real Estate and Accumulated Depreciation, Amount of Encumbrances		43,691
Entitled, developed and under development projects [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		283,025
Improvements less Cost of Sales and Other		60,025
Carrying Costs	[1]	9,091
Land & Land Improvements		352,141
Total		352,141
SEC Schedule III, Real Estate and Accumulated Depreciation, Amount of Encumbrances		4,355
Entitled, developed and under development projects [Member] | Other County [Member] | Other Property [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		8,443
Improvements less Cost of Sales and Other		(4,097)
Carrying Costs	[1]	653
Land & Land Improvements		4,999
Total		4,999
Entitled, developed and under development projects [Member] | TENNESSEE | Williamson County [Member] | Morgan Farms [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		6,841
Improvements less Cost of Sales and Other		(552)
Carrying Costs	[1]	166
Land & Land Improvements		6,455
Total		$ 6,455
Date of Construction		2,013
Date Acquired		2,013
Entitled, developed and under development projects [Member] | TENNESSEE | Williamson County [Member] | Vickery Park [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,575
Improvements less Cost of Sales and Other		560
Land & Land Improvements		4,135
Total		$ 4,135
Date Acquired		2,015
Entitled, developed and under development projects [Member] | TENNESSEE | Williamson County [Member] | Weatherford Estates [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 856
Improvements less Cost of Sales and Other		1,603
Land & Land Improvements		2,459
Total		$ 2,459
Date of Construction		2,015
Date Acquired		2,014
Entitled, developed and under development projects [Member] | TENNESSEE | Williamson County [Member] | Beckwith Crossing [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,294
Improvements less Cost of Sales and Other		2,519
Land & Land Improvements		3,813
Total		$ 3,813
Date of Construction		2,015
Date Acquired		2,014
Entitled, developed and under development projects [Member] | ARIZONA | Pima County [Member] | Dove Mountain [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 5,860
Improvements less Cost of Sales and Other		3
Land & Land Improvements		5,863
Total		$ 5,863
Date Acquired		2,015
Entitled, developed and under development projects [Member] | California [Member] | Contra Costa County [Member] | San Joaquin River [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 12,225
Improvements less Cost of Sales and Other		(3,310)
Land & Land Improvements		8,915
Total		8,915
Entitled, developed and under development projects [Member] | COLORADO | Douglas County [Member] | Pinery West [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		7,308
Improvements less Cost of Sales and Other		3,691
Land & Land Improvements		10,999
Total		$ 10,999
Date of Construction		2,006
Date Acquired		2,006
Entitled, developed and under development projects [Member] | COLORADO | Weld County [Member] | Buffalo Highlands [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,001
Improvements less Cost of Sales and Other		547
Land & Land Improvements		3,548
Total		$ 3,548
Date of Construction		2,006
Date Acquired		2,005
Entitled, developed and under development projects [Member] | COLORADO | Weld County [Member] | Johnstown Farms [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 2,749
Improvements less Cost of Sales and Other		4,024
Carrying Costs	[1]	188
Land & Land Improvements		6,961
Total		$ 6,961
Date of Construction		2,002
Date Acquired		2,002
Entitled, developed and under development projects [Member] | COLORADO | Weld County [Member] | Stone Braker [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,878
Improvements less Cost of Sales and Other		(1,469)
Land & Land Improvements		2,409
Total		$ 2,409
Date of Construction		2,005
Date Acquired		2,005
Entitled, developed and under development projects [Member] | Georgia [Member] | Cobb County [Member] | West Oaks [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,669
Improvements less Cost of Sales and Other		232
Land & Land Improvements		1,901
Total		$ 1,901
Date of Construction		2,015
Date Acquired		2,015
Entitled, developed and under development projects [Member] | Georgia [Member] | Paulding County [Member] | Harris Place [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 265
