Forestar (FOR) 10-K 6 Mar 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Mar. 02, 2015	Jun. 30, 2014
Entity Information [Line Items]
Document Type	10-K
Amendment Flag	FALSE
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Trading Symbol	FOR
Entity Registrant Name	FORESTAR GROUP INC.
Entity Central Index Key	1406587
Current Fiscal Year End Date	-19
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		33,618,526
Entity Public Float			$457

CONSOLIDATED_BALANCE_SHEET

CONSOLIDATED BALANCE SHEET (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
ASSETS
Cash and cash equivalents	$170,127	$192,307
Real estate, net	575,756	519,464
Oil and gas properties and equipment, net	263,493	232,641
Investment in unconsolidated ventures	65,005	41,147
Timber	8,315	10,947
Receivables, net	24,589	39,252
Income taxes receivable	7,503	0
Prepaid expenses	6,000	5,136
Property and equipment, net	11,627	6,112
Deferred tax asset, net	40,624	40,398
Goodwill and other intangible assets	66,131	66,646
Other assets	19,029	18,102
TOTAL ASSETS	1,258,199	1,172,152
LIABILITIES AND EQUITY
Accounts payable	20,400	21,409
Accrued employee compensation and benefits	8,323	5,814
Accrued property taxes	5,966	3,822
Accrued interest	3,451	2,343
Income taxes payable	0	3,876
Earnest money deposits	10,045	10,854
Other accrued expenses	35,729	26,851
Other liabilities	31,799	24,379
Debt	432,744	357,407
TOTAL LIABILITIES	548,457	456,755
COMMITMENTS AND CONTINGENCIES
Forestar Group Inc. shareholders’ equity:
Preferred stock, par value $0.01 per share, 25,000,000 authorized shares, none issued	0	0
Common stock, par value $1.00 per share, 200,000,000 authorized shares, 36,946,603 issued at December 31, 2014 and December 31, 2013	36,947	36,947
Additional paid-in capital	558,945	556,676
Retained earnings	167,001	150,418
Treasury stock, at cost, 3,485,278 shares at December 31, 2014 and 2,199,666 shares at December 31, 2013	-55,691	-34,196
Total Forestar Group Inc. shareholders’ equity	707,202	709,845
Noncontrolling interests	2,540	5,552
TOTAL EQUITY	709,742	715,397
TOTAL LIABILITIES AND EQUITY	$1,258,199	$1,172,152

CONSOLIDATED_BALANCE_SHEET_Par

CONSOLIDATED BALANCE SHEET (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Statement of Financial Position [Abstract]
Preferred stock, par value	$0.01	$0.01
Preferred stock, shares authorized	25,000,000	25,000,000
Preferred stock, shares issued	0	0
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	3,485,278	2,199,666

CONSOLIDATED_STATEMENTS_OF_INC

CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
REVENUES
Real estate sales and other	$171,672	$152,684	$81,459
Commercial and income producing properties	41,440	95,327	38,656
Real estate	213,112	248,011	120,115
Oil and gas	84,300	72,313	44,220
Other natural resources	9,362	10,721	8,256
Total revenues	306,774	331,045	172,591
EXPENSES
Cost of real estate sales and other	-86,432	-76,628	-40,400
Cost of commercial and income producing properties	-37,332	-80,166	-29,639
Cost of oil and gas producing activities	-98,371	-42,067	-10,842
Cost of other natural resources	-3,006	-2,033	-2,995
Other operating	-58,683	-60,359	-55,213
General and administrative	-22,230	-28,376	-32,320
Total expenses	-306,054	-289,629	-171,409
GAIN ON SALE OF ASSETS	38,038	5,161	25,983
OPERATING INCOME	38,758	46,577	27,165
Equity in earnings of unconsolidated ventures	8,685	8,737	14,469
Interest expense	-30,286	-20,004	-19,363
Other non-operating income	8,588	6,959	3,621
INCOME BEFORE TAXES	25,745	42,269	25,892
Income tax expense	-8,657	-7,208	-8,016
Net income	17,088	35,061	17,876
Less: Net (income) attributable to noncontrolling interests	-505	-5,740	-4,934
NET INCOME ATTRIBUTABLE TO FORESTAR GROUP INC.	16,583	29,321	12,942
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING
Basic (usd per share)	35,317	35,365	35,214
Diluted (usd per share)	43,596	36,813	35,482
NET INCOME PER COMMON SHARE
Basic (usd per share)	$0.38	$0.81	$0.37
Diluted (usd per share)	$0.38	$0.80	$0.36
COMPREHENSIVE INCOME ATTRIBUTABLE TO FORESTAR GROUP INC.	$16,583	$29,321	$12,942

CONSOLIDATED_STATEMENTS_OF_EQU

CONSOLIDATED STATEMENTS OF EQUITY (USD $)	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Treasury Stock [Member]	Retained Earnings [Member]	Noncontrolling Interest [Member]
In Thousands, except Share data
Beginning Balances at Dec. 31, 2011	$511,212	$36,836	$398,517	($33,982)	$108,155	$1,686
Beginning Balances, Shares at Dec. 31, 2011		36,835,732		-2,212,876
Net income	17,876				12,942	4,934
Distributions to noncontrolling interest	-3,694					-3,694
Contributions from noncontrolling interest	1,133					1,133
Issuances of common stock, Shares		18,469
Issuances of common stock, Value	0	19	-19
Issuances of restricted stock, Shares				27,934
Issuances of restricted stock, Value	300		-129	429
Issuances from exercises of stock options, net of swaps, Shares		92,402		11,372
Issuances from exercises of stock options, net of swaps, Value	1,159	92	899	168
Shares withheld for payroll taxes, Shares				-59,603
Shares withheld for payroll taxes, Value	-968			-968
Shares repurchased, Shares				-94,450
Shares repurchased, Value	-1,409			-1,409
Share-based compensation	7,572		7,572
Tax benefit from exercise of restricted stock units and stock options and vested restricted stock	366		366
Ending Balances at Dec. 31, 2012	533,547	36,947	407,206	-35,762	121,097	4,059
Ending Balances, Shares at Dec. 31, 2012		36,946,603		-2,327,623
Net income	35,061				29,321	5,740
Distributions to noncontrolling interest	-7,269					-7,269
Contributions from noncontrolling interest	3,022					3,022
Issuances of restricted stock, Shares				7,298
Issuances of restricted stock, Value	2,871		2,721	150
Convertible note issuance proceeds, net of issuance costs and taxes	17,058		17,058
TEU issuance proceeds, net of issuance costs - 6,000,000 units	120,335		120,335
Issuances from exercises of stock options, net of swaps, Shares				189,864
Issuances from exercises of stock options, net of swaps, Value	2,106		-449	2,555
Shares withheld for payroll taxes, Shares	-59,219			-59,219
Shares withheld for payroll taxes, Value	-1,137		-8	-1,129
Forfeitures of restricted stock, Shares				-9,986
Forfeitures of restricted stock, Value	0		10	-10
Share-based compensation	9,911		9,911
Tax benefit from exercise of restricted stock units and stock options and vested restricted stock	-108		-108
Ending Balances at Dec. 31, 2013	715,397	36,947	556,676	-34,196	150,418	5,552
Ending Balances, Shares at Dec. 31, 2013		36,946,603		-2,199,666
Net income	17,088				16,583	505
Distributions to noncontrolling interest	-4,171					-4,171
Noncontrolling Interest, Increase from Business Combination	-2,585					-2,585
Dissolution of noncontrolling interests	1,342					1,342
Purchase of noncontrolling interests, net	-6,242		-2,969			-3,273
Issuances of common stock, Shares				164,914
Issuances of common stock, Value	0		-2,567	2,567
Issuances from exercises of stock options, net of swaps, Shares				105,885
Issuances from exercises of stock options, net of swaps, Value	1,206		-376	1,582
Shares withheld for payroll taxes, Shares	-55,238			-55,238
Shares withheld for payroll taxes, Value	-1,043		-4	-1,039
Shares repurchased, Shares	-1,491,187			-1,491,187
Shares repurchased, Value	-24,595			-24,595
Forfeitures of restricted stock, Shares				-9,986
Forfeitures of restricted stock, Value	0		10	-10
Share-based compensation	8,033		8,033
Tax benefit from exercise of restricted stock units and stock options and vested restricted stock	142		142
Ending Balances at Dec. 31, 2014	$709,742	$36,947	$558,945	($55,691)	$167,001	$2,540
Ending Balances, Shares at Dec. 31, 2014		36,946,603		-3,485,278

CONSOLIDATED_STATEMENTS_OF_EQU1

CONSOLIDATED STATEMENTS OF EQUITY CONSOLIDATED STATEMENTS OF EQUITY (Parenthetical) (6% Tangible Equity Units [Member])	0 Months Ended
	Nov. 27, 2013
	Unit
6% Tangible Equity Units [Member]
Units issued	6,000,000

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
CASH FLOWS FROM OPERATING ACTIVITIES:
Consolidated net income	$17,088,000	$35,061,000	$17,876,000
Adjustments:
Depreciation, depletion and amortization	41,715,000	29,980,000	18,926,000
Change in deferred income taxes	1,645,000	5,389,000	-6,506,000
Change in unrecognized tax benefits	0	-6,251,000	151,000
Equity in (earnings) loss of unconsolidated ventures	-8,685,000	-8,737,000	-14,469,000
Distributions of earnings of unconsolidated ventures	5,721,000	6,360,000	3,251,000
Proceeds from consolidated ventures’ sale of assets, net	0	0	24,294,000
Share-based compensation	3,417,000	16,809,000	14,929,000
Real estate cost of sales	84,665,000	104,899,000	39,360,000
Dry hole and unproved leasehold impairment costs	29,528,000	5,837,000	1,069,000
Real estate development and acquisition expenditures, net	-114,694,000	-106,609,000	-91,940,000
Reimbursements from utility and improvement districts	66,047,000	9,945,000	8,524,000
Other changes in real estate	3,537,000	3,146,000	1,384,000
Changes in deferred income	143,000	-2,246,000	1,070,000
Asset impairments	15,934,000	1,790,000	0
Gain on sale of assets	-38,038,000	-5,161,000	-25,983,000
Other	2,207,000	1,491,000	-21,000
Changes in:
Notes and accounts receivables	10,704,000	-3,864,000	-1,132,000
Prepaid expenses and other	2,180,000	-795,000	-2,560,000
Accounts payable and other accrued liabilities	-4,653,000	-1,557,000	-2,527,000
Income taxes	-11,379,000	3,290,000	-7,914,000
Net cash provided by (used for) operating activities	107,082,000	88,777,000	-22,218,000
Statement [Line Items]
Property, equipment, software, reforestation and other	-16,398,000	-11,828,000	-2,735,000
Oil and gas properties and equipment	-101,145,000	-96,069,000	-21,416,000
Acquisition of partner's interest in unconsolidated multifamily venture, net of cash	-20,155,000
Acquisition of oil and gas properties	-1,100,000	0	0
Investment in unconsolidated ventures	-14,692,000	-857,000	-2,318,000
Proceeds from sale of assets	21,962,000	1,333,000	0
Return of investment in unconsolidated ventures	1,797,000	3,494,000	12,654,000
Business acquisition, net of cash acquired	0	0	-152,915,000
Proceeds from sale of multifamily property	0	0	29,474,000
Proceeds from sale of venture interest	0	0	32,095,000
Other	0	0	42,000
Net cash (used for) investing activities	-129,731,000	-103,927,000	-105,119,000
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from issuance of convertible senior notes, net	0	120,795,000	0
Proceeds from issuance of senior secured notes, net	241,947,000	0	0
Proceeds from issuance of tangible equity units, net	0	144,998,000	0
Payments of debt	-225,481,000	-106,076,000	-74,226,000
Additions to debt	22,593,000	43,911,000	203,642,000
Deferred financing fees	-3,217,000	-438,000	-5,883,000
Distributions to noncontrolling interests, net	-3,146,000	-7,154,000	-3,266,000
Purchase of noncontrolling interests	-7,971,000	0	0
Exercise of stock options	1,206,000	2,106,000	1,159,000
Repurchases of common stock	-24,595,000	0	-1,409,000
Payroll taxes on restricted stock and stock options	-1,043,000	-1,137,000	-968,000
Excess income tax benefit from share-based compensation	176,000	91,000	366,000
Net cash provided by financing activities	469,000	197,096,000	119,415,000
Net (decrease) increase in cash and cash equivalents	-22,180,000	181,946,000	-7,922,000
Cash and cash equivalents at beginning of year	192,307,000	10,361,000	18,283,000
Cash and cash equivalents at year-end	170,127,000	192,307,000	10,361,000
Cash paid during the year for:
Interest	22,936,000	13,818,000	12,820,000
Income taxes	18,322,000	4,955,000	21,678,000
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION:
Capitalized interest	1,154,000	816,000	721,000
Noncontrolling interests	2,904,000	2,907,000	1,032,000
Multi Family Property [Member]
Statement [Line Items]
Acquisition of partner's interest in unconsolidated multifamily venture, net of cash		$0	$0

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
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 2014 and 2013, restricted cash was $217,000 and $3,954,000 and is included in other assets.
	Cash Flows
	Expenditures for the acquisition and development of single-family and multifamily real estate are classified as operating activities. Expenditures for the acquisition of stabilized income producing properties, 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 2014 and 2013 were $19,405,000 and $12,976,000 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 $1,188,000 at year-end 2014 and $1,544,000 at year-end 2013 and is included in other assets. The amortization of these capitalized costs was $1,067,000 in 2014, $1,593,000 in 2013 and $1,320,000 in 2012 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.
	The following summarizes the changes in asset retirement obligations:
		Year-End
		2014				2013
		(In thousands)
	Beginning balance	$	1,483			$	1,360
	Additions	314				29
	Property dispositions	(230		)		—
	Change in estimate	118				—
	Accretion expense	122				94
		$	1,807			$	1,483
	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 2014, 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. As of year-end 2014, we have $8,575,000 in capitalized exploratory well costs pending determination of proved reserves, none of which have been capitalized for a period greater than one year. 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		Carrying
				Value Year-End
		Useful Lives		2014				2013
				(In thousands)
	Buildings and building improvements	10 to 40 years		$	4,461			$	4,111
	Property and equipment	2 to 10 years		14,084				8,240
				18,545				12,351
	Less: accumulated depreciation			(6,918		)		(6,239		)
				$	11,627			$	6,112
	Depreciation expense of property and equipment was $903,000 in 2014, $1,028,000 in 2013 and $962,000 in 2012.
	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 real estate 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 100 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.
	Reclassifications
	In 2014, we have reclassified prior years' earnest money deposits that were included in other accrued expenses and other liabilities on our consolidated balance sheets as a separate line item to conform to the current year presentation.
	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 revenue from our multifamily properties when payments are due from residents, generally on a monthly basis.
	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.
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. No such allowance was considered necessary at December 31, 2014 or 2013.
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, 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 102,000 acres of timber, primarily in Georgia. The non-cash cost of timber cut and sold is $371,000 in 2014, $609,000 in 2013 and $1,220,000 in 2012 and is included in depreciation, depletion and amortization in our statement of cash flows.

New_and_Pending_Accounting_Pro

New and Pending Accounting Pronouncements	12 Months Ended
	Dec. 31, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]
New and Pending Accounting Pronouncements	Accounting Standards Adopted in 2014
	In 2014, we adopted ASU 2013-04 — Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation Is Fixed at the Reporting Date, ASU 2014-12 — Compensation-Stock Compensation (Topic 718): Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period and ASU 2014-17 — Business Combinations (Topic 805): Pushdown Accounting. Adoption did not materially affect our earnings, financial position or disclosures.
	We also adopted ASU 2014-08 — Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360), Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. ASU 2014-08 raises the threshold for a disposal to qualify as a discontinued operation and requires new and expanded disclosures of both discontinued operations and certain other disposals that do not meet the definition of a discontinued operation.  The Company adopted the updated standard in second quarter 2014. As a result, certain asset disposals were not considered discontinued operations, due to the higher threshold under the updated standard, but that would have qualified as discontinued operations under the previous guidance.