Improvements less Cost of Sales and Other		(111)
Land & Land Improvements		154
Total		$ 154
Date Acquired		2,012
Entitled, developed and under development projects [Member] | Georgia [Member] | Paulding County [Member] | Seven Hills [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 2,964
Improvements less Cost of Sales and Other		145
Land & Land Improvements		3,109
Total		$ 3,109
Date Acquired		2,012
Entitled, developed and under development projects [Member] | South Carolina [Member] | York County [Member] | Habersham [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,877
Improvements less Cost of Sales and Other		3,072
Carrying Costs	[1]	239
Land & Land Improvements		7,188
Total		$ 7,188
Date of Construction		2,014
Date Acquired		2,013
Entitled, developed and under development projects [Member] | South Carolina [Member] | Lancaster County [Member] | Ansley [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 5,089
Improvements less Cost of Sales and Other		574
Land & Land Improvements		5,663
Total		$ 5,663
Date Acquired		2,015
Entitled, developed and under development projects [Member] | North Carolina [Member] | Mechlanburg County [Member] | Walden [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 12,085
Improvements less Cost of Sales and Other		345
Land & Land Improvements		12,430
Total		$ 12,430
Date Acquired		2,015
Entitled, developed and under development projects [Member] | Texas [Member] | Hays County [Member] | Arrowhead Ranch [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 12,856
Improvements less Cost of Sales and Other		6,537
Land & Land Improvements		19,393
Total		$ 19,393
Date of Construction		2,015
Date Acquired		2,007
Entitled, developed and under development projects [Member] | Texas [Member] | Williamson County [Member] | La Conterra [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 4,024
Improvements less Cost of Sales and Other		(2,790)
Carrying Costs	[1]	293
Land & Land Improvements		1,527
Total		$ 1,527
Date Acquired		2,006
Entitled, developed and under development projects [Member] | Texas [Member] | Williamson County [Member] | Westside at Buttercup Creek [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 13,149
Improvements less Cost of Sales and Other		(13,586)
Carrying Costs	[1]	488
Land & Land Improvements		51
Total		$ 51
Date of Construction		1,993
Date Acquired		1,993
Entitled, developed and under development projects [Member] | Texas [Member] | Tarrant County [Member] | Summer Creek Ranch [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 2,887
Improvements less Cost of Sales and Other		(1,601)
Land & Land Improvements		1,286
Total		$ 1,286
Date Acquired		2,012
Entitled, developed and under development projects [Member] | Texas [Member] | Tarrant County [Member] | Bar C Ranch [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,365
Improvements less Cost of Sales and Other		3,258
Carrying Costs	[1]	32
Land & Land Improvements		4,655
Total		$ 4,655
Date Acquired		2,012
Entitled, developed and under development projects [Member] | Texas [Member] | Nueces County [Member] | Tortuga Dunes [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 12,080
Improvements less Cost of Sales and Other		9,670
Land & Land Improvements		21,750
Total		$ 21,750
Date Acquired		2,006
Entitled, developed and under development projects [Member] | Texas [Member] | Calhoun County [Member] | Caracol [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 8,603
Improvements less Cost of Sales and Other		3,688
Carrying Costs	[1]	2,047
Land & Land Improvements		14,338
Total		$ 14,338
Date of Construction		2,006
Date Acquired		2,006
SEC Schedule III, Real Estate and Accumulated Depreciation, Amount of Encumbrances		$ 2,237
Entitled, developed and under development projects [Member] | Texas [Member] | Bastrop County [Member] | Hunters Crossing [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		3,613
Improvements less Cost of Sales and Other		5,180
Carrying Costs	[1]	358
Land & Land Improvements		9,151
Total		$ 9,151
Date of Construction		2,001
Date Acquired		2,001
Entitled, developed and under development projects [Member] | Texas [Member] | Bastrop County [Member] | The Colony [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 8,726
Improvements less Cost of Sales and Other		15,206
Carrying Costs	[1]	161
Land & Land Improvements		24,093
Total		$ 24,093
Date of Construction		1,999
Date Acquired		1,999
Entitled, developed and under development projects [Member] | Texas [Member] | Bexar County [Member] | Cibolo Canyons [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 17,305
Improvements less Cost of Sales and Other		40,243
Carrying Costs	[1]	1,202
Land & Land Improvements		58,750
Total		$ 58,750
Date of Construction		2,004
Date Acquired		1,986
Entitled, developed and under development projects [Member] | Texas [Member] | Harris County [Member] | City Park [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,946
Improvements less Cost of Sales and Other		1,463
Carrying Costs	[1]	1,641
Land & Land Improvements		7,050
Total		$ 7,050
Date of Construction		2,002
Date Acquired		2,001
SEC Schedule III, Real Estate and Accumulated Depreciation, Amount of Encumbrances		$ 1,659
Entitled, developed and under development projects [Member] | Texas [Member] | Harris County [Member] | Barrington [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		8,950
Improvements less Cost of Sales and Other		(7,062)
Land & Land Improvements		1,888
Total		$ 1,888
Date Acquired		2,011
Entitled, developed and under development projects [Member] | Texas [Member] | Harris County [Member] | Imperial Forest [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 5,345
Improvements less Cost of Sales and Other		819
Land & Land Improvements		6,164
Total		$ 6,164
Date of Construction		2,015
Date Acquired		2,014
Entitled, developed and under development projects [Member] | Texas [Member] | Collin County [Member] | Lakes Of Prosper [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 8,951
Improvements less Cost of Sales and Other		(3,550)
Carrying Costs	[1]	180
Land & Land Improvements		5,581
Total		$ 5,581
Date Acquired		2,012
Entitled, developed and under development projects [Member] | Texas [Member] | Collin County [Member] | Maxwell Creek [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 9,904
Improvements less Cost of Sales and Other		(7,946)
Carrying Costs	[1]	635
Land & Land Improvements		2,593
Total		$ 2,593
Date of Construction		2,000
Date Acquired		2,000
Entitled, developed and under development projects [Member] | Texas [Member] | Collin County [Member] | Park Place [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 2,177
Improvements less Cost of Sales and Other		3,661
Land & Land Improvements		5,838
Total		$ 5,838
Date of Construction		2,014
Date Acquired		2,013
Entitled, developed and under development projects [Member] | Texas [Member] | Collin County [Member] | Timber Creek [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 7,282
Improvements less Cost of Sales and Other		9,137
Land & Land Improvements		16,419
Total		$ 16,419
Date of Construction		2,007
Date Acquired		2,007
Entitled, developed and under development projects [Member] | Texas [Member] | Collin County [Member] | Village Park [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 4,772
Improvements less Cost of Sales and Other		(4,765)
Carrying Costs	[1]	45
Land & Land Improvements		52
Total		$ 52
Date Acquired		2,012
Entitled, developed and under development projects [Member] | Texas [Member] | Comal County [Member] | Oak Creek Estates [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,921
Improvements less Cost of Sales and Other		2,314
Carrying Costs	[1]	175
Land & Land Improvements		4,410
Total		$ 4,410
Date of Construction		2,006
Date Acquired		2,005
Entitled, developed and under development projects [Member] | Texas [Member] | Dallas County [Member] | Stoney Creek [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 12,822
Improvements less Cost of Sales and Other		2,783
Carrying Costs	[1]	49
Land & Land Improvements		15,654
Total		$ 15,654
Date of Construction		2,007
Date Acquired		2,007
Entitled, developed and under development projects [Member] | Texas [Member] | Denton County [Member] | Lantana [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 27,673
Improvements less Cost of Sales and Other		(7,382)
Land & Land Improvements		20,291
Total		$ 20,291
Date of Construction		2,000
Date Acquired		1,999
Entitled, developed and under development projects [Member] | Texas [Member] | Denton County [Member] | River's Edge [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 1,227