Goodwill_and_Other_Intangible_

Goodwill and Other Intangible Assets	12 Months Ended
	Dec. 31, 2014
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
		2014		2013
		(In thousands)
	Goodwill	$	63,423	$	64,493
	Identified intangibles, net	2,708		2,153
		$	66,131	$	66,646
	Goodwill related to oil and gas properties is $59,549,000 and $60,619,000 at year-end 2014 and 2013. Goodwill associated with our water resources company acquired in 2010 is $3,874,000 at year-end 2014 and 2013. The change in goodwill for oil and gas properties is related to goodwill allocated to properties sold in 2014.
	Identified intangibles include $1,681,000 in indefinite lived groundwater leases associated with a water resources company acquired in 2010, $649,000 related to in-place tenant leases with definite lives associated with the purchase of our partner's interest in the Eleven venture and $378,000 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, 2014
Real Estate [Abstract]
Real Estate	Real Estate
	Real estate consists of:
		At Year-End
		2014			2013
		(In thousands)
	Entitled, developed and under development projects	$	321,273		$	361,687
	Undeveloped land (includes land in entitlement)	93,182			86,367
	Commercial and income producing properties
	Carrying value	192,678			99,476
	Accumulated depreciation	(31,377		)	(28,066		)
	Net carrying value	161,301			71,410
		$	575,756		$	519,464
	Our estimated cost of assets we expect to convey to utility and improvement districts were $65,212,000 in 2014 and $62,183,000 in 2013, which includes $31,913,000 at year-end 2014 and $41,795,000 at year-end 2013 related to our Cibolo Canyons project near San Antonio. These costs relate to water, sewer and other infrastructure assets we have submitted or will submit to utility or improvement districts for approval and reimbursement. We submitted for reimbursement to these districts $7,118,000 in 2014 and $17,923,000 in 2013. We collected $15,497,000 from these districts in 2014, of which $9,883,000 is related to our Cibolo Canyons project and was accounted for as a reduction of our investment in the mixed-use development. We collected $5,545,000 from these districts in 2013, of which $600,000 related to our Cibolo Canyons project. We expect to collect the remaining amounts billed when these districts achieve adequate tax bases to support payment.
	In 2014, we received $50,550,000 from 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 has a balance of $9,010,000 at year-end 2014. The surety bond will decrease as CCSID makes annual ad valorem tax rebate payments to SARE, which obligation is scheduled to be retired in full by 2020. As a result of these transactions, we recorded a gain of $6,577,000 after recovery of our full resort investment of $24,067,000, which was included in entitled, developed and under development projects. In 2013, we received $4,400,000 from CCSID from hotel occupancy and sales revenues collected as taxes by CCSID.
	In 2014, undeveloped land increased due to a non-monetary exchange of leasehold timber rights on approximately 10,300 acres for 5,400 acres of undeveloped land with a partner in a consolidated venture, in which we recorded a $10,476,000 gain.
	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 real estate commercial and income producing properties of $53,917,000 and other assets of $992,000 primarily consisting 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.
	In 2014, the increase in commercial and income producing properties was principally due to the Eleven multifamily project which is now wholly-owned after acquisition of our partner's interest in the Eleven venture and $26,110,000 from acquisition of three multifamily development sites. At year-end 2014, commercial and income producing properties represents our $53,382,000 investment in our 257-unit multifamily property in Austin, our investment in a 413 guest room hotel in Austin with a carrying value of $30,712,000, our $33,062,000 investment in our 354-unit multifamily property in Dallas and our investment in multifamily development sites located in Austin, Charlotte, and Nashville with a combined carrying value of $44,145,000.
	As a general contractor on guaranteed maximum price contracts associated with two multifamily venture properties, we recognized charges of $5,111,000 in 2014 and $554,000 in 2013 related to cost overruns.
	We recognized non-cash asset impairment charges of $399,000 in 2014 associated with two owned and consolidated entitled projects. We had $1,790,000 non-cash impairment charges in 2013 associated with a master-planned community and golf club near Dallas. We had no non-cash asset impairment charges in 2012.
	Depreciation expense related to income producing properties was $3,319,000 in 2014, $2,507,000 in 2013 and $3,640,000 in 2012 and is included in other operating expense.

Oil_and_Gas_Properties_Notes

Oil and Gas Properties (Notes)	12 Months Ended
	Dec. 31, 2014
Oil and Gas Properties [Abstract]
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]	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
		2014			2013
		(In thousands)
	Unproved oil and gas properties	$	90,446		$	100,320
	Proved oil and gas properties	221,299			155,262
	Total costs	311,745			255,582
	Less accumulated depreciation, depletion and amortization	(48,252		)	(22,941		)
		$	263,493		$	232,641
	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 2014, we recognized non-cash impairment charges on our unproved leasehold interests of $17,130,000 and on our proved properties of $15,535,000 compared to $473,000 of non-cash impairment charges on our unproved leasehold interests in 2013 principally due to the significant decline in oil prices. Impairment charges are included in cost of oil and gas producing activities on our income statement.
	Asset Sales
	In 2014, we sold certain non-strategic assets and recorded gains of $8,526,000 related to the sale of approximately 650 net mineral acres leased from others in North Dakota and the sale of 124 gross (18 net) producing oil and gas wells primarily in Oklahoma. Total proceeds received were $17,660,000.

Investment_in_Unconsolidated_V

Investment in Unconsolidated Ventures	12 Months Ended
	Dec. 31, 2014
Equity Method Investments and Joint Ventures [Abstract]
Investment in Unconsolidated Ventures	Investment in Unconsolidated Ventures
	At year-end 2014, we had ownership interests in 15 ventures that we account for using the equity method.
	In 2014, we formed three new multifamily unconsolidated ventures:
	•FMF Littleton LLC was formed with AIGGRE Littleton Common Investor LLC (AIGGRE) to develop a 385-unit multifamily property in Littleton, Colorado. We own a 25 percent interest and AIGGRE owns the remaining 75 percent interest. We contributed $4,900,000 of land and pre-development costs to the venture, net of $9,852,000 of reimbursements received from the venture for land and pre-development costs we previously incurred. The venture obtained a senior secured construction loan in the amount of $46,384,000 that bears interest at 30-day LIBOR plus 1.90% payable monthly, of which none was outstanding at year-end 2014. We provided the lender a construction completion guaranty; a guaranty of repayment of 25 percent of the principal balance and unpaid accrued interest; and a nonrecourse carve-out guaranty. The principal guaranty will reduce from 25 percent of principal to 10 percent upon achievement of certain conditions. At year-end 2014, our investment in this venture is $6,287,000.
	•CREA FMF Nashville LLC was formed with Massachusetts Mutual Life Insurance Co. (MassMutual) to develop a 320-unit multifamily property in Nashville, Tennessee. We own a 30 percent interest and MassMutual owns the remaining 70 percent interest. We contributed $5,897,000 of land and pre-development costs to the venture, net of $7,191,000 of reimbursements received from the venture for pre-development costs we previously incurred. The venture obtained a senior secured construction loan in the amount of $51,950,000 that bears interest at 30-day LIBOR plus 2.50% per annum, of which $29,660,000 was outstanding at year-end 2014. MassMutual is obligated to make a capital contribution to the venture in an amount equal to its equity commitment under the construction loan in an amount not to exceed $14,220,000. Such capital contribution shall be paid upon the earlier of (i) March 17, 2015 (ii) two months after the issuance of final certificates of occupancy with respect to the entire project, or (iii) ten business days after the date on which the long-term credit rating of MassMutual is less than AA- from Standard & Poor's or A1 from Moody's. We provided the lender a construction completion guaranty; a guaranty of repayment of 25 percent of the principal balance and unpaid accrued interest; and a nonrecourse carve-out guaranty. The principal guaranty will reduce from 25 percent of principal to zero upon achievement of certain conditions. At year-end 2014, our investment in this venture is $5,516,000.
	•Elan 99, LLC was formed with GS Elan 99 Holdings, LLC (Greystar) to develop a 360-unit multifamily property in Katy, Texas. We own a 90 percent non-managing member interest and Greystar owns the remaining 10 percent managing member interest. We contributed $8,757,000 in cash to the venture. The venture obtained a senior secured construction loan in the amount of $37,275,000 that bears interest at LIBOR plus 2.50% per annum which reduces to 2.30% upon meeting a debt coverage ratio test, of which $1,000 was outstanding at year-end 2014. Greystar will act as the guarantor for the construction loan as a developer and general contractor for the benefit of the Elan 99, LLC venture and Forestar as the investor member. At year-end 2014, our investment in this venture is $8,679,000.
	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
		2014		2013		2014		2013			2014			2013			2014			2013
		(In thousands)
	242, LLC(b)	$	33,021	$	23,751	$	6,940	$	921		$	21,789		$	19,838		$	10,098		$	9,084
	CJUF III, RH Holdings(c)	—		36,320		—		18,492			—			15,415			—			3,235
	CL Ashton Woods, LP(d)	13,269		10,473		—		—			11,453			9,704			6,015			3,544
	CL Realty, LLC	7,960		8,298		—		—			7,738			8,070			3,869			4,035
	CREA FMF Nashville LLC(b)	40,014		—		29,660		—			5,987			—			5,516			—
	Elan 99, LLC	10,070		—		1		—			9,643			—			8,679			—
	FMF Littleton LLC	26,953		—		—		—			24,435			—			6,287			—
	FMF Peakview LLC	43,638		30,673		23,070		12,533			17,464			16,620			3,575			3,406
	HM Stonewall Estates, Ltd.(d)	3,750		3,781		669		63			3,081			3,718			1,752			2,128
	LM Land Holdings, LP(d)	25,561		33,298		4,448		9,768			18,500			13,347			9,322			8,283
	PSW Communities, LP	16,045		—		10,515		—			4,415			—			3,924			—
	TEMCO Associates, LLC	11,756		13,320		—		—			11,556			13,160			5,778			6,580
	Other ventures (4)(e)	8,453		12,723		26,944		29,699			(25,614		)	(31,357		)	190			852
		$	240,490	$	172,637	$	102,247	$	71,476		$	110,447		$	68,515		$	65,005		$	41,147
	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
		2014		2013		2012		2014			2013			2012			2014			2013			2012
		(In thousands)
	242, LLC(b)	$	5,612	$	6,269	$	4,868	$	2,951		$	1,512		$	1,040		$	1,514		$	805		$	572
	CJUF III, RH Holdings(c)	2,168		120		—		(956		)	(652		)	(241		)	(956		)	(652		)	(241		)
	CL Ashton Woods, LP(d)	5,431		9,018		3,353		1,748			2,660			1,472			2,471			4,169			2,024
	CL Realty, LLC	1,573		1,603		2,667		1,068			1,028			1,060			534			514			530
	CREA FMF Nashville LLC(b)	—		—		—		(163		)	—			—			(163		)	—			—
	Elan 99, LLC	—		—		—		(87		)	—			—			(78		)	—			—
	FMF Littleton LLC	—		—		—		(239		)	—			—			(60		)	—			—
	FMF Peakview LLC	4		1		—		(410		)	(252		)	(116		)	(83		)	(50		)	(23		)
	HM Stonewall Estates, Ltd.(d)	1,728		2,922		2,500		613			1,082			829			248			452			332
	LM Land Holdings, LP(d)	21,980		25,426		10,268		15,520			11,012			1,895			4,827			3,418			257
	PSW Communities, LP	—		—		—		(86		)	—			—			(76		)	—			—
	TEMCO Associates, LLC	2,155		630		702		494			96			(80		)	247			48			(40		)
	Other ventures (4)(f)	1,792		5,994		8,790		4,835			176			10,032			260			33			11,058
		$	42,443	$	51,983	$	33,148	$	25,288		$	16,662		$	15,891		$	8,685		$	8,737		$	14,469
	_____________________
	(a)	Total includes current maturities of $65,795,000 at year-end 2014, of which $42,566,000 is non-recourse to us, and $37,966,000 at year-end 2013, of which $37,822,000 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 $1,621,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2014.
	(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. At year-end 2014, we no longer have an equity method investment in the Eleven venture.
	(d)	Includes unrecognized basis difference of $1,517,000 which is reflected as a reduction of our investment in unconsolidated ventures at year-end 2014. 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 25 to 50 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.
	(f)	In 2012, other ventures earnings include $5,307,000 related to a consolidated venture’s share of the gain associated with Round Rock Luxury Apartment's sale of Las Brisas. Our share of these earnings was $2,541,000 and we allocated $2,766,000 to net income attributable to noncontrolling interests.
	In 2014, we invested $14,692,000 in these ventures and received $7,518,000 in distributions; in 2013, we invested $857,000 in these ventures and received $9,854,000 in distributions; in 2012, we invested $2,318,000 in these ventures and received $15,905,000 in distributions. Distributions include both return of investments and distributions of earnings.
	We provide construction and development services for some of these ventures for which we receive fees. Fees for these services were $2,275,000 in 2014, $1,068,000 in 2013 and $935,000 in 2012 and are included in real estate revenues.

Receivables

Receivables	12 Months Ended
	Dec. 31, 2014
Receivables [Abstract]
Receivables	Receivables
	Receivables consist of:
		At Year-End
		2014			2013
		(In thousands)
	Loan secured by real estate	$	3,574		$	7,610
	Other loans secured by real estate, average interest rate of 4.41% at year-end 2014 and 5.00% at year-end 2013	1,737			7,987
	Oil and gas joint interest billing receivables	5,738			3,896
	Oil and gas revenue accruals	7,293			8,137
	Other receivables and accrued interest	6,505			11,648
		24,847			39,278
	Allowance for bad debts	(258		)	(26		)
		$	24,589		$	39,252
	At year-end 2014, we have $3,574,000 invested in a loan secured by real estate. The loan was acquired from a financial institution in 2011 when the loan was non-performing and is secured by a lien on developed and undeveloped real estate located near Houston designated for single-family residential and commercial development. In 2012, an approved bankruptcy plan of reorganization of the borrower became effective establishing a principal amount of $33,900,000 maturing in April 2017. Interest accrues at nine percent the first three years escalating to ten percent in April 2015 and 12 percent in April 2016, with interest above 6.25 percent to be forgiven if the loan is prepaid by certain dates. Commencing with the reorganization, we estimated future cash flows and calculated accretable yield to be recognized over the term of the loan, which is included in other non-operating income. In 2014 and 2013, we received principal payments of $11,304,000 and $14,315,000 and interest payments of $634,000 and $1,872,000. At year-end 2014, the outstanding principal balance was $4,394,000.
	Estimated accretable yield is as follows:
		At Year-End
		2014			2013
		(In thousands)
	Beginning of year	$	8,908		$	25,149
	Change in accretable yield due to change in timing of estimated cash flows	(166		)	(10,950		)
	Interest income recognized	(7,903		)	(5,291		)
		$	839		$	8,908
	Other loans secured by real estate generally are secured by a deed of trust and due within three years. The decrease in 2014 is principally associated with the sale of 33 commercial tract acres from our Cibolo Canyons project in San Antonio, Texas for $7,700,000 in which we seller-financed $6,160,000 at an interest rate of prime plus one percent. The buyer was unable to meet the terms of the financing and we foreclosed on the property. The remaining loans secured by real estate at year-end 2014 principally consist of $824,000 related to a real estate contract for a project in Colorado and $550,000 related to a real estate contract for a project in Los Angeles.

Debt

Debt	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Debt	Debt
	Debt consists of:
		At Year-End
		2014		2013
		(In thousands)
	Senior secured credit facility
	Term loan facility — average interest rate of 4.17% at year-end 2013	$	—	$	200,000
	8.50% senior secured notes due 2022	250,000		—
	3.75% convertible senior notes due 2020, net of discount	103,194		99,890
	6.00% tangible equity units, net of discount	17,154		25,619
	Secured promissory notes — average interest rates of 3.17% at year-end 2014 and 2013	15,400		15,400
	Other indebtedness due through 2017 at variable and fixed interest rates ranging from 2.19% to 5.00%	46,996		16,498
		$	432,744	$	357,407
	In 2014, we amended our senior secured credit facility in order to consolidate previous amendments and to effect the following:
	•increase the revolving loan commitment from 200,000,000 to 300,000,000;
	•extend the maturity date to May 15, 2017 (with two one-year extension options);
	•increase the minimum interest coverage ratio from 1.50x to 2.50x;
	•eliminate the collateral value to loan commitment ratio covenant; and
	•increase the maximum total leverage ratio from 40% to 50%.
	We incurred fees of $3,068,000 related to this amendment. At year-end 2014, our senior secured credit facility provides for a $300,000,000 revolving line of credit maturing May 15, 2017. The term loan and 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 $15,415,000 is outstanding at year-end 2014. 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 2014, we had $284,585,000 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. At year-end 2014, we were in compliance with the financial covenants of these agreements. In addition, we may elect to make distributions so long as the total leverage ratio is less than 40 percent, the interest coverage is greater than 3.0:1.0, and available liquidity is not less than $125,000,000. At year-end 2014, we satisfied all of the above conditions.
	On May 12, 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. We incurred debt issuance costs of approximately $8,053,000, including the underwriters discount of $6,250,000. Notes are secured by a second lien on the same collateral pledged under our credit facility. Net proceeds from issuance of the Notes were used to repay our $200,000,000 senior secured term loan. We intend to use the remaining amount for general corporate purposes, which may include investments in strategic growth opportunities.
	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 2014, unamortized debt discount of our Convertible Notes was $21,806,000.
	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 2014, secured promissory notes include a $15,400,000 loan collateralized by a 413 guest room hotel located in Austin with a carrying value of $30,712,000.
	At year-end 2014, other indebtedness principally represents senior secured construction loans for two multifamily properties, of which $23,936,000 is related to the 2014 acquisition of our partner's interest in a 257-unit multifamily project in Austin and $19,117,000 is related to our 354-unit multifamily property in Dallas. The combined carrying value of these two multifamily properties is $86,444,000 at year-end 2014.
	At year-end 2014 and 2013, we have $15,168,000 and $7,896,000 in unamortized deferred fees which are included in other assets. Amortization of deferred financing fees was $3,845,000 in 2014, $3,050,000 in 2013 and $2,922,000 in 2012 and is included in interest expense.
	Debt maturities during the next five years are: 2015 — $49,535,000; 2016 — $29,031,000; 2017 — $984,000; 2018 — $0; 2019 — $0 and thereafter — $353,194,000.