Improvements less Cost of Sales and Other		381
Land & Land Improvements		1,608
Total		$ 1,608
Date Acquired		2,014
Entitled, developed and under development projects [Member] | Texas [Member] | Denton County [Member] | The Preserve At Pecan Creek [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 5,855
Improvements less Cost of Sales and Other		(3,905)
Carrying Costs	[1]	436
Land & Land Improvements		2,386
Total		$ 2,386
Date of Construction		2,006
Date Acquired		2,005
Entitled, developed and under development projects [Member] | Texas [Member] | Fort Bend County [Member] | Summer Lakes [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 4,269
Improvements less Cost of Sales and Other		968
Land & Land Improvements		5,237
Total		$ 5,237
Date of Construction		2,013
Date Acquired		2,012
Entitled, developed and under development projects [Member] | Texas [Member] | Fort Bend County [Member] | Summer Park [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 4,804
Improvements less Cost of Sales and Other		57
Land & Land Improvements		4,861
Total		$ 4,861
Date of Construction		2,013
Date Acquired		2,012
Entitled, developed and under development projects [Member] | Texas [Member] | Fort Bend County [Member] | Willow Creek Farms [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,479
Improvements less Cost of Sales and Other		(311)
Carrying Costs	[1]	90
Land & Land Improvements		3,258
Total		$ 3,258
Date of Construction		2,012
Date Acquired		2,012
SEC Schedule III, Real Estate and Accumulated Depreciation, Amount of Encumbrances		$ 459
Entitled, developed and under development projects [Member] | Missouri [Member] | Clay County [Member] | Somerbrook [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		3,061
Improvements less Cost of Sales and Other		(218)
Carrying Costs	[1]	13
Land & Land Improvements		2,856
Total		$ 2,856
Date of Construction		2,003
Date Acquired		2,001
Undeveloped Land Type [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 61,742
Improvements less Cost of Sales and Other		36,439
Carrying Costs	[1]	0
Land & Land Improvements		98,181
Total		98,181
SEC Schedule III, Real Estate and Accumulated Depreciation, Amount of Encumbrances		0
Undeveloped Land Type [Member] | Other County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		9,170
Improvements less Cost of Sales and Other		7,661
Land & Land Improvements		16,831
Total		16,831
Undeveloped Land Type [Member] | California [Member] | Los Angeles [Member] | Land In Entitlement Process [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		3,950
Improvements less Cost of Sales and Other		19,564
Land & Land Improvements		23,514
Total		$ 23,514
Date Acquired		1,997
Undeveloped Land Type [Member] | Georgia [Member] | Coweta County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 3,089
Improvements less Cost of Sales and Other		1,343
Land & Land Improvements		4,432
Total		4,432
Undeveloped Land Type [Member] | Georgia [Member] | Dawson County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		2,228
Improvements less Cost of Sales and Other		3,381
Land & Land Improvements		5,609
Total		5,609
Undeveloped Land Type [Member] | Georgia [Member] | Dawson County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		3,150
Improvements less Cost of Sales and Other		(108)
Land & Land Improvements		3,042
Total		3,042
Undeveloped Land Type [Member] | Georgia [Member] | Polk County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		2,354
Improvements less Cost of Sales and Other		(198)
Land & Land Improvements		2,156
Total		2,156
Undeveloped Land Type [Member] | Georgia [Member] | Bexar County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Improvements less Cost of Sales and Other		3,036
Land & Land Improvements		3,036
Total		3,036
Undeveloped Land Type [Member] | Georgia [Member] | Harris County [Member] | Land In Entitlement Process [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		685
Improvements less Cost of Sales and Other		1,151
Land & Land Improvements		1,836
Total		1,836
Undeveloped Land Type [Member] | Georgia [Member] | Bartow County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		4,057
Improvements less Cost of Sales and Other		(2,440)
Land & Land Improvements		1,617
Total		1,617
Undeveloped Land Type [Member] | Georgia [Member] | Carroll County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		13,564