Fair_Value

Fair Value	12 Months Ended
	Dec. 31, 2014
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.
	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.
	Proved oil and gas properties are evaluated for impairment when facts and circumstances indicate that their carrying amounts may not be recoverable. If projected undiscounted future net cash flows are less than the carrying value of the property, an impairment loss is recognized for the excess of the carrying amount over estimated fair value. Future net cash flows are based on future sales prices of oil and gas, future development and production costs, future reserves to be recovered and timing of production. We used Level 3 inputs and the income valuation method to estimate the fair value of proved oil and gas properties where the carrying amount exceeded the estimated undiscounted cash flows. We used a discount rate of 10 percent as of year-end 2014 which is commensurate with our risk and current market conditions associated with realizing the expected cash flows projected. As a result, we recorded proved property non-cash impairment charges of $15,535,000 in 2014.
	In 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 $399,000 in 2014 associated with two owned entitled projects. We had $1,790,000 non-cash impairment charges in 2013 associated with a master-planned community and golf club near Dallas.
		Year-End 2014												Year-End 2013
		Level 1			Level 2			Level 3			Total			Level 1		Level 2		Level 3		Total
		(In thousands)
	Non-Financial Assets and Liabilities:
	Real estate	$	—		$	970		$	—		$	970		$	—	$	3,700	$	—	$	3,700
	Proved oil and gas properties	$	—		$	—		$	3,655		$	3,655		$	—	$	—	$	—	$	—
	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 2014						Year-End 2013
		Carrying			Fair			Carrying			Fair			Valuation
		Amount			Value			Amount			Value			Technique
		(In thousands)
	Loan secured by real estate	$	3,574		$	4,859		$	7,610		$	18,025		Level 2
	Fixed rate debt(a)	$	(370,348	)	$	(359,131	)	$	(126,640	)	$	(118,634	)	Level 2
	_____________________
	(a)	Year-end 2014 includes our $250,000,000 of 8.50% senior secured notes due 2022, issued May 12, 2014.

Capital_Stock

Capital Stock	12 Months Ended
	Dec. 31, 2014
Equity [Abstract]
Capital Stock	Capital Stock
	Pursuant to our shareholder rights plan, each share of common stock outstanding is coupled with one-quarter of a preferred stock purchase right (Right). Each Right entitles our shareholders to purchase, under certain conditions, one one-hundredth of a share of newly issued Series A Junior Participating Preferred Stock at an exercise price of $100. Rights will be exercisable only if someone acquires beneficial ownership of 20 percent or more of our common shares or commences a tender or exchange offer, upon consummation of which they would beneficially own 20 percent or more of our common shares. We will generally be entitled to redeem the Rights at $0.001 per Right at any time until the 10th business day following public announcement that a 20 percent position has been acquired. The Rights will expire on December 11, 2017.
	Please read Note 8 — Debt and Note 11 — Net Income 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 Compensation for information about additional shares of common stock that could be issued under terms of our share-based compensation plans.
	At year-end 2014, personnel of former affiliates held options to purchase 705,000 shares of our common stock. The options have a weighted average exercise price of $26.15 and a weighted average remaining contractual term of one year. At year-end 2014, the options have an aggregate intrinsic value of $30,000.
	In 2014, we repurchased 1,491,187 shares of our common stock for $24,595,000. In 2013, we did not repurchase shares of our common stock. 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, 2014
Earnings Per Share [Abstract]
Net Income per Share	Net Income per Share
	Basic and diluted earnings per share is 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 per share are as follows:
		For the Year
		2014			2013			2012
		(In thousands)
	Numerator:
	Consolidated net income	$	17,088		$	35,061		$	17,876
	Less: Net income attributable to noncontrolling interest	(505		)	(5,740		)	(4,934		)
	Earnings available for diluted earnings per share	$	16,583		$	29,321		$	12,942
	Less: Undistributed net income allocated to participating securities	(3,018		)	(585		)	—
	Earnings available to common shareholders for basic earnings per share	$	13,565		$	28,736		$	12,942
	Denominator:
	Weighted average common shares outstanding — basic	35,317			35,365			35,214
	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			268
	Total weighted average shares outstanding — diluted	43,596			36,813			35,482
	Anti-dilutive awards excluded from diluted weighted average shares outstanding	2,238			1,803			2,713
	_____________________
	(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 November 27, 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 2014 did not exceed the conversion price which resulted in no additional diluted outstanding shares.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes
	Income tax expense consists of:
		For the Year
		2014				2013				2012
		(In thousands)
	Current tax provision:
	U.S. Federal	$	(5,444	)		$	(6,004	)		$	(11,834	)
	State and other	(1,569		)		(2,066		)		(2,171		)
		(7,013		)		(8,070		)		(14,005		)
	Deferred tax provision:
	U.S. Federal	(2,772		)		1,148				4,910
	State and other	1,128				(286		)		1,079
		(1,644		)		862				5,989
	Income tax expense	$	(8,657	)		$	(7,208	)		$	(8,016	)
	A reconciliation of the federal statutory rate to the effective income tax rate on continuing operations follows:
		For the Year
		2014			2013			2012
	Federal statutory rate	35	%		35	%		35	%
	State, net of federal benefit	1			4			5
	Recognition of previously unrecognized tax benefits	—			(15	)		—
	State rate change due to acquisition	—			—			(2	)
	Acquisition costs	—			—			4
	Noncontrolling interests	—			(5	)		(7	)
	Goodwill	1			—			—
	Charitable contributions	(1	)		—			—
	Oil and gas percentage depletion	(2	)		(2	)		(5	)
	Other	—			—			1
	Effective tax rate	34	%		17	%		31	%
	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. Our 2012 effective tax rate includes a two percent non-cash benefit associated with state deferred tax rate changes due to our acquisition of Credo and operating in additional states.
	Significant components of deferred taxes are:
		At Year-End
		2014				2013
		(In thousands)
	Deferred Tax Assets:
	Real estate	$	79,244			$	75,157
	Employee benefits	17,352				17,902
	Net operating loss carryforwards	3,012				3,076
	Income producing properties	364				3,529
	Oil and gas percentage depletion carryforwards	3,471				3,344
	Accruals not deductible until paid	1,111				960
	Gross deferred tax assets	104,554				103,968
	Valuation allowance	(384		)		(375		)
	Deferred tax asset net of valuation allowance	104,170				103,593
	Deferred Tax Liabilities:
	Oil and gas properties	(49,905		)		(46,966		)
	Undeveloped land	(4,937		)		(5,961		)
	Convertible debt	(7,816		)		(8,803		)
	Timber	(888		)		(1,465		)
	Gross deferred tax liabilities	(63,546		)		(63,195		)
	Net Deferred Tax Asset	$	40,624			$	40,398
	At year-end 2014, we had federal net operating loss carryforwards of approximately $7,500,000 as a result of our acquisition of Credo in 2012, and we had approximately $18,000,000 of state net operating loss carryforwards. These are subject to certain limitations. If not utilized, these carryforwards will expire in 2031 for federal purposes and 2015 to 2034 for state purposes. We had approximately $9,200,000 of oil and gas percentage depletion carryforwards that also were a result of our acquisition of Credo. These carryforwards are subject to certain limitations but do not expire.
	At year-end 2014 and 2013, we have not provided a valuation allowance for our federal deferred tax asset because we believe it is likely it will be recoverable in future periods. We have provided a valuation allowance for some of our state net operating loss carryforwards. The change in our state valuation allowance for the year was $9,000. Our deferred tax liability on oil and gas properties includes purchase accounting amounts for the excess of fair value allocated to Credo oil and gas properties over the carryover tax basis received. Goodwill associated with our acquisition of Credo is not deductible for income tax purposes.
	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 2011 and state examinations for years before 2010.
	A reconciliation of the beginning and ending amount of tax benefits not recognized for book purposes is as follows:
		At Year-End
		2014				2013				2012
		(In thousands)
	Balance at beginning of year	$	—			$	5,831			$	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	$	—			$	—			$	5,831
	We recognize interest accrued related to unrecognized tax benefits in income tax expense. In 2014, 2013 and 2012, we recognized approximately $0, $75,000 and $152,000 in interest expense. At year-end 2014 and 2013, we have no accrued interest or penalties.

Litigation_and_Environmental_C

Litigation and Environmental Contingencies	12 Months Ended
	Dec. 31, 2014
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.
	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. We estimate the remaining cost to complete remediation activities will be approximately $529,000, 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 and comprehensive income. At year-end 2014, our asset retirement obligation was $1,807,000, which is included in other liabilities.

Commitments_and_Other_Continge

Commitments and Other Contingencies	12 Months Ended
	Dec. 31, 2014
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 $2,617,000 in 2014, $2,374,000 in 2013 and $2,115,000 in 2012. Future minimum rental commitments under non-cancelable operating leases having a remaining term in excess of one year are: 2015 — $3,308,000; 2016 — $3,111,000; 2017 — $3,101,000; 2018 — $2,165,000; 2019 — $571,000 and thereafter —$2,284,000.
	We have three years remaining on groundwater leases of about 20,000 acres. At year-end 2014, the remaining contractual obligation for these groundwater leases is $1,514,000.
	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 $5,632,000. We also lease office space in several other locations in support of our business operations with approximately 21,000 and 10,000 square feet in Ft. Worth, Texas and Denver, Colorado. The total remaining contractual obligations for these leases is $6,262,000.
	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.

Segment_Information

Segment Information	12 Months Ended
	Dec. 31, 2014
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 investments. 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 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 2014, 2013 and 2012, no single customer accounted for more than 10 percent of our total revenues.
		Real			Oil and Gas			Other Natural			Items Not				Total
		Estate						Resources			Allocated to
											Segments
		(In thousands)
	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 (loss) 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 (loss) 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
	For the year or at year-end 2012
	Revenues	$	120,115		$	44,220		$	8,256		$	—			$	172,591
	Depreciation, depletion and amortization	4,340			4,987			1,254			8,345				18,926
	Equity in earnings of unconsolidated ventures	13,897			509			63			—				14,469
	Income (loss) before taxes	53,582			26,608			29			(59,261		)	(a)	20,958
	Total assets	588,137			227,061			24,066			79,170				918,434
	Investment in unconsolidated ventures	41,546			—			—			—				41,546
	Capital expenditures(b)	1,093			21,971			292			795				24,151
	_____________________
	(a)	Items not allocated to segments consist of:
		For the Year
		2014			2013			2012
		(In thousands)
	General and administrative expense	$	(21,229	)	$	(20,597	)	$	(25,176	)
	Share-based compensation expense	(3,417		)	(16,809		)	(14,929		)
	Gain on sale of assets	—			—			16
	Interest expense	(30,286		)	(20,004		)	(19,363		)
	Other corporate non-operating income	453			119			191
		$	(54,479	)	$	(57,291	)	$	(59,261	)
	(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, 2014
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.
	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 variable interest entities (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.
	At year-end 2014, we have four 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 2014, these VIEs have total assets of $64,311,000, substantially all of which represent developed and undeveloped real estate and total liabilities of $79,723,000, which includes $30,667,000 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 2014, our investment is $9,500,000 and is included in investment in unconsolidated ventures. In 2014, we contributed $4,415,000 to these VIEs. Our maximum exposure to loss related to these VIEs is estimated at $3,597,000, 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.

ShareBased_Compensation

Share-Based Compensation	12 Months Ended
	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share-Based Compensation	Share-Based Compensation
	Share-based compensation expense consists of:
		For the Year
		2014				2013				2012
		(In thousands)
	Cash-settled awards	$	(3,710	)		$	7,774			$	6,465
	Equity-settled awards	5,168				4,281				3,059
	Restricted stock	(25		)		538				2,154
	Stock options	1,984				4,216				3,251
		$	3,417			$	16,809			$	14,929
	Share-based compensation expense is included in:
		For the Year
		2014				2013				2012
		(In thousands)
	General and administrative	$	1,001			$	7,779			$	7,144
	Other operating	2,416				9,030				7,785
		$	3,417			$	16,809			$	14,929
	In 2014, share-based compensation expense decreased principally as a result of a decrease in our stock price and its impact on cash-settled awards as well as forfeiture of awards due to employee separations.
	The fair value of awards granted to retirement-eligible employees and expensed at the date of grant was $760,000 in 2014, $590,000 in 2013 and $595,000 in 2012. Unrecognized share-based compensation expense related to non-vested equity-settled awards, restricted stock and stock options is $7,160,000 at year-end 2014. 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 2014, 2013 or 2012.
	In 2014 and 2013, we issued 215,561 and 137,943 shares out of our treasury stock associated with vesting of stock-based awards or exercises of stock options. These shares are net of 55,238 and 59,219 shares withheld for payroll taxes having a value of $1,043,000 and $1,137,000 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 2014:
		Equivalent			Weighted Average Grant Date Fair Value
		Units
		(In thousands)			(Per unit)
	Non-vested at beginning of period	233			$17.90
	Granted	93			18.96
	Vested	(132	)		17.86
	Forfeited	(9	)		17.42
	Non-vested at end of period	185			18.49
	The weighted average grant date fair value of our non-vested cash-settled restricted stock unit awards at year-end 2012 was $17.03 for 350,000 equivalent units.
	The following table summarizes the activity of cash-settled stock appreciation rights in 2014:
		Rights			Weighted Average		Weighted Average		Aggregate Intrinsic Value
		Outstanding			Exercise Price		Remaining Contractual Term		(Current Value Less Exercise Price)
		(In thousands)			(Per share)		(In years)		(In thousands)
	Balance at beginning of period	580			$11.96		5		$5,400
	Granted	—			—
	Exercised	(116	)		9.41
	Forfeited	(6	)		17.8
	Balance at end of period	458			12.54		4		1,732
	Exercisable at end of period	458			12.54		4		1,732
	The weighted average exercise price of our cash-settled stock appreciation rights at year-end 2012 was $11.38 for 866,000 awards.
	The fair value of awards settled in cash was $3,467,000 in 2014, $7,237,000 in 2013 and $5,299,000 in 2012. At year-end 2014, the fair value of accrued cash-settled awards is $9,560,000 and is included in other liabilities. The aggregate current value of non-vested awards is $2,850,000 at year-end 2014 based on a year-end stock price of $15.40.
	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 2014:
		Equivalent			Weighted Average Grant Date Fair Value
		Units
		(In thousands)			(Per unit)
	Non-vested at beginning of period	581			$	19.5
	Granted	512			19.18
	Vested	(259	)		20.01
	Forfeited	(124	)		18.58
	Non-vested at end of period	710			19.24
	In 2014, we granted 270,000 PSU awards to be settled in common stock upon achievement of the performance goal over the measurement period of three years. The number of shares to be issued could range from a high of 540,000 shares to a low of no shares issued based upon performance.
	In 2014, we granted 86,000 MSU awards. These awards will be settled in common stock based upon our stock price performance over three years from the date of grant. The number of shares to be issued could range from a high of 129,000 shares if our stock price increases by 50 percent or more, to 43,000 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. MSU awards are valued using a Monte Carlo simulation pricing model, which includes expected stock price volatility and risk-free interest rate assumptions. Compensation expense is recognized regardless of achievement of performance conditions, provided the requisite service period is satisfied.
	The weighted average grant date fair value of our non-vested equity-settled awards at year-end 2012 was $18.99 for 409,000 non-vested restricted shares.
	Unrecognized share-based compensation expense related to non-vested equity-settled awards is $5,975,000 at year-end 2014. The weighted average period over which this amount will be recognized is estimated to be two years.
	Restricted stock
	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 2014:
		Restricted			Weighted Average Grant Date Fair Value
		Shares
	(In thousands)			(Per unit)
Non-vested at beginning of period	47			$	14.99
Granted	—			—
Vested	(20	)		12.74
Forfeited	(10	)		15.02
Non-vested at end of period	17			17.56
The weighted average grant date fair value of our non-vested restricted stock awards at year-end 2012 was $16.95 for 211,000 non-vested restricted shares.
Unrecognized share-based compensation expense related to non-vested restricted stock awards is $138,000 at year-end 2014. 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. Options were granted with an exercise price equal to the market value of our stock on the date of grant. The following table summarizes the activity of stock option awards in 2014:
	Options			Weighted				Weighted		Aggregate
	Outstanding			Average				Average		Intrinsic Value
				Exercise Price				Remaining		(Current
								Contractual		Value Less
								Term		Exercise Price)
	(In thousands)			(Per share)				(In years)		(In thousands)
Balance at beginning of period	2,006			$	20.3			7		$	6,433
Granted	—			—
Exercised	(56	)		9.64
Forfeited	(89	)		17.65
Balance at end of period	1,861			20.74				6		643
Exercisable at end of period	1,364			21.86				5		620
We estimate the grant date fair value of stock options using the Black-Scholes option pricing model and the following assumptions:
		For the Year
		2013				2012
Expected stock price volatility		66.8		%		60.2		%
Risk-free interest rate		1.4		%		1.3		%
Expected life of options (years)		6				6
Expected dividend yield		—		%		—		%
Weighted average estimated fair value of options at grant date		$	11.47			$	9.22
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.
The fair value of vested stock options was $21,000 in 2014, $1,355,000 in 2013 and $429,000 in 2012. The intrinsic value of options exercised was $568,000 in 2014 and $562,000 in 2013. There were no options exercised in 2012. Unrecognized share-based compensation expense related to non-vested stock options is $1,047,000 at year-end 2014. 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. As a result of Temple-Inland’s merger with International Paper in first quarter 2012, all outstanding awards on Temple-Inland stock were settled with an intrinsic value of $1,132,000.
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 2014, there were 56,000 pre-spin awards outstanding and exercisable on our stock with a weighted average exercise price of $27.03 and weighted average remaining term of one year.

Retirement_Plans

Retirement Plans	12 Months Ended
	Dec. 31, 2014
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 $1,651,000 in 2014, $1,456,000 in 2013 and $1,393,000 in 2012. The unfunded liability for our supplemental plan was $715,000 at year-end 2014 and $586,000 at year-end 2013 and is included in other liabilities.

Supplemental_Oil_and_Gas_Discl

Supplemental Oil and Gas Disclosures (Unaudited)	12 Months Ended
	Dec. 31, 2014
Extractive Industries [Abstract]
Supplemental Oil and Natural 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.
	In 2012, we acquired 100 percent of the outstanding common stock of Credo in an all cash transaction for $14.50 per share, representing an equity purchase price of approximately $146,445,000. In addition, we paid in full $8,770,000 of Credo’s outstanding debt. Credo was an independent oil and gas exploration, development and production company based in Denver, Colorado. The acquired assets included leasehold interests in the Bakken and Three Forks formations of North Dakota, the Lansing – Kansas City formation in Kansas and Nebraska, and the Tonkawa and Cleveland formations in Texas.
	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 2014, 2013 and 2012.
	These estimates were based on the economic and operating conditions existing at year-end 2014, 2013 and 2012. 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 2014, 2013 and 2012, the average spot price per barrel of oil based on the West Texas Intermediate Crude price is $94.99, $96.91 and $94.71 and the average price per MMBTU of gas based on the Henry Hub spot market is $4.35, $3.67 and $2.76. 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)			Gas
		(Barrels)			(Mcf)
		(In thousands)
	Consolidated entities:
	Year-end 2011	1,064			8,203
	Revisions of previous estimates	45			(2,163	)
	Extensions and discoveries	86			241
	Acquisitions	2,396			7,109
	Production	(371	)		(1,668	)
	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
	Our share of ventures accounted for using the equity method:
	Year-end 2011	—			3,283
	Revisions of previous estimates	—			(390	)
	Production	—			(321	)
	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
	Total consolidated and our share of equity method ventures:
	Year-end 2012
	Proved developed reserves	2,416			13,020
	Proved undeveloped reserves	804			1,274
	Total Year-end 2012	3,220			14,294
	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
	_____________________
	(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 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 2012, decreases in gas prices accounted for about 800,000 Mcf of downward revisions in gas reserves for our consolidated entities and about 330,000 Mcf of downward revisions for our equity method ventures. The remaining downward revisions in gas reserves for our consolidated entities were attributable to adverse performance from reducing the total fluid withdrawal rate in a natural water drive reservoir, adverse performance from increasing total fluid withdrawal rate in another natural water drive reservoir, from unfavorable performance from newer wells in over-pressured reservoirs that are exhibiting pressure-dependent permeability reductions, and generally due to higher operating pressures adversely affecting gas well performances in a higher back-pressure environment.
	In 2014, 2013 and 2012, 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 for the royalty interest wells and in 2012 with the acquisition of Credo, working interest wells apply industry practices for new well classifications. There were 106 new well additions in 2014, 88 new well additions in 2013 and 27 new well additions in 2012.
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
	2014				2013
	(In thousands)
Consolidated entities:
Unproved oil and gas properties	$	90,446			$	100,320
Proved oil and gas properties	221,299				155,262
Total costs	311,745				255,582
Less accumulated depreciation, depletion and amortization	(48,252		)		(22,941		)
	$	263,493			$	232,641
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
	2014				2013			2012
	(In thousands)
Consolidated entities:
Acquisition costs:
Proved properties	$	2,001			$	—		$	—
Unproved properties	25,666				35,806			4,418
Exploration costs	39,399				10,486			1,752
Development costs	40,277				54,538			15,938
	$	107,343			$	100,830		$	22,108
We have not incurred any costs for our share in ventures accounted for using the equity method. In 2014 and 2013, acquisition of leasehold interests, exploration expenses, and development costs have increased as a result of our increased focus to increase production, reserves, and also to explore and develop the assets acquired from Credo.
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
	2014				2013			2012
	(In thousands)
Consolidated entities:
Future cash inflows	$	665,657			$	544,098		$	322,098
Future production and development costs	(271,735		)		(231,801		)	(104,441		)
Future income tax expenses	(106,002		)		(77,361		)	(50,350		)
Future net cash flows	287,920				234,936			167,307
10% annual discount for estimated timing of cash flows	(124,079		)		(99,383		)	(60,764		)
Standardized measure of discounted future net cash flows	$	163,841			$	135,553		$	106,543
Our share in ventures accounted for using the equity method:
Future cash inflows	$	6,186			$	4,765		$	5,125
Future production and development costs	(664		)		(512		)	(551		)
Future income tax expenses	(2,098		)		(1,616		)	(1,738		)
Future net cash flows	3,424				2,637			2,836
10% annual discount for estimated timing of cash flows	(1,649		)		(1,337		)	(1,423		)
Standardized measure of discounted future net cash flows	$	1,775			$	1,300		$	1,413
Total consolidated and our share of equity method ventures	$	165,616			$	136,853		$	107,956
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			Total
					Method Ventures
	(In thousands)
Year-end 2011	$	52,698			$	3,508		$	56,206
Changes resulting from:
Net change in sales prices and production costs	(5,709		)		(2,497		)	(8,206		)
Net change in future development costs	(1,834		)		—			(1,834		)
Sales of oil and gas, net of production costs	(31,732		)		(632		)	(32,364		)
Net change due to extensions and discoveries	5,596				—			5,596
Net change due to acquisition of reserves	86,013				—			86,013
Net change due to revisions of quantity estimates	(2,254		)		18			(2,236		)
Previously estimated development costs incurred	1,007				—			1,007
Accretion of discount	7,377				401			7,778
Net change in income taxes	(4,619		)		615			(4,004		)
Aggregate change for the year	53,845				(2,095		)	51,750
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
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, 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
	2014				2013			2012
	(In thousands)
Consolidated entities(a)
Revenues	$	82,919			$	69,036		$	36,204
Production costs	(19,727		)		(12,477		)	(4,472		)
Exploration costs	(17,416		)		(10,486		)	(1,754		)
Depreciation, depletion, amortization	(29,442		)		(19,552		)	(4,905		)
Non-cash impairments	(32,665		)		(473		)	—
Oil and gas administrative expenses	(17,000		)		(14,407		)	(8,332		)
Accretion expense	(121		)		(94		)	(26		)
Income tax expenses	13,398				(3,471		)	(4,841		)
Results of operations	(20,054		)		8,076			11,874
Our share in ventures accounted for using the equity method:
Revenues	$	786			$	801		$	770
Production costs	(105		)		(123		)	(138		)
Oil and gas administrative expenses	(95		)		(86		)	(123		)
Income tax expenses	(235		)		(178		)	(147		)
Results of operations	$	351			$	414		$	362
Total results of operations	$	(19,703	)		$	8,490		$	12,236
_____________________
(a)	2012 includes only three months of operations from Credo due to our third quarter 2012 acquisition.
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_o

Summary of Quarterly Results of Operations (Unaudited)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Summary of Quarterly Results of Operations (Unaudited)	Summary of Quarterly Results of Operations (Unaudited)
	Summarized quarterly financial results for 2014 and 2013 follows:
		First		Second		Third		Fourth
		Quarter		Quarter		Quarter		Quarter(a)
		(In thousands, except per share amounts)
	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	$	0.2	$	0.34	$	0.12	$	(0.34	)
	Net income (loss) per share — diluted	$	0.19	$	0.34	$	0.12	$	(0.34	)
	2013
	Total revenues	$	97,471	$	60,079	$	75,107	$	98,388
	Gross profit	35,899		22,463		32,608		39,181
	Operating income	9,520		3,554		10,612		22,891
	Equity in earnings of unconsolidated ventures	913		2,566		3,125		2,133
	Income before taxes	7,035		2,109		9,965		23,160
	Net income attributable to Forestar Group Inc.	3,951		541		11,830		12,999
	Net income per share — basic	$	0.11	$	0.02	$	0.33	$	0.34
	Net income per share — diluted	$	0.11	$	0.02	$	0.33	$	0.33
	_____________________
	(a)	Fourth quarter 2014 results include pre-tax non-cash impairment charges of $30,591,000 for unproved leasehold interests and proved oil and gas properties.

Consolidated_Real_Estate_and_A

Consolidated Real Estate and Accumulated Depreciation	12 Months Ended
	Dec. 31, 2014
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 2014
	(In thousands)
						Initial Cost to						Costs Capitalized								Gross Amount Carried at End of Period
						Company						Subsequent to Acquisition
	Description	Encumbrances				Land				Buildings &		Improvements				Carrying				Land & Land				Buildings &	Total		Accumulated		Date of	Date
										Improvements		less Cost of				Costs(a)				Improvements				Improvements			Depreciation		Construction	Acquired
												Sales and Other
	Entitled, Developed, and Under Development Projects:
	CALIFORNIA
	Contra Costa County
	San Joaquin River					$	12,225					$	(3,310	)						$	8,915				$	8,915				(b)
	COLORADO
	Douglas County
	Pinery West					7,308						7,045								14,353					14,353				2006	2006
	Weld County
	Buffalo Highlands					3,001						555								3,556					3,556				2006	2005
	Johnstown Farms					2,749						2,046				$	188			4,983					4,983				2002	2002
	Stonebraker					3,878						(1,436		)						2,442					2,442				2005	2005
	GEORGIA
	Cherokee County
	Heron Pond					1,104						1,285								2,389					2,389					2012
	Coweta County
	Corinth Landing					607						585								1,192					1,192					(b)
	Coweta South Industrial Park					532						476								1,008					1,008					(b)
	Genesee					480						1,176								1,656					1,656					(b)
	Dawson County
	Woodlands at Burt Creek					71						1,670								1,741					1,741					(b)
	Paulding County
	Seven Hills					2,964						129								3,093					3,093					2012
	SOUTH CAROLINA
	York County
	Habersham					3,877						1,478				239				5,594					5,594					2013
	TENNESEE
	Williamson County
	Morgan Farms					6,841						917				166				7,924					7,924					2013
	Weatherford Estates					856						201								1,057					1,057					2014
	Wilson County
	Beckwith Crossing					1,294						185								1,479					1,479					2014
	TEXAS
	Bastrop County
	Hunter’s Crossing					3,613						6,465				358				10,436					10,436				2001	2001
	The Colony					8,726						12,347				161				21,234					21,234				1999	1999
	Bexar County
	Cibolo Canyons					25,569						26,137				1,607				53,313					53,313				2004	1986
	Calhoun County
	Caracol	$	3,869			8,603						3,355				2,047				14,005					14,005				2006	2006
						Initial Cost to								Costs Capitalized								Gross Amount Carried at End of Period
						Company								Subsequent to Acquisition
	Description	Encumbrances				Land				Buildings &				Improvements				Carrying				Land & Land			Buildings &		Total			Accumulated			Date of	Date
										Improvements				less Cost of				Costs(a)				Improvements			Improvements					Depreciation			Construction	Acquired
														Sales and Other
	Collin County
	Lakes of Prosper					$	8,951							$	(634	)		$	180			$	8,497				$	8,497						2012
	Maxwell Creek					9,904								(8,687		)		635				1,852					1,852						2000	2000
	Parkside					2,177								1,294								3,471					3,471							2013
	Timber Creek					7,282								4,386								11,668					11,668						2007	2007
	Village Park					6,550								(6,579		)		81				52					52							2012
	Comal County
	Oak Creek Estates					1,921								941				175				3,037					3,037						2006	2005
	Dallas County
	Stoney Creek					12,822								1,278				49				14,149					14,149						2007	2007
	Denton County
Lantana					27,673								(825		)						26,848					26,848						2000	1999
River's Edge					1,227								351								1,578					1,578							2014
The Preserve at Pecan Creek					5,855								(1,884		)		436				4,407					4,407						2006	2005
Fort Bend County
Summer Lakes					4,269								(169		)						4,100					4,100							2012
Summer Park					4,804								3								4,807					4,807							2012
Willow Creek Farms					3,479								358				90				3,927					3,927							2012
Harris County
Barrington					8,950								(5,833		)						3,117					3,117							2011
City Park	$	74			3,946								(1,485		)		1,641				4,102					4,102						2002	2001
Imperial Forest					5,345								47								5,392					5,392							2014
Hays County
Arrowhead Ranch					12,856								3,104								15,960					15,960							2007
Hood County
Harbor Lakes					3,514								(1,970		)		312				1,856					1,856						2000	1998
Montgomery County
Woodtrace					8,622								(8,621		)						1					1							2014
Nueces County
Tortuga Dunes					12,080								9,473								21,553					21,553							2006
Tarrant County
Summer Creek Ranch					2,887								(1,625		)						1,262					1,262							2012
The Bar C Ranch					1,365								2,330				32				3,727					3,727							2012
Williamson County
La Conterra					4,024								(2,790		)		293				1,527					1,527							2006
MISSOURI
Clay County
Somerbrook					3,061								(218		)		13				2,856					2,856						2003	2001
Other					32,304								(22,418		)		1,271				11,157					11,157
Total Entitled, Developed, and Under Development Projects	$	3,943			$	290,166			$	—			$	21,133			$	9,974			$	321,273		$	—	$	321,273		$	—
					Initial Cost to								Costs Capitalized								Gross Amount Carried at End of Period
					Company								Subsequent to Acquisition
Description	Encumbrances				Land				Buildings &				Improvements				Carrying				Land & Land			Buildings &		Total			Accumulated			Date of	Date
									Improvements				less Cost of				Costs(a)				Improvements			Improvements					Depreciation			Construction	Acquired
													Sales and Other
Undeveloped Land and Land in Entitlement:
CALIFORNIA
Los Angeles County
Land In Entitlement Process					$	3,969							$	18,122							$	22,091				$	22,091						1997
GEORGIA
Bartow County
Undeveloped Land					3,551								48								3,599					3,599							(b)
Carroll County
Undeveloped Land					4,397								107								4,504					4,504							(b)
Land In Entitlement Process					9,006								2,159								11,165					11,165							(b)
Cherokee County
Undeveloped Land					3,322								92								3,414					3,414							(b)
Land In Entitlement Process					2,340								566								2,906					2,906							(b)
Coweta County
Undeveloped Land					454								380								834					834							(b)
Land In Entitlement Process					644								222								866					866							(b)
Dawson County
Undeveloped Land					2,157								1,485								3,642					3,642							(b)
Gilmer County
Undeveloped Land					2,748								26								2,774					2,774							(b)
Lumpkin County
Undeveloped Land					3,015								4								3,019					3,019							(b)
Paulding County
Undeveloped Land					7,494																7,494					7,494							(b)
Pickens County
Undeveloped Land					2,235								28								2,263					2,263							(b)
Polk County
Undeveloped Land					2,354																2,354					2,354							(b)
TEXAS
Bexar County
Undeveloped Land													3,038								3,038					3,038							(b)
Harris County
Land in Entitlement Process					685								1,145								1,830					1,830							(b)
Other
Undeveloped Land					8,666								8,171								16,837					16,837							(b)
Land in Entitlement Process					504								48								552					552							(b)
Total Undeveloped Land and Land in Entitlement	$	—			$	57,541			$	—			$	35,641			$	—			$	93,182		$	—	$	93,182		$	—
					Initial Cost to								Costs Capitalized								Gross Amount Carried at End of Period
					Company								Subsequent to Acquisition
Description	Encumbrances				Land				Buildings &				Improvements				Carrying				Land & Land			Buildings &		Total			Accumulated			Date of	Date
									Improvements				less Cost of				Costs(a)				Improvements			Improvements					Depreciation			Construction	Acquired
													Sales and
													Other
Income Producing Properties:
NORTH CAROLINA
Mecklenburg County
Dilworth					$	5,779							$	9,424							$	15,203				$	15,203						2012
TENNESSEE
Davidson County
Music Row					6,607								1,068								7,675					7,675							2014
TEXAS
Dallas County
Midtown	$	19,117			2,526								30,767								2,526			30,767		33,293			$	(231	)	2011	2011
Hood County
Harbor Lakes Golf Club									1,446				608											2,054		2,054			(1,508		)	2000	1998
Travis County
Eleven	23,936				7,940				$	45,947			71								7,940			46,018		53,958			(576		)	2013	2014
Downtown Edge					11,202								654								11,856					11,856							2014
Radisson Hotel & Suites	15,400								10,603				49,170								—			59,773		59,773			(29,062		)		(b)
West Austin					7,274								1,592								8,866					8,866							2014
Total Income Producing Properties	$	58,453			$	41,328			$	57,996			$	93,354			$	—			$	54,066		$	138,612	$	192,678		$	(31,377	)
Total	$	62,396			$	389,035			$	57,996			$	150,128			$	9,974			$	468,521		$	138,612	$	607,133		$	(31,377	)
_____________________
(a)	We do not capitalize carrying costs until development begins.
(b)	The acquisition date is not available.
Reconciliation of real estate:
		2014				2013				2012
		(In thousands)
Balance at beginning of year		$	547,530			$	545,370			$	592,322
Amounts capitalized		214,184				111,428				143,711
Amounts retired or adjusted		(154,581		)		(109,268		)		(190,663		)
Balance at close of period		$	607,133			$	547,530			$	545,370
Reconciliation of accumulated depreciation:
		2014				2013				2012
		(In thousands)
Balance at beginning of year		$	(28,066	)		$	(28,220	)		$	(26,955	)
Depreciation expense		(3,319		)		(2,185		)		(3,640		)
Amounts retired or adjusted		8				2,339				2,375
Balance at close of period		$	(31,377	)		$	(28,066	)		$	(28,220	)