Improvements less Cost of Sales and Other		2,580
Land & Land Improvements		16,144
Total		16,144
Undeveloped Land Type [Member] | Georgia [Member] | Cherokee County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		6,043
Improvements less Cost of Sales and Other		536
Land & Land Improvements		6,579
Total		6,579
Undeveloped Land Type [Member] | Georgia [Member] | Gilmer County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		2,748
Improvements less Cost of Sales and Other		(62)
Land & Land Improvements		2,686
Total		2,686
Undeveloped Land Type [Member] | Georgia [Member] | Haralson County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		195
Improvements less Cost of Sales and Other		88
Land & Land Improvements		283
Total		283
Undeveloped Land Type [Member] | Georgia [Member] | Lumpkin County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		3,015
Improvements less Cost of Sales and Other		(93)
Land & Land Improvements		2,922
Total		2,922
Undeveloped Land Type [Member] | Georgia [Member] | Paulding County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 7,494
Improvements less Cost of Sales and Other
Land & Land Improvements		$ 7,494
Total		7,494
Income Producing Properties [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		38,803
Buildings & Improvements		56,559
Improvements less Cost of Sales and Other		73,160
Carrying Costs	[1]	0
Land & Land Improvements		59,677
Buildings & Improvements		108,845
Total		168,522
Accumulated depreciation		(32,129)
SEC Schedule III, Real Estate and Accumulated Depreciation, Amount of Encumbrances		39,336
Income Producing Properties [Member] | TENNESSEE | Davidson County [Member] | Westmont [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		6,607
Improvements less Cost of Sales and Other		3,340
Land & Land Improvements		9,947
Total		$ 9,947
Date Acquired		2,014
Income Producing Properties [Member] | North Carolina [Member] | Mechlanburg County [Member] | East Morehead [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 5,779
Improvements less Cost of Sales and Other		14,208
Land & Land Improvements		19,987
Total		$ 19,987
Date Acquired		2,012
Income Producing Properties [Member] | Texas [Member] | Travis County [Member] | Radisson Hotel And Suites [Member]
Real Estate and Accumulated Depreciation [Line Items]
Buildings & Improvements		$ 10,603
Improvements less Cost of Sales and Other		52,286
Land & Land Improvements		0
Buildings & Improvements		62,889
Total		62,889
Accumulated depreciation		(29,268)
SEC Schedule III, Real Estate and Accumulated Depreciation, Amount of Encumbrances		15,400
Income Producing Properties [Member] | Texas [Member] | Travis County [Member] | Eleven [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		7,940
Buildings & Improvements		45,956
Improvements less Cost of Sales and Other		0
Land & Land Improvements		7,940
Buildings & Improvements		45,956
Total		53,896
Accumulated depreciation		$ (2,861)
Date of Construction		2,013
Date Acquired		2,014
SEC Schedule III, Real Estate and Accumulated Depreciation, Amount of Encumbrances		$ 23,936
Income Producing Properties [Member] | Texas [Member] | Travis County [Member] | Downtown Edge [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		11,202
Improvements less Cost of Sales and Other		1,504
Land & Land Improvements		12,706
Total		$ 12,706
Date Acquired		2,014
Income Producing Properties [Member] | Texas [Member] | Travis County [Member] | West Austin [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land		$ 7,275
Improvements less Cost of Sales and Other		1,822
Land & Land Improvements		9,097
Total		$ 9,097
Date Acquired		2,014
[1]	Includes natural gas liquids (NGLs).

Schedule III - Reconciliation o

Schedule III - Reconciliation of Real Estate and Accumulated Depreciation (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
SEC Schedule III, Real Estate and Accumulated Depreciation Disclosure [Abstract]
Beginning balance	$ 607,133	$ 547,530	$ 545,370
Amounts capitalized	124,633	214,184	111,428
Amounts retired or adjusted	(112,922)	(154,581)	(109,268)
Ending balance	618,844	607,133	547,530
Beginning balance	(31,377)	(28,066)	(28,220)
Depreciation expense	(6,810)	(3,319)	(2,185)
Amounts retired or adjusted	6,058	8	2,339
Ending balance	$ (32,129)	$ (31,377)	$ (28,066)