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
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 2014 and 2013, restricted cash was $217,000 and $3,954,000 and is included in other assets.
Cash Flows	Cash Flows
	Expenditures for the acquisition and development of single-family and multifamily real estate are classified as operating activities. Expenditures for the acquisition of stabilized income producing properties, 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 2014 and 2013 were $19,405,000 and $12,976,000 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 $1,188,000 at year-end 2014 and $1,544,000 at year-end 2013 and is included in other assets. The amortization of these capitalized costs was $1,067,000 in 2014, $1,593,000 in 2013 and $1,320,000 in 2012 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.
	The following summarizes the changes in asset retirement obligations:
		Year-End
		2014				2013
		(In thousands)
	Beginning balance	$	1,483			$	1,360
	Additions	314				29
	Property dispositions	(230		)		—
	Change in estimate	118				—
	Accretion expense	122				94
		$	1,807			$	1,483
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.
Impairment of Long-Lived Assets
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. As of year-end 2014, we have $8,575,000 in capitalized exploratory well costs pending determination of proved reserves, none of which have been capitalized for a period greater than one year. 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.
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		Carrying
				Value Year-End
		Useful Lives		2014				2013
				(In thousands)
	Buildings and building improvements	10 to 40 years		$	4,461			$	4,111
	Property and equipment	2 to 10 years		14,084				8,240
				18,545				12,351
	Less: accumulated depreciation			(6,918		)		(6,239		)
				$	11,627			$	6,112
	Depreciation expense of property and equipment was $903,000 in 2014, $1,028,000 in 2013 and $962,000 in 2012.
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 real estate 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 100 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.
Reclassifications	Reclassifications
	In 2014, we have reclassified prior years' earnest money deposits that were included in other accrued expenses and other liabilities on our consolidated balance sheets as a separate line item to conform to the current year presentation.
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 revenue from our multifamily properties when payments are due from residents, generally on a monthly basis.
	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.
	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. No such allowance was considered necessary at December 31, 2014 or 2013.
	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, 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 102,000 acres of timber, primarily in Georgia. The non-cash cost of timber cut and sold is $371,000 in 2014, $609,000 in 2013 and $1,220,000 in 2012 and is included in depreciation, depletion and amortization in our statement of cash flows.
New and Pending Accounting Pronouncements	New and Pending Accounting Pronouncements
	Accounting Standards Adopted in 2014
	In 2014, we adopted ASU 2013-04 — Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation Is Fixed at the Reporting Date, ASU 2014-12 — Compensation-Stock Compensation (Topic 718): Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period and ASU 2014-17 — Business Combinations (Topic 805): Pushdown Accounting. Adoption did not materially affect our earnings, financial position or disclosures.
	We also adopted ASU 2014-08 — Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360), Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. ASU 2014-08 raises the threshold for a disposal to qualify as a discontinued operation and requires new and expanded disclosures of both discontinued operations and certain other disposals that do not meet the definition of a discontinued operation.  The Company adopted the updated standard in second quarter 2014. As a result, certain asset disposals were not considered discontinued operations, due to the higher threshold under the updated standard, but that would have qualified as discontinued operations under the previous guidance.
	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. 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.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Schedule of Change in Asset Retirement Obligation	The following summarizes the changes in asset retirement obligations:
		Year-End
		2014				2013
		(In thousands)
	Beginning balance	$	1,483			$	1,360
	Additions	314				29
	Property dispositions	(230		)		—
	Change in estimate	118				—
	Accretion expense	122				94
		$	1,807			$	1,483
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
		2014				2013
		(In thousands)
	Unproved oil and gas properties	$	90,446			$	100,320
	Proved oil and gas properties	221,299				155,262
	Total costs	311,745				255,582
	Less accumulated depreciation, depletion and amortization	(48,252		)		(22,941		)
		$	263,493			$	232,641
Schedule of Property, Plant and Equipment	We depreciate these assets using the straight-line method over their estimated useful lives as follows:
		Estimated		Carrying
				Value Year-End
		Useful Lives		2014				2013
				(In thousands)
	Buildings and building improvements	10 to 40 years		$	4,461			$	4,111
	Property and equipment	2 to 10 years		14,084				8,240
				18,545				12,351
	Less: accumulated depreciation			(6,918		)		(6,239		)
				$	11,627			$	6,112

Goodwill_and_Other_Intangible_1

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2014
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
		2014		2013
		(In thousands)
	Goodwill	$	63,423	$	64,493
	Identified intangibles, net	2,708		2,153
		$	66,131	$	66,646

Real_Estate_Tables

Real Estate (Tables)	12 Months Ended
	Dec. 31, 2014
Real Estate [Abstract]
Real Estate	Real estate consists of:
		At Year-End
		2014			2013
		(In thousands)
	Entitled, developed and under development projects	$	321,273		$	361,687
	Undeveloped land (includes land in entitlement)	93,182			86,367
	Commercial and income producing properties
	Carrying value	192,678			99,476
	Accumulated depreciation	(31,377		)	(28,066		)
	Net carrying value	161,301			71,410
		$	575,756		$	519,464

Oil_and_Gas_Properties_Tables

Oil and Gas Properties (Tables)	12 Months Ended
	Dec. 31, 2014
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
		2014			2013
		(In thousands)
	Unproved oil and gas properties	$	90,446		$	100,320
	Proved oil and gas properties	221,299			155,262
	Total costs	311,745			255,582
	Less accumulated depreciation, depletion and amortization	(48,252		)	(22,941		)
		$	263,493		$	232,641

Investment_in_Unconsolidated_V1

Investment in Unconsolidated Ventures (Tables)	12 Months Ended
	Dec. 31, 2014
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
		2014		2013		2014		2013			2014			2013			2014			2013
		(In thousands)
	242, LLC(b)	$	33,021	$	23,751	$	6,940	$	921		$	21,789		$	19,838		$	10,098		$	9,084
	CJUF III, RH Holdings(c)	—		36,320		—		18,492			—			15,415			—			3,235
	CL Ashton Woods, LP(d)	13,269		10,473		—		—			11,453			9,704			6,015			3,544
	CL Realty, LLC	7,960		8,298		—		—			7,738			8,070			3,869			4,035
	CREA FMF Nashville LLC(b)	40,014		—		29,660		—			5,987			—			5,516			—
	Elan 99, LLC	10,070		—		1		—			9,643			—			8,679			—
	FMF Littleton LLC	26,953		—		—		—			24,435			—			6,287			—
	FMF Peakview LLC	43,638		30,673		23,070		12,533			17,464			16,620			3,575			3,406
	HM Stonewall Estates, Ltd.(d)	3,750		3,781		669		63			3,081			3,718			1,752			2,128
	LM Land Holdings, LP(d)	25,561		33,298		4,448		9,768			18,500			13,347			9,322			8,283
	PSW Communities, LP	16,045		—		10,515		—			4,415			—			3,924			—
	TEMCO Associates, LLC	11,756		13,320		—		—			11,556			13,160			5,778			6,580
	Other ventures (4)(e)	8,453		12,723		26,944		29,699			(25,614		)	(31,357		)	190			852
		$	240,490	$	172,637	$	102,247	$	71,476		$	110,447		$	68,515		$	65,005		$	41,147
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
		2014		2013		2012		2014			2013			2012			2014			2013			2012
		(In thousands)
	242, LLC(b)	$	5,612	$	6,269	$	4,868	$	2,951		$	1,512		$	1,040		$	1,514		$	805		$	572
	CJUF III, RH Holdings(c)	2,168		120		—		(956		)	(652		)	(241		)	(956		)	(652		)	(241		)
	CL Ashton Woods, LP(d)	5,431		9,018		3,353		1,748			2,660			1,472			2,471			4,169			2,024
	CL Realty, LLC	1,573		1,603		2,667		1,068			1,028			1,060			534			514			530
	CREA FMF Nashville LLC(b)	—		—		—		(163		)	—			—			(163		)	—			—
	Elan 99, LLC	—		—		—		(87		)	—			—			(78		)	—			—
	FMF Littleton LLC	—		—		—		(239		)	—			—			(60		)	—			—
	FMF Peakview LLC	4		1		—		(410		)	(252		)	(116		)	(83		)	(50		)	(23		)
	HM Stonewall Estates, Ltd.(d)	1,728		2,922		2,500		613			1,082			829			248			452			332
	LM Land Holdings, LP(d)	21,980		25,426		10,268		15,520			11,012			1,895			4,827			3,418			257
	PSW Communities, LP	—		—		—		(86		)	—			—			(76		)	—			—
	TEMCO Associates, LLC	2,155		630		702		494			96			(80		)	247			48			(40		)
	Other ventures (4)(f)	1,792		5,994		8,790		4,835			176			10,032			260			33			11,058
		$	42,443	$	51,983	$	33,148	$	25,288		$	16,662		$	15,891		$	8,685		$	8,737		$	14,469
	_____________________
	(a)	Total includes current maturities of $65,795,000 at year-end 2014, of which $42,566,000 is non-recourse to us, and $37,966,000 at year-end 2013, of which $37,822,000 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 $1,621,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2014.
	(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. At year-end 2014, we no longer have an equity method investment in the Eleven venture.
	(d)	Includes unrecognized basis difference of $1,517,000 which is reflected as a reduction of our investment in unconsolidated ventures at year-end 2014. 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 25 to 50 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.
	(f)	In 2012, other ventures earnings include $5,307,000 related to a consolidated venture’s share of the gain associated with Round Rock Luxury Apartment's sale of Las Brisas. Our share of these earnings was $2,541,000 and we allocated $2,766,000 to net income attributable to noncontrolling interests.

Receivables_Tables

Receivables (Tables)	12 Months Ended
	Dec. 31, 2014
Receivables [Abstract]
Receivables	Receivables consist of:
		At Year-End
		2014			2013
		(In thousands)
	Loan secured by real estate	$	3,574		$	7,610
	Other loans secured by real estate, average interest rate of 4.41% at year-end 2014 and 5.00% at year-end 2013	1,737			7,987
	Oil and gas joint interest billing receivables	5,738			3,896
	Oil and gas revenue accruals	7,293			8,137
	Other receivables and accrued interest	6,505			11,648
		24,847			39,278
	Allowance for bad debts	(258		)	(26		)
		$	24,589		$	39,252
Estimated Accretable Yield	Estimated accretable yield is as follows:
		At Year-End
		2014			2013
		(In thousands)
	Beginning of year	$	8,908		$	25,149
	Change in accretable yield due to change in timing of estimated cash flows	(166		)	(10,950		)
	Interest income recognized	(7,903		)	(5,291		)
		$	839		$	8,908

Debt_Tables

Debt (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Debt	Debt consists of:
		At Year-End
		2014		2013
		(In thousands)
	Senior secured credit facility
	Term loan facility — average interest rate of 4.17% at year-end 2013	$	—	$	200,000
	8.50% senior secured notes due 2022	250,000		—
	3.75% convertible senior notes due 2020, net of discount	103,194		99,890
	6.00% tangible equity units, net of discount	17,154		25,619
	Secured promissory notes — average interest rates of 3.17% at year-end 2014 and 2013	15,400		15,400
	Other indebtedness due through 2017 at variable and fixed interest rates ranging from 2.19% to 5.00%	46,996		16,498
		$	432,744	$	357,407

Fair_Value_Tables

Fair Value (Tables)	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Carrying Value of Assets
		Year-End 2014												Year-End 2013
		Level 1			Level 2			Level 3			Total			Level 1		Level 2		Level 3		Total
		(In thousands)
	Non-Financial Assets and Liabilities:
	Real estate	$	—		$	970		$	—		$	970		$	—	$	3,700	$	—	$	3,700
	Proved oil and gas properties	$	—		$	—		$	3,655		$	3,655		$	—	$	—	$	—	$	—
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 2014						Year-End 2013
		Carrying			Fair			Carrying			Fair			Valuation
		Amount			Value			Amount			Value			Technique
		(In thousands)
	Loan secured by real estate	$	3,574		$	4,859		$	7,610		$	18,025		Level 2
	Fixed rate debt(a)	$	(370,348	)	$	(359,131	)	$	(126,640	)	$	(118,634	)	Level 2
	_____________________
	(a)	Year-end 2014 includes our $250,000,000 of 8.50% senior secured notes due 2022, issued May 12, 2014.

Net_Income_per_Share_Tables

Net Income per Share (Tables)	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Earnings Attributable to Common Shareholders and Weighted Average Common Shares Outstanding
		For the Year
		2014			2013			2012
		(In thousands)
	Numerator:
	Consolidated net income	$	17,088		$	35,061		$	17,876
	Less: Net income attributable to noncontrolling interest	(505		)	(5,740		)	(4,934		)
	Earnings available for diluted earnings per share	$	16,583		$	29,321		$	12,942
	Less: Undistributed net income allocated to participating securities	(3,018		)	(585		)	—
	Earnings available to common shareholders for basic earnings per share	$	13,565		$	28,736		$	12,942
	Denominator:
	Weighted average common shares outstanding — basic	35,317			35,365			35,214
	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			268
	Total weighted average shares outstanding — diluted	43,596			36,813			35,482
	Anti-dilutive awards excluded from diluted weighted average shares outstanding	2,238			1,803			2,713
	_____________________
	(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 November 27, 2013.

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Tax Expense	Income tax expense consists of:
		For the Year
		2014				2013				2012
		(In thousands)
	Current tax provision:
	U.S. Federal	$	(5,444	)		$	(6,004	)		$	(11,834	)
	State and other	(1,569		)		(2,066		)		(2,171		)
		(7,013		)		(8,070		)		(14,005		)
	Deferred tax provision:
	U.S. Federal	(2,772		)		1,148				4,910
	State and other	1,128				(286		)		1,079
		(1,644		)		862				5,989
	Income tax expense	$	(8,657	)		$	(7,208	)		$	(8,016	)
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
		2014			2013			2012
	Federal statutory rate	35	%		35	%		35	%
	State, net of federal benefit	1			4			5
	Recognition of previously unrecognized tax benefits	—			(15	)		—
	State rate change due to acquisition	—			—			(2	)
	Acquisition costs	—			—			4
	Noncontrolling interests	—			(5	)		(7	)
	Goodwill	1			—			—
	Charitable contributions	(1	)		—			—
	Oil and gas percentage depletion	(2	)		(2	)		(5	)
	Other	—			—			1
	Effective tax rate	34	%		17	%		31	%
Significant Components of Deferred Taxes	Significant components of deferred taxes are:
		At Year-End
		2014				2013
		(In thousands)
	Deferred Tax Assets:
	Real estate	$	79,244			$	75,157
	Employee benefits	17,352				17,902
	Net operating loss carryforwards	3,012				3,076
	Income producing properties	364				3,529
	Oil and gas percentage depletion carryforwards	3,471				3,344
	Accruals not deductible until paid	1,111				960
	Gross deferred tax assets	104,554				103,968
	Valuation allowance	(384		)		(375		)
	Deferred tax asset net of valuation allowance	104,170				103,593
	Deferred Tax Liabilities:
	Oil and gas properties	(49,905		)		(46,966		)
	Undeveloped land	(4,937		)		(5,961		)
	Convertible debt	(7,816		)		(8,803		)
	Timber	(888		)		(1,465		)
	Gross deferred tax liabilities	(63,546		)		(63,195		)
	Net Deferred Tax Asset	$	40,624			$	40,398
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
		2014				2013				2012
		(In thousands)
	Balance at beginning of year	$	—			$	5,831			$	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	$	—			$	—			$	5,831

Segment_Information_Tables

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Segment Revenues and Earnings
		Real			Oil and Gas			Other Natural			Items Not				Total
		Estate						Resources			Allocated to
											Segments
		(In thousands)
	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 (loss) 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 (loss) 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
	For the year or at year-end 2012
	Revenues	$	120,115		$	44,220		$	8,256		$	—			$	172,591
	Depreciation, depletion and amortization	4,340			4,987			1,254			8,345				18,926
	Equity in earnings of unconsolidated ventures	13,897			509			63			—				14,469
	Income (loss) before taxes	53,582			26,608			29			(59,261		)	(a)	20,958
	Total assets	588,137			227,061			24,066			79,170				918,434
	Investment in unconsolidated ventures	41,546			—			—			—				41,546
	Capital expenditures(b)	1,093			21,971			292			795				24,151
	_____________________
	(a)	Items not allocated to segments consist of:
		For the Year
		2014			2013			2012
		(In thousands)
	General and administrative expense	$	(21,229	)	$	(20,597	)	$	(25,176	)
	Share-based compensation expense	(3,417		)	(16,809		)	(14,929		)
	Gain on sale of assets	—			—			16
	Interest expense	(30,286		)	(20,004		)	(19,363		)
	Other corporate non-operating income	453			119			191
		$	(54,479	)	$	(57,291	)	$	(59,261	)
	(b)	Consists of expenditures for oil and gas properties and equipment, commercial and income producing properties, property, plant and equipment and reforestation of timber.

ShareBased_Compensation_Tables

Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Components of Share-Based Compensation Expense (Income)	Share-based compensation expense consists of:
		For the Year
		2014				2013				2012
		(In thousands)
	Cash-settled awards	$	(3,710	)		$	7,774			$	6,465
	Equity-settled awards	5,168				4,281				3,059
	Restricted stock	(25		)		538				2,154
	Stock options	1,984				4,216				3,251
		$	3,417			$	16,809			$	14,929
Share-Based Compensation Expense (Income) Included in Operating Expense	Share-based compensation expense is included in:
		For the Year
		2014				2013				2012
		(In thousands)
	General and administrative	$	1,001			$	7,779			$	7,144
	Other operating	2,416				9,030				7,785
		$	3,417			$	16,809			$	14,929
Summarized Activity of Cash-Settled Restricted Stock Unit Awards	The following table summarizes the activity of cash-settled restricted stock unit awards in 2014:
		Equivalent			Weighted Average Grant Date Fair Value
		Units
		(In thousands)			(Per unit)
	Non-vested at beginning of period	233			$17.90
	Granted	93			18.96
	Vested	(132	)		17.86
	Forfeited	(9	)		17.42
	Non-vested at end of period	185			18.49
Summarized Activity of Cash-Settled Stock Appreciation Rights	The following table summarizes the activity of cash-settled stock appreciation rights in 2014:
		Rights			Weighted Average		Weighted Average		Aggregate Intrinsic Value
		Outstanding			Exercise Price		Remaining Contractual Term		(Current Value Less Exercise Price)
		(In thousands)			(Per share)		(In years)		(In thousands)
	Balance at beginning of period	580			$11.96		5		$5,400
	Granted	—			—
	Exercised	(116	)		9.41
	Forfeited	(6	)		17.8
	Balance at end of period	458			12.54		4		1,732
	Exercisable at end of period	458			12.54		4		1,732
Summarized Activity of Equity-Settled Awards	The following table summarizes the activity of equity-settled awards in 2014:
		Equivalent			Weighted Average Grant Date Fair Value
		Units
		(In thousands)			(Per unit)
	Non-vested at beginning of period	581			$	19.5
	Granted	512			19.18
	Vested	(259	)		20.01
	Forfeited	(124	)		18.58
	Non-vested at end of period	710			19.24
Summarized Activity of Restricted Stock Awards	The following table summarizes the activity of restricted stock awards in 2014:
		Restricted			Weighted Average Grant Date Fair Value
		Shares
		(In thousands)			(Per unit)
	Non-vested at beginning of period	47			$	14.99
	Granted	—			—
	Vested	(20	)		12.74
	Forfeited	(10	)		15.02
	Non-vested at end of period	17			17.56
Summarized Activity of Stock Option Awards	The following table summarizes the activity of stock option awards in 2014:
		Options			Weighted				Weighted		Aggregate
		Outstanding			Average				Average		Intrinsic Value
					Exercise Price				Remaining		(Current
									Contractual		Value Less
									Term		Exercise Price)
		(In thousands)			(Per share)				(In years)		(In thousands)
	Balance at beginning of period	2,006			$	20.3			7		$	6,433
	Granted	—			—
	Exercised	(56	)		9.64
	Forfeited	(89	)		17.65
	Balance at end of period	1,861			20.74				6		643
	Exercisable at end of period	1,364			21.86				5		620
Fair Value of Stock Options Using Black-Scholes Option Pricing Model	We estimate the grant date fair value of stock options using the Black-Scholes option pricing model and the following assumptions:
			For the Year
			2013				2012
	Expected stock price volatility		66.8		%		60.2		%
	Risk-free interest rate		1.4		%		1.3		%
	Expected life of options (years)		6				6
	Expected dividend yield		—		%		—		%
	Weighted average estimated fair value of options at grant date		$	11.47			$	9.22

Supplemental_Oil_and_Gas_Discl1

Supplemental Oil and Gas Disclosures (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2014
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)			Gas
		(Barrels)			(Mcf)
		(In thousands)
	Consolidated entities:
	Year-end 2011	1,064			8,203
	Revisions of previous estimates	45			(2,163	)
	Extensions and discoveries	86			241
	Acquisitions	2,396			7,109
	Production	(371	)		(1,668	)
	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
	Our share of ventures accounted for using the equity method:
	Year-end 2011	—			3,283
	Revisions of previous estimates	—			(390	)
	Production	—			(321	)
	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
	Total consolidated and our share of equity method ventures:
	Year-end 2012
	Proved developed reserves	2,416			13,020
	Proved undeveloped reserves	804			1,274
	Total Year-end 2012	3,220			14,294
	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
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
		2014				2013
		(In thousands)
	Unproved oil and gas properties	$	90,446			$	100,320
	Proved oil and gas properties	221,299				155,262
	Total costs	311,745				255,582
	Less accumulated depreciation, depletion and amortization	(48,252		)		(22,941		)
		$	263,493			$	232,641
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
		2014				2013			2012
		(In thousands)
	Consolidated entities:
	Acquisition costs:
	Proved properties	$	2,001			$	—		$	—
	Unproved properties	25,666				35,806			4,418
	Exploration costs	39,399				10,486			1,752
	Development costs	40,277				54,538			15,938
		$	107,343			$	100,830		$	22,108
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
		2014				2013			2012
		(In thousands)
	Consolidated entities:
	Future cash inflows	$	665,657			$	544,098		$	322,098
	Future production and development costs	(271,735		)		(231,801		)	(104,441		)
	Future income tax expenses	(106,002		)		(77,361		)	(50,350		)
	Future net cash flows	287,920				234,936			167,307
	10% annual discount for estimated timing of cash flows	(124,079		)		(99,383		)	(60,764		)
	Standardized measure of discounted future net cash flows	$	163,841			$	135,553		$	106,543
	Our share in ventures accounted for using the equity method:
	Future cash inflows	$	6,186			$	4,765		$	5,125
	Future production and development costs	(664		)		(512		)	(551		)
	Future income tax expenses	(2,098		)		(1,616		)	(1,738		)
	Future net cash flows	3,424				2,637			2,836
	10% annual discount for estimated timing of cash flows	(1,649		)		(1,337		)	(1,423		)
	Standardized measure of discounted future net cash flows	$	1,775			$	1,300		$	1,413
	Total consolidated and our share of equity method ventures	$	165,616			$	136,853		$	107,956
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			Total
						Method Ventures
		(In thousands)
	Year-end 2011	$	52,698			$	3,508		$	56,206
	Changes resulting from:
	Net change in sales prices and production costs	(5,709		)		(2,497		)	(8,206		)
	Net change in future development costs	(1,834		)		—			(1,834		)
	Sales of oil and gas, net of production costs	(31,732		)		(632		)	(32,364		)
	Net change due to extensions and discoveries	5,596				—			5,596
	Net change due to acquisition of reserves	86,013				—			86,013
	Net change due to revisions of quantity estimates	(2,254		)		18			(2,236		)
	Previously estimated development costs incurred	1,007				—			1,007
	Accretion of discount	7,377				401			7,778
	Net change in income taxes	(4,619		)		615			(4,004		)
	Aggregate change for the year	53,845				(2,095		)	51,750
	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
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
		2014				2013			2012
		(In thousands)
	Consolidated entities(a)
	Revenues	$	82,919			$	69,036		$	36,204
	Production costs	(19,727		)		(12,477		)	(4,472		)
	Exploration costs	(17,416		)		(10,486		)	(1,754		)
	Depreciation, depletion, amortization	(29,442		)		(19,552		)	(4,905		)
	Non-cash impairments	(32,665		)		(473		)	—
	Oil and gas administrative expenses	(17,000		)		(14,407		)	(8,332		)
	Accretion expense	(121		)		(94		)	(26		)
	Income tax expenses	13,398				(3,471		)	(4,841		)
	Results of operations	(20,054		)		8,076			11,874
	Our share in ventures accounted for using the equity method:
	Revenues	$	786			$	801		$	770
	Production costs	(105		)		(123		)	(138		)
	Oil and gas administrative expenses	(95		)		(86		)	(123		)
	Income tax expenses	(235		)		(178		)	(147		)
	Results of operations	$	351			$	414		$	362
	Total results of operations	$	(19,703	)		$	8,490		$	12,236
	_____________________
	(a)	2012 includes only three months of operations from Credo due to our third quarter 2012 acquisition.
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
		2014				2013
		(In thousands)
	Consolidated entities:
	Unproved oil and gas properties	$	90,446			$	100,320
	Proved oil and gas properties	221,299				155,262
	Total costs	311,745				255,582
	Less accumulated depreciation, depletion and amortization	(48,252		)		(22,941		)
		$	263,493			$	232,641

Summary_of_Quarterly_Results_o1

Summary of Quarterly Results of Operations (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Summary of Quarterly Results of Operations	Summarized quarterly financial results for 2014 and 2013 follows:
		First		Second		Third		Fourth
		Quarter		Quarter		Quarter		Quarter(a)
		(In thousands, except per share amounts)
	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	$	0.2	$	0.34	$	0.12	$	(0.34	)
	Net income (loss) per share — diluted	$	0.19	$	0.34	$	0.12	$	(0.34	)
	2013
	Total revenues	$	97,471	$	60,079	$	75,107	$	98,388
	Gross profit	35,899		22,463		32,608		39,181
	Operating income	9,520		3,554		10,612		22,891
	Equity in earnings of unconsolidated ventures	913		2,566		3,125		2,133
	Income before taxes	7,035		2,109		9,965		23,160
	Net income attributable to Forestar Group Inc.	3,951		541		11,830		12,999
	Net income per share — basic	$	0.11	$	0.02	$	0.33	$	0.34
	Net income per share — diluted	$	0.11	$	0.02	$	0.33	$	0.33
	_____________________
	(a)	Fourth quarter 2014 results include pre-tax non-cash impairment charges of $30,591,000 for unproved leasehold interests and proved oil and gas properties.

Summary_of_Significant_Account3

Summary of Significant Accounting Policies - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Significant Accounting Policies [Line Items]
Capitalized Exploratory Well Costs	$8,575,000
Capital Expenditures Incurred but Not yet Paid	19,405,000	12,976,000
Restricted cash and cash equivalents	217,000	3,954,000
Contractual Period Of Sale Contracts	5 years
Capitalized Exploratory Well Costs that Have Been Capitalized for Period Greater than One Year	0
Non-Oil And Gas Properties [Member]
Significant Accounting Policies [Line Items]
Depreciation expense of property and equipment	903,000	1,028,000	962,000
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	100.00%
Capitalize reforestation costs	2 years
Computer Software, Intangible Asset [Member]
Significant Accounting Policies [Line Items]
Carrying value of capitalized software	1,188,000	1,544,000
Capitalized software amortization	1,067,000	1,593,000	1,320,000
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	102,000
Depletion	$371,000	$609,000	$1,220,000

Summary_of_Significant_Account4

Summary of Significant Accounting Policies - Schedule of Change in Asset Retirement Obligation (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Asset Retirement Obligation [Roll Forward]
Beginning balance	$1,483	$1,360
Accretion expense	122	94
Additions	314	29
Asset Retirement Obligation, Liabilities Settled	-230	0
Asset Retirement Obligation, Revision of Estimate	118	0
Ending balance	$1,807	$1,483

Summary_of_Significant_Account5

Summary of Significant Accounting Policies - Estimated Useful Lives of Property Plant and Equipment (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Property plant and equipment, gross	18,545	$12,351
Less: accumulated depreciation	-6,918	-6,239
Property Plant And Equipment, Net	11,627	6,112
Building and Building Improvements [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment, gross	4,461	4,111
Property and Equipment [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment, gross	14,084	$8,240
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_Intangible_2

Goodwill and Other Intangible Assets - Carrying Value of Goodwill and Other Intangible Assets (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	$63,423	$64,493
Identified intangibles, net	2,708	2,153
Total	$66,131	$66,646

Goodwill_and_Other_Intangible_3

Goodwill and Other Intangible Assets - Additional Information (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2010	Sep. 30, 2014
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Goodwill acquired on acquisition	$63,423,000	$64,493,000
Credo [Member]
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Goodwill acquired on acquisition	59,549,000	60,619,000
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	378,000
Multi Family Property [Member] | Austin, Texas [Member]
Schedule Of Goodwill And Other Intangible Assets [Line Items]
Identified intangibles, net	$649,000			$865,000

Real_Estate_Real_Estate_Detail

Real Estate - Real Estate (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Thousands, unless otherwise specified
Real Estate [Abstract]
Entitled, developed and under development projects	$321,273	$361,687
Undeveloped land (includes land entitlement)	93,182	86,367
Carrying value	192,678	99,476
Accumulated depreciation	-31,377	-28,066	-28,220	-26,955
Net carrying value	161,301	71,410
Total Real Estate	$575,756	$519,464

Real_Estate_Additional_Informa

Real Estate - Additional Information (Detail) (USD $)	12 Months Ended			9 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Sep. 30, 2014
Real Estate Properties [Line Items]
Costs relate to water, sewer and other infrastructure assets	$7,118,000	$17,923,000
Recovery of direct costs	-66,047,000	-9,945,000	-8,524,000
GAIN ON SALE OF ASSETS	38,038,000	5,161,000	25,983,000
Investment in resort development	575,756,000	519,464,000
Carrying value	192,678,000	99,476,000
General Contractor Costs	5,111,000	554,000
Non-cash asset impairment charges	15,934,000	1,790,000	0
Payments to Acquire and Develop Real Estate	114,694,000	106,609,000	91,940,000
Cibolo Canyons Project [Member]
Real Estate Properties [Line Items]
Recovery of direct costs	9,883,000	600,000
Payments Received From Special Improvement District	50,550,000	4,400,000
GAIN ON SALE OF ASSETS	6,577,000
Investment in resort development				24,067,000
Area of Land	33
Cibolo Canyons Project [Member] | San Antonio Texas [Member]
Real Estate Properties [Line Items]
Cost of asset in developed and under development projects	31,913,000	41,795,000
Multi Family Property [Member] | Austin, Texas [Member]
Real Estate Properties [Line Items]
Carrying value	53,382,000			53,917,000
Number Of Units Of Multifamily Project	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			55,275,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt	23,936,000			23,936,000
Business Combination, Consideration Transferred, Including Equity Interest in Acquiree Held Prior to Combination	2,229,000
Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value	2,229,000			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	649,000			865,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Working Capital				979,000
Multi Family Property [Member] | Dallas, Texas [Member]
Real Estate Properties [Line Items]
Carrying value	33,062,000
Number Of Units Of Multifamily Project	354
Hotel Property [Member] | Austin, Texas [Member]
Real Estate Properties [Line Items]
Carrying value	30,712,000
Commercial And Income Producing Properties Unit	413
Multi Family Development Properties [Member]
Real Estate Properties [Line Items]
Carrying value	44,145,000
Payments to Acquire and Develop Real Estate	26,110,000
Consolidated Properties [Member]
Real Estate Properties [Line Items]
Recovery of direct costs	15,497,000	5,545,000
Utility and Improvement District [Member]
Real Estate Properties [Line Items]
Cost of asset in developed and under development projects	65,212,000	62,183,000
Income Producing Properties [Member] | Land, Buildings and Improvements [Member]
Real Estate Properties [Line Items]
Depreciation expense, related to commercial and income producing properties	3,319,000	2,507,000	3,640,000
Exchange of Productive Assets [Member]
Real Estate Properties [Line Items]
Land Subject to Ground Leases	10,300
Area of Land	5,400
Nonmonetary Transaction, Gain (Loss) Recognized on Transfer	10,476,000
Real Estate [Member]
Real Estate Properties [Line Items]
Non-cash asset impairment charges	399,000
Bonds [Member] | Cibolo Canyons Project [Member]
Real Estate Properties [Line Items]
Payments Received From Special Improvement District	46,500,000
Debt Instrument, Face Amount	48,900,000
Letters of Credit Outstanding, Amount	6,846,000
Surety Bond for Bond Trustee	$9,010,000

Oil_and_Gas_Properties_Details

Oil and Gas Properties (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
	Well
	acre
Impairment of Leasehold	$17,130,000	$473,000
Impairment of Oil and Gas Properties	15,535,000
Gain (Loss) on Disposition of Proved Property	8,526,000
Gas and Oil Area, Undeveloped, Net	650
Productive Oil Wells, Number of Wells, Gross	124
Productive Oil Wells, Number of Wells, Net	18
Proceeds from Sale of Oil and Gas Property and Equipment	$17,660,000

Oil_and_Gas_Properties_Oil_and

Oil and Gas Properties Oil and Gas Properties - Net Capitalized Costs Related to Oil and Gas Producing Activities (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Oil and Gas Properties [Abstract]
Unproved oil and gas properties	$90,446	$100,320
Proved Oil and Gas Property, Successful Effort Method	221,299	155,262
Total costs	311,745	255,582
Oil and Gas Property, Successful Effort Method, Accumulated Depreciation, Depletion and Amortization	-48,252	-22,941
Oil and Gas Property, Successful Effort Method, Net	$263,493	$232,641

Recovered_Sheet1

Investment In Unconsolidated Ventures - Additional Information (Detail) (USD $)	12 Months Ended					9 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012	Sep. 30, 2014
	Venture
Payments to Acquire Additional Interest in Subsidiaries	$7,971,000		$0		$0
Noncontrolling interests	2,904,000		2,907,000		1,032,000
Investment in unconsolidated ventures	65,005,000		41,147,000		41,546,000
Number of ventures under ownership interest using equity method	15
for_NumberOfNewlyFormedUnconsolidatedVentures	3
Payments to Acquire Interest in Joint Venture	20,155,000
Distributions	7,518,000		9,854,000		15,905,000
Fees for services	2,275,000		1,068,000		935,000
Equity Method Investee [Member]
Payments to Acquire Interest in Joint Venture	14,692,000		857,000		2,318,000
FMF Littleton [Member]
Construction Loan	0	[1]
Investment in unconsolidated ventures	6,287,000		0
FMF Littleton [Member] | COLORADO
Number Of Units Of Multifamily Project	385
Equity Method Investment, Ownership Percentage	25.00%
Equity Method Investment, Ownership Percentage of Partner	75.00%
Noncontrolling interests	4,900,000
Reimbursed Costs From Unconsolidated Ventures	9,852,000
Construction Loan, Guaranty Of Repayment, Conditions Not Met, Percentage	25.00%
Construction Loan, Guaranty Of Repayment, Conditions Met, Percentage	10.00%
CREA FMF [Member]
Investment in unconsolidated ventures	5,516,000	[2]	0	[2]
CREA FMF [Member] | Nashville, Tennessee [Member]
Number Of Units Of Multifamily Project	320
Equity Method Investment, Ownership Percentage	30.00%
Equity Method Investment, Ownership Percentage of Partner	70.00%
Noncontrolling interests	5,897,000
Reimbursed Costs From Unconsolidated Ventures	7,191,000
Maximum Capital Contribution from Partner	14,220,000
Construction Loan, Guaranty Of Repayment, Conditions Not Met, Percentage	25.00%
Construction Loan, Guaranty Of Repayment, Conditions Met, Percentage	0.00%
Elan 99 LLC [Member]
Investment in unconsolidated ventures	8,679,000		0
Elan 99 LLC [Member] | Houston, Texas [Member]
Number Of Units Of Multifamily Project	360
Equity Method Investment, Ownership Percentage	90.00%
Equity Method Investment, Ownership Percentage of Partner	10.00%
Noncontrolling interests	8,757,000
Construction Loans [Member] | FMF Littleton [Member] | COLORADO
Debt Instrument, Unused Borrowing Capacity, Amount	46,384,000
Construction Loans [Member] | CREA FMF [Member] | Nashville, Tennessee [Member]
Debt Instrument, Unused Borrowing Capacity, Amount	51,950,000
Construction Loan	29,660,000	[1],[2]
Construction Loans [Member] | Elan 99 LLC [Member] | Houston, Texas [Member]
Debt Instrument, Unused Borrowing Capacity, Amount	37,275,000
Construction Loan	1,000	[1]
Thirty Day LIBOR Rate [Member] | Construction Loans [Member]
Debt Instrument, Basis Spread on Variable Rate	2.50%
Thirty Day LIBOR Rate [Member] | Construction Loans [Member] | FMF Littleton [Member] | COLORADO
Debt Instrument, Basis Spread on Variable Rate	1.90%
London Interbank Offered Rate (LIBOR) [Member] | Construction Loans [Member] | Elan 99 LLC [Member] | Houston, Texas [Member]
Debt Instrument, Basis Spread on Variable Rate	2.50%
Debt Instrument, Basis Spread on Variable Rate if test is met	2.30%
Multi Family Property [Member]
Payments to Acquire Interest in Joint Venture			0		0
Multi Family Property [Member] | Austin, Texas [Member]
Payments to Acquire Additional Interest in Subsidiaries	21,500,000
Number Of Units Of Multifamily Project	257
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net	55,275,000					55,275,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt	23,936,000					23,936,000
Business Combination, Step Acquisition, Equity Interest in Acquiree, Fair Value	$2,229,000					$9,839,000
[1]	Total includes current maturities of $65,795,000 at year-end 2014, of which $42,566,000 is non-recourse to us, and $37,966,000 at year-end 2013, of which $37,822,000 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 $1,621,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2014.

Recovered_Sheet2

Investment In Unconsolidated Ventures - Summarized Balance Sheet Information (Detail) (USD $)	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Schedule of Equity Method Investments [Line Items]
Venture Assets	$240,490,000		$172,637,000
Venture Borrowings	102,247,000	[1]	71,476,000	[1]
Venture Equity	110,447,000		68,515,000
Investment in unconsolidated ventures	65,005,000		41,147,000		41,546,000
242, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	33,021,000	[2]	23,751,000	[2]
Venture Borrowings	6,940,000	[1],[2]	921,000	[1],[2]
Venture Equity	21,789,000	[2]	19,838,000	[2]
Investment in unconsolidated ventures	10,098,000	[2]	9,084,000	[2]
Elan 99 LLC [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	10,070,000		0
Venture Borrowings			0	[1]
Venture Equity	9,643,000		0
Investment in unconsolidated ventures	8,679,000		0
CJUF III, RH Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	0	[3]	36,320,000	[3]
Venture Borrowings	0	[1],[3]	18,492,000	[1],[3]
Venture Equity	0	[3]	15,415,000	[3]
Investment in unconsolidated ventures	0	[3]	3,235,000	[3]
CL Ashton Woods [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	13,269,000	[4]	10,473,000	[4]
Venture Borrowings	0	[1],[4]	0	[1],[4]
Venture Equity	11,453,000	[4]	9,704,000	[4]
Investment in unconsolidated ventures	6,015,000	[4]	3,544,000	[4]
CL Realty [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	7,960,000		8,298,000
Venture Borrowings	0	[1]	0	[1]
Venture Equity	7,738,000		8,070,000
Investment in unconsolidated ventures	3,869,000		4,035,000
CREA FMF [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	40,014,000	[2]	0	[2]
Venture Borrowings			0	[1],[2]
Venture Equity	5,987,000	[2]	0	[2]
Investment in unconsolidated ventures	5,516,000	[2]	0	[2]
FMF Littleton [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	26,953,000		0
Construction Loan	0	[1]
Venture Borrowings			0	[1]
Venture Equity	24,435,000		0
Investment in unconsolidated ventures	6,287,000		0
FMF Peakview [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	43,638,000		30,673,000
Venture Borrowings	23,070,000	[1]	12,533,000	[1]
Venture Equity	17,464,000		16,620,000
Investment in unconsolidated ventures	3,575,000		3,406,000
HM Stonewall Estates [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	3,750,000	[3]	3,781,000	[3]
Venture Borrowings	669,000	[1],[4]	63,000	[1],[4]
Venture Equity	3,081,000	[3]	3,718,000	[3]
Investment in unconsolidated ventures	1,752,000	[3]	2,128,000	[3]
LM Land Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	25,561,000	[3]	33,298,000	[3]
Venture Borrowings	4,448,000	[1],[4]	9,768,000	[1],[4]
Venture Equity	18,500,000	[3]	13,347,000	[3]
Investment in unconsolidated ventures	9,322,000	[3]	8,283,000	[3]
PSW Communities [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	16,045,000		0
Venture Borrowings	10,515,000	[1]	0	[1]
Venture Equity	4,415,000		0
Investment in unconsolidated ventures	3,924,000		0
Temco [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	11,756,000		13,320,000
Venture Borrowings	0	[1]	0	[1]
Venture Equity	11,556,000		13,160,000
Investment in unconsolidated ventures	5,778,000		6,580,000
Other Ventures [Member]
Schedule of Equity Method Investments [Line Items]
Venture Assets	8,453,000	[4]	12,723,000	[4]
Venture Borrowings	26,944,000	[1],[5]	29,699,000	[1],[5]
Venture Equity	-25,614,000	[4]	-31,357,000	[4]
Investment in unconsolidated ventures	$190,000	[4]	$852,000	[4]
[1]	Total includes current maturities of $65,795,000 at year-end 2014, of which $42,566,000 is non-recourse to us, and $37,966,000 at year-end 2013, of which $37,822,000 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 $1,621,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2014.
[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. At year-end 2014, we no longer have an equity method investment in the Eleven venture.
[4]	Includes unrecognized basis difference of $1,517,000 which is reflected as a reduction of our investment in unconsolidated ventures at year-end 2014. 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.
[5]	Our investment in other ventures reflects our ownership interests generally ranging from 25 to 50 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_V2

Investment In Unconsolidated Ventures - Summarized Income Statement Information (Detail) (USD $)	3 Months Ended									12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Schedule of Equity Method Investments [Line Items]
Revenues										$42,443		$51,983		$33,148
Earnings (Loss)										25,288		16,662		15,891
Our share of earnings (loss)	4,720	[1]	2,016	958	991	2,133	3,125	2,566	913	8,685		8,737		14,469
242, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Revenues										5,612	[2]	6,269	[2]	4,868	[2]
Earnings (Loss)										2,951	[2]	1,512	[2]	1,040	[2]
Our share of earnings (loss)										1,514	[2]	805	[2]	572	[2]
CJUF III, RH Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Revenues										2,168	[3]	120	[3]	0	[3]
Earnings (Loss)										-956	[3]	-652	[3]	-241	[3]
Our share of earnings (loss)										-956	[3]	-652	[3]	-241	[3]
CL Ashton Woods [Member]
Schedule of Equity Method Investments [Line Items]
Revenues										5,431	[4]	9,018	[4]	3,353	[4]
Earnings (Loss)										1,748	[4]	2,660	[4]	1,472	[4]
Our share of earnings (loss)										2,471	[4]	4,169	[4]	2,024	[4]
CL Realty [Member]
Schedule of Equity Method Investments [Line Items]
Revenues										1,573		1,603		2,667
Earnings (Loss)										1,068		1,028		1,060
Our share of earnings (loss)										534		514		530
CREA FMF [Member]
Schedule of Equity Method Investments [Line Items]
Revenues										0	[2]	0	[2]	0	[2]
Earnings (Loss)										-163	[2]	0	[2]	0	[2]
Our share of earnings (loss)										-163	[2]	0	[2]	0	[2]
Elan 99 LLC [Member]
Schedule of Equity Method Investments [Line Items]
Revenues										0		0		0
Earnings (Loss)										-87		0		0
Our share of earnings (loss)										-78		0		0
FMF Littleton [Member]
Schedule of Equity Method Investments [Line Items]
Revenues										0		0		0
Earnings (Loss)										-239		0		0
Our share of earnings (loss)										-60		0		0
FMF Peakview [Member]
Schedule of Equity Method Investments [Line Items]
Revenues										4		1		0
Earnings (Loss)										-410		-252		-116
Our share of earnings (loss)										-83		-50		-23
HM Stonewall Estates [Member]
Schedule of Equity Method Investments [Line Items]
Revenues										1,728	[4]	2,922	[4]	2,500	[4]
Earnings (Loss)										613	[4]	1,082	[4]	829	[4]
Our share of earnings (loss)										248	[4]	452	[4]	332	[4]
LM Land Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Revenues										21,980	[4]	25,426	[4]	10,268	[4]
Earnings (Loss)										15,520	[4]	11,012	[4]	1,895	[4]
Our share of earnings (loss)										4,827	[4]	3,418	[4]	257	[4]
PSW Communities [Member]
Schedule of Equity Method Investments [Line Items]
Revenues										0		0		0
Earnings (Loss)										-86		0		0
Our share of earnings (loss)										-76		0		0
Temco [Member]
Schedule of Equity Method Investments [Line Items]
Revenues										2,155		630		702
Earnings (Loss)										494		96		-80
Our share of earnings (loss)										247		48		-40
Other Ventures [Member]
Schedule of Equity Method Investments [Line Items]
Revenues										1,792	[5]	5,994	[5]	8,790	[5]
Earnings (Loss)										4,835	[5]	176	[5]	10,032	[5]
Our share of earnings (loss)										$260	[5]	$33	[5]	$11,058	[5]
[1]	Fourth quarter 2014 results include pre-tax non-cash impairment charges of $30,591,000 for unproved leasehold interests and proved oil and gas properties.
[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 $1,621,000 are reflected as a reduction to our investment in unconsolidated ventures at year-end 2014.
[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. At year-end 2014, we no longer have an equity method investment in the Eleven venture.
[4]	Includes unrecognized basis difference of $1,517,000 which is reflected as a reduction of our investment in unconsolidated ventures at year-end 2014. 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.
[5]	In 2012, other ventures earnings include $5,307,000 related to a consolidated venture’s share of the gain associated with Round Rock Luxury Apartment's sale of Las Brisas. Our share of these earnings was $2,541,000 and we allocated $2,766,000 to net income attributable to noncontrolling interests.

Investment_In_Unconsolidated_V3

Investment In Unconsolidated Ventures - Summarized Income Statement Information (Footnotes) (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2014
Schedule of Equity Method Investments [Line Items]
Reduction in investment		$1,517
242, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Reduction in investment		1,621
Other Ventures [Member]
Schedule of Equity Method Investments [Line Items]
Earnings of other ventures related to consolidated ventures shares	5,307
Our share earnings of other ventures related to consolidated ventures shares	2,541
Our share of earnings allocated to noncontrolling interests	-2,766
Other Ventures [Member] | Minimum [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		25.00%
Other Ventures [Member] | Maximum [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		50.00%
Equity Method Investments [Member]
Schedule of Equity Method Investments [Line Items]
Long-term Debt, Current Maturities	37,966	65,795
Equity Method Investments [Member] | Non-recourse Debt [Member]
Schedule of Equity Method Investments [Line Items]
Long-term Debt, Current Maturities	$37,822	$42,566

Receivables_Receivables_Detail

Receivables - Receivables (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	$24,847	$39,278
Oil and gas joint interest billing receivables	5,738	3,896
Allowance for bad debts	-258	-26
Receivables, net	24,589	39,252
Loan secured by real estate [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	3,574	7,610
Other loans secured by real estate [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	1,737	7,987
Average Interest Rates	4.41%	5.00%
Oil and gas revenue accrual receivable [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	7,293	8,137
Other receivables and accrued interest [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables, gross	$6,505	$11,648

Receivables_Additional_Informa

Receivables - Additional Information (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts and Notes Receivables	$24,847	$39,278
Due period of notes receivable as secured by deed of trust	3 years
Loan secured by real estate [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts and Notes Receivables	3,574	7,610
Principal amount after reorganization	33,900
Interest accrue percentage till year three	9.00%
Interest accrue percentage year four	10.00%
Interest accrue percentage year five	12.00%
Forgiven interest rate	6.25%
Principal amount of loan received	11,304	14,315
Interest amount of loan received	634	1,872
Outstanding principal balance	4,394
Other loans secured by real estate [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts and Notes Receivables	1,737	7,987
Cibolo Canyons Project [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Area of Land	33
Cibolo Canyons Project [Member] | Prime Rate [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Loans Receivable, Basis Spread on Variable Rate	1.00%
Cibolo Canyons Project [Member] | Other loans secured by real estate [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts and Notes Receivables	6,160
Real Estate Property Sale Price	7,700
Real Estate Project - Colorado [Member] | Other loans secured by real estate [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts and Notes Receivables	824
San Joaquin River [Member] | Other loans secured by real estate [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts and Notes Receivables	$550

Receivables_Estimated_Accretab

Receivables - Estimated Accretable Yield (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Receivables [Abstract]
Beginning of period	$8,908	$25,149
Change in accretable yield due to change in timing of estimated cash flows	-166	-10,950
Interest income recognized	-7,903	-5,291
End of period	$839	$8,908

Debt_Schedule_of_Debt_Detail

Debt - Schedule of Debt (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Line of Credit Facility [Line Items]
Debt	$432,744	$357,407
6% Tangible Equity Units [Member]
Line of Credit Facility [Line Items]
Debt	17,154	25,619
Term Loan Facility [Member] | Senior Secured Credit Facility [Member]
Line of Credit Facility [Line Items]
Debt	0	200,000
Senior Notes [Member]
Line of Credit Facility [Line Items]
Debt	250,000	0
Convertible Debt [Member]
Line of Credit Facility [Line Items]
Debt	103,194	99,890
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	$46,996	$16,498

Debt_Debt_Detail

Debt - Debt (Detail)	0 Months Ended	12 Months Ended
	Feb. 26, 2013	Dec. 31, 2014	Dec. 31, 2013
Convertible Debt [Member]
Line of Credit Facility [Line Items]
Average interest rate		3.75%	3.75%
Debt Instrument, Maturity Date	1-Mar-20
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		3.17%	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		5.00%
Senior Notes [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Maturity Date	1-Jun-22
Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Expiration Date		15-May-17
Senior Secured Credit Facility [Member] | Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Average interest rate		4.17%	4.17%
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		14-Sep-17
Second Amended Senior Secured Credit Facility [Member] [Member] | Revolving Line of Credit [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Maturity Date		14-Sep-15
6% Tangible Equity Units [Member] | Senior Notes [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Expiration Date		15-Dec-16

Debt_Additional_Information_De

Debt - Additional Information (Detail) (USD $)	12 Months Ended			0 Months Ended		9 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Nov. 27, 2013	Feb. 26, 2013	Sep. 30, 2014
				Unit
Line of Credit Facility [Line Items]
Common stock, par value	$1	$1
Debt	$432,744,000	$357,407,000
Carrying value	192,678,000	99,476,000
Deferred Finance Costs, Net	15,168,000	7,896,000
Amortization of deferred financing fees	3,845,000	3,050,000	2,922,000
Debt Maturities 2015	49,535,000
Debt Maturities 2016	29,031,000
Debt Maturities 2017	984,000
Debt Maturities 2018	0
Debt Maturities 2019	0
Debt Maturities thereafter	353,194,000
Austin [Member]
Line of Credit Facility [Line Items]
Guest room hotel	413
Multi Family Property [Member] | Austin, Texas [Member]
Line of Credit Facility [Line Items]
Number Of Units Of Multifamily Project	257
Carrying value	53,382,000					53,917,000
Multi Family Property [Member] | Dallas, Texas [Member]
Line of Credit Facility [Line Items]
Number Of Units Of Multifamily Project	354
Carrying value	33,062,000
Multi Family Development Properties [Member]
Line of Credit Facility [Line Items]
Carrying value	44,145,000
Multi Family Development Properties [Member] | Texas [Member]
Line of Credit Facility [Line Items]
Carrying value	86,444,000
Senior Secured Credit Facility [Member]
Line of Credit Facility [Line Items]
DebtCovenantMinimumInterestCoverageRatio		150.00%
DebtCovenantLeverageRatio		40.00%
Amended Senior Secured Credit Facility [Domain]
Line of Credit Facility [Line Items]
Minimum liquidity required	125,000,000
Minimum effective leverage ratio exceeded	40.00%
DebtCovenantMinimumInterestCoverageLiquidity	300.00%
DebtCovenantMinimumInterestCoverageRatio	250.00%
DebtCovenantLeverageRatio	50.00%
6% Tangible Equity Units [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Face Amount				150,000,000
Units issued				6,000,000
Exercise price of unit				25
Common stock, par value				$1
Interest rate percentage				6.00%
Debt	17,154,000	25,619,000
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	0	200,000,000
Letter of Credit [Member]
Line of Credit Facility [Line Items]
Sublimit for letters of credit outstanding	15,415,000
Convertible Debt [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Face Amount					125,000,000
Debt Instrument, Maturity Date					1-Mar-20
Interest rate percentage					3.75%
Initial conversion rate					40.8351
Principal amount of initial conversion rate					1,000
Unamortized debt discount	21,806,000
Debt	103,194,000	99,890,000
Senior Notes [Member]
Line of Credit Facility [Line Items]
Debt Instrument, Maturity Date					1-Jun-22
Interest rate percentage	8.50%
Debt	250,000,000	0
Debt issuance cost	8,053,000
Senior Notes [Member] | 6% Tangible Equity Units [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Expiration Date	15-Dec-16
Face amount per unit, debt				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	30,712,000
Other Indebtedness [Member]
Line of Credit Facility [Line Items]
Debt	46,996,000	16,498,000
Other Indebtedness [Member] | Multi Family Property [Member] | Austin, Texas [Member]
Line of Credit Facility [Line Items]
Debt	23,936,000
Other Indebtedness [Member] | Multi Family Property [Member] | Dallas, Texas [Member]
Line of Credit Facility [Line Items]
Debt	19,117,000
Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity under term Loan facility	300,000,000	200,000,000
Line of Credit Facility, Expiration Date	15-May-17
Revolving Line Of Credit Facility Extension Option Term						two one-year extension options
Net unused borrowing capacity	284,585,000
Percentage Of Spread On Federal Funds Effective Rate	0.50%
Debt Instrument, Fee Amount	3,068,000
Minimum [Member] | 6% Tangible Equity Units [Member]
Line of Credit Facility [Line Items]
Units issued				6,547,800
Maximum [Member] | 6% Tangible Equity Units [Member]
Line of Credit Facility [Line Items]
Units issued				7,857,000
Over-Allotment Option [Member] | 6% Tangible Equity Units [Member]
Line of Credit Facility [Line Items]
Units issued				600,000
Over-Allotment Option [Member] | Senior Notes [Member]
Line of Credit Facility [Line Items]
Debt issuance cost	$6,250,000
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%

Fair_Value_Additional_Informat

Fair Value - Additional Information (Detail) (USD $)	3 Months Ended	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of Oil and Gas Properties	$30,591,000	$15,535,000
Asset impairments		15,934,000	1,790,000	0
Real Estate [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset impairments		$399,000

Fair_Value_Carrying_Value_of_A

Fair Value - Carrying Value of Assets (Detail) (Non-recurring [Member], USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Oil and Gas Properties [Member]
Non-Financial Assets and Liabilities:
Real estate	$3,655	$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	3,655	0
Real Estate [Member]
Non-Financial Assets and Liabilities:
Real estate	970	3,700
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	970	3,700
Real Estate [Member] | Level 3 [Member]
Non-Financial Assets and Liabilities:
Real estate	$0	$0

Fair_Value_Information_About_o

Fair Value - Information About our Fixed Rate Financial instruments not Measured at Fair Value (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	$432,744		$357,407
Senior Notes [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	250,000		0
Interest rate percentage	8.50%
Debt Instrument, Issuance Date	12-May-14
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Loan secured by real estate	3,574		7,610
Loan Secured by Real Estate Fair Value	4,859		18,025
Fixed rate debt, carrying value	-370,348	[1]	-126,640
Fixed rate debt, fair value	($359,131)	[1]	($118,634)
[1]	Year-end 2014 includes our $250,000,000 of 8.50% senior secured notes due 2022, issued May 12, 2014.

Capital_Stock_Detail

Capital Stock - (Detail) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2012	Dec. 31, 2013	Nov. 27, 2013	Feb. 26, 2013
Class of Stock [Line Items]
Number of shares repurchased	1,491,187
Value of share repurchased	$24,595	$1,409
Common Stock Repurchased Since Announcement Of Strategic Initiative	3,493,332
Value Of Common Stock Repurchased Since Announcement Of Strategic Initiative	54,159
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	1,364,000
Weighted average exercise price	$21.86
Weighted average remaining contractual term	5 years
Aggregate intrinsic value	643		6,433
Former Affiliated Entity [Member] | Stock Options [Member]
Class of Stock [Line Items]
Options to purchase shares of common stock	705,000
Weighted average exercise price	$26.15
Weighted average remaining contractual term	1 year
Aggregate intrinsic value	$30
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]
Preferred stock purchase right description	One-quarter of a preferred stock purchase right
Number of rights issued per share of common stock	0.25
Stockholders to purchase conditions description	One one-hundredth of a share of newly issued Series A Junior Participating Preferred Stock
Number of securities called by preferred stock purchase right	0.001
Preferred stock exercise price	$100
Minimum percentage of beneficial ownership to acquire exercisable rights	20.00%
Redemption price of rights	$0.00
Redemption time of rights	10 days
Expiry date of rights	11-Dec-17

Net_Income_per_Share_Earnings_

Net Income per Share - Earnings Attributable to Common Shareholders and Weighted Average Common Shares Outstanding (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Numerator:
Consolidated net income	$17,088	$35,061	$17,876
Less: Net income attributable to noncontrolling interest	-505	-5,740	-4,934
Earnings available for diluted earnings per share	16,583	29,321	12,942
Less: Undistributed net income allocated to participating securities	-3,018	-585	0
Earnings available to common shareholders for basic earnings per share	$13,565	$28,736	$12,942
Weighted average common shares outstanding - basic	35,317	35,365	35,214
Weighted average common shares upon conversion of participating securities	7,857	835	0
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	422	613	268
Weighted average common shares outstanding - diluted	43,596	36,813	35,482
Anti-dilutive awards excluded from diluted weighted average shares outstanding	2,238	1,803	2,713

Net_Income_per_Share_Additiona

Net Income per Share - Additional Information (Details) (USD $)	0 Months Ended
	Nov. 27, 2013	Dec. 31, 2014
	Unit
6% Tangible Equity Units [Member]
Debt Instrument [Line Items]
Stated interest rate on tangible equity units	6.00%
Units issued	6,000,000
Convertible Debt [Member]
Debt Instrument [Line Items]
Exercise price of unit		$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_Expens

Income Taxes - Income Tax Expense (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Current tax provision:
U.S. Federal	($5,444)	($6,004)	($11,834)
State and other	-1,569	-2,066	-2,171
Total	-7,013	-8,070	-14,005
Deferred tax provision:
U.S. Federal	-2,772	1,148	4,910
State and other	1,128	-286	1,079
Total	-1,644	862	5,989
Income tax expense	($8,657)	($7,208)	($8,016)

Income_Taxes_Reconciliation_of

Income Taxes - Reconciliation of Federal Statutory Rate to Effective Income Tax Rate on Continuing Operations (Detail)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Disclosure [Abstract]
Federal statutory rate	35.00%	35.00%	35.00%
State, net of federal benefit	1.00%	4.00%	5.00%
Recognition of previously unrecognized tax benefits	0.00%	-15.00%	0.00%
State rate change due to acquisition	0.00%	0.00%	-2.00%
Acquisition costs	0.00%	0.00%	4.00%
Noncontrolling interests	0.00%	-5.00%	-7.00%
Effective Income Tax Rate Reconciliation, Disposition of Asset, Percent	1.00%	0.00%	0.00%
Charitable contributions	-1.00%	0.00%	0.00%
Oil and gas percentage depletion	-2.00%	-2.00%	-5.00%
Other	0.00%	0.00%	1.00%
Effective tax rate	34.00%	17.00%	31.00%

Income_Taxes_Additional_Inform

Income Taxes - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Operating Loss Carryforwards [Line Items]
Recognition of previously unrecognized tax benefits	0.00%	15.00%	0.00%
Change in effective tax rate due to acquisition of Credo	0.00%	0.00%	-2.00%
Tax benefits not recognized for book purposes		$6,326,000
Recognized interest accrued related to unrecognized tax benefits	0	75,000	152,000
Accrued interest	0
Decrease in valuation allowance	9,000
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	7,500,000
Expiration date of operating loss carry forwards		31-Dec-31
State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating loss carry forwards	$18,000,000
Minimum [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Expiration date of operating loss carry forwards		31-Dec-15
Maximum [Member] | State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Expiration date of operating loss carry forwards		31-Dec-34

Income_Taxes_Significant_Compo

Income Taxes - Significant Components of Deferred Taxes (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Deferred Tax Assets:
Real estate	$79,244	$75,157
Employee benefits	17,352	17,902
Net operating loss carryforwards	3,012	3,076
Income producing properties	364	3,529
Oil and gas percentage depletion carryforwards	3,471	3,344
Accruals not deductible until paid	1,111	960
Gross deferred tax assets	104,554	103,968
Valuation allowance	-384	-375
Deferred tax asset net of valuation allowance	104,170	103,593
Deferred Tax Liabilities:
Oil and gas properties	-49,905	-46,966
Undeveloped land	-4,937	-5,961
Income producing properties	-7,816	-8,803
Timber	-888	-1,465
Gross deferred tax liabilities	-63,546	-63,195
Deferred Tax Assets, Net	$40,624	$40,398

Income_Taxes_Reconciliation_of1

Income Taxes - Reconciliation of Beginning and Ending Amount of Tax Benefits Not Recognized for Book Purposes (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Disclosure [Abstract]
Balance at beginning of year	$0	$5,831	$5,831
Reductions for tax positions of prior years	0	0	0
Reductions due to lapse of statute of limitations	0	-5,831	0
Balance at end of year	$0	$0	$5,831

Litigation_and_Environmental_C1

Litigation and Environmental Contingencies - Additional Information (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	acre
Commitments and Contingencies Disclosure [Abstract]
Area for which certificate of completion received	288
Portion of site for which certificate not received	80
Cost to complete remediation activities	$529
Asset Retirement Obligation	$1,807	$1,483	$1,360

Commitments_and_Other_Continge1

Commitments and Other Contingencies (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2008
				sqft
Operating Leased Assets [Line Items]
operating lease future payments, 2015	$3,308,000
operating lease future payments, 2016	3,111,000
operating lease future payments, 2016	3,101,000
operating lease future payments, 2018	2,165,000
operating lease future payments, 2019	571,000
operating lease future payments, thereafter	2,284,000
Office Facilities And Other Equipment [Member]
Operating Leased Assets [Line Items]
Lease expense	2,617,000	2,374,000	2,115,000
Ground Water Lease [Member]
Operating Leased Assets [Line Items]
Remaining years of timber lease	3 years
Timber land area taken on lease	20,000
Remaining contractual obligation of groundwater lease	1,514,000
Corporate Headquarters [Member]
Operating Leased Assets [Line Items]
Net Rentable Area				32,000
Remaining contractual obligation of groundwater lease	5,632,000
Other Office Locations [Member]
Operating Leased Assets [Line Items]
Remaining contractual obligation of groundwater lease	$6,262,000
Other Office Locations [Member] | Texas [Member]
Operating Leased Assets [Line Items]
Net Rentable Area	21,000
Other Office Locations [Member] | COLORADO
Operating Leased Assets [Line Items]
Net Rentable Area	10,000

Segment_Information_Additional

Segment Information - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
	Customer	Customer
	Segment
Segment Reporting [Abstract]
Number of business segments	3
Concentration Risk, Percentage	10.00%
Number of customer who contributed more than 10 percent of revenue	0	0

Segment_Information_Segment_Re

Segment Information - Segment Revenues and Earnings (Detail) (USD $)	3 Months Ended									12 Months Ended
	Dec. 31, 2014		Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Segment Reporting Information [Line Items]
Revenues	$80,316,000	[1]	$58,840,000	$83,013,000	$84,605,000	$98,388,000	$75,107,000	$60,079,000	$97,471,000	$306,774,000		$331,045,000		$172,591,000
Depreciation, depletion and amortization										41,715,000		29,980,000		18,926,000
Equity in earnings of unconsolidated ventures	4,720,000	[1]	2,016,000	958,000	991,000	2,133,000	3,125,000	2,566,000	913,000	8,685,000		8,737,000		14,469,000
Income (loss) before taxes										25,240,000		36,529,000		20,958,000
Total assets	1,258,199,000					1,172,152,000				1,258,199,000		1,172,152,000		918,434,000
Investment in unconsolidated ventures	65,005,000					41,147,000				65,005,000		41,147,000		41,546,000
Capital expenditures										138,798,000	[2]	107,897,000	[2]	24,151,000	[2]
Operating Segments [Member] | Real Estate [Member]
Segment Reporting Information [Line Items]
Revenues										213,112,000		248,011,000		120,115,000
Depreciation, depletion and amortization										3,741,000		3,117,000		4,340,000
Equity in earnings of unconsolidated ventures										8,068,000		8,089,000		13,897,000
Income (loss) before taxes										96,906,000		68,454,000		53,582,000
Total assets	654,774,000					582,802,000				654,774,000		582,802,000		588,137,000
Investment in unconsolidated ventures	65,005,000					41,147,000				65,005,000		41,147,000		41,546,000
Capital expenditures										28,980,000	[2]	7,265,000	[2]	1,093,000	[2]
Operating Segments [Member] | Oil and Gas [Member]
Segment Reporting Information [Line Items]
Revenues										84,300,000		72,313,000		44,220,000
Depreciation, depletion and amortization										29,442,000		19,552,000		4,987,000
Equity in earnings of unconsolidated ventures										586,000		592,000		509,000
Income (loss) before taxes										-22,686,000		18,859,000		26,608,000
Total assets	342,703,000					312,553,000				342,703,000		312,553,000		227,061,000
Investment in unconsolidated ventures	0					0				0		0		0
Capital expenditures										103,385,000	[2]	97,696,000	[2]	21,971,000	[2]
Operating Segments [Member] | Other Natural Resources [Member]
Segment Reporting Information [Line Items]
Revenues										9,362,000		10,721,000		8,256,000
Depreciation, depletion and amortization										497,000		651,000		1,254,000
Equity in earnings of unconsolidated ventures										31,000		56,000		63,000
Income (loss) before taxes										5,499,000		6,507,000		29,000
Total assets	22,531,000					23,478,000				22,531,000		23,478,000		24,066,000
Investment in unconsolidated ventures	0					0				0		0		0
Capital expenditures										5,817,000	[2]	2,720,000	[2]	292,000	[2]
Items Not Allocated To Segments [Member]
Segment Reporting Information [Line Items]
Revenues										0		0		0
Depreciation, depletion and amortization										8,035,000		6,660,000		8,345,000
Equity in earnings of unconsolidated ventures										0		0		0
Income (loss) before taxes										-54,479,000	[3]	-57,291,000	[3]	-59,261,000	[3]
Total assets	238,191,000					253,319,000				238,191,000		253,319,000		79,170,000
Investment in unconsolidated ventures	0					0				0		0		0
Capital expenditures										$616,000	[2]	$216,000	[2]	$795,000	[2]
[1]	Fourth quarter 2014 results include pre-tax non-cash impairment charges of $30,591,000 for unproved leasehold interests and proved oil and gas properties.
[2]	Consists of expenditures for oil and gas properties and equipment, commercial and income producing properties, property, plant and equipment and reforestation of timber.
[3]	Items not allocated to segments consist of: For the Year 2014 2013 2012 (In thousands)General and administrative expense$(21,229) $(20,597) $(25,176)Share-based compensation expense(3,417) (16,809) (14,929)Gain on sale of assets— — 16Interest expense(30,286) (20,004) (19,363)Other corporate non-operating income453 119 191 $(54,479) $(57,291) $(59,261)

Segment_Information_Items_Not_

Segment Information - Items Not Allocated to Segments (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Segment Reporting Information [Line Items]
Income (loss) before taxes	$25,240		$36,529		$20,958
Items Not Allocated To Segments [Member]
Segment Reporting Information [Line Items]
Income (loss) before taxes	-54,479	[1]	-57,291	[1]	-59,261	[1]
Items Not Allocated To Segments [Member] | General and Administrative Expense [Member]
Segment Reporting Information [Line Items]
Income (loss) before taxes	-21,229		-20,597		-25,176
Items Not Allocated To Segments [Member] | Share-based compensation expense [Member]
Segment Reporting Information [Line Items]
Income (loss) before taxes	-3,417		-16,809		-14,929
Items Not Allocated To Segments [Member] | Gain on sale of assets [Member]
Segment Reporting Information [Line Items]
Income (loss) before taxes	0		0		16
Items Not Allocated To Segments [Member] | Interest expense [Member]
Segment Reporting Information [Line Items]
Income (loss) before taxes	-30,286		-20,004		-19,363
Items Not Allocated To Segments [Member] | Other corporate non-operating income [Member]
Segment Reporting Information [Line Items]
Income (loss) before taxes	$453		$119		$191
[1]	Items not allocated to segments consist of: For the Year 2014 2013 2012 (In thousands)General and administrative expense$(21,229) $(20,597) $(25,176)Share-based compensation expense(3,417) (16,809) (14,929)Gain on sale of assets— — 16Interest expense(30,286) (20,004) (19,363)Other corporate non-operating income453 119 191 $(54,479) $(57,291) $(59,261)

Variable_Interest_Entities_Add

Variable Interest Entities - Additional Information (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Variable Interest Entity [Line Items]
Payments to Acquire Additional Interest in Subsidiaries	$7,971	$0	$0
Deferred Tax Assets, Net	40,624	40,398
Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Count of VIEs	4
Variable Interest Entity, Non consolidated, Carrying amount, Assets	64,311
Variable Interest Entity, Nonconsolidated, Carrying Amount, Liabilities	79,723
Variable Interest Entity, Financial or Other Support, Amount	4,415
Maximum Exposure to loss related to VIEs	3,597
Investment in VIEs	9,500
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	$30,667

Share_Based_Compensation_Compo

Share Based Compensation - Components of Share-Based Compensation Expense (Income) (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	$3,417	$16,809	$14,929
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	1,984	4,216	3,251
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	-25	538	2,154
Equity-settled awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	5,168	4,281	3,059
Cash Settled Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	($3,710)	$7,774	$6,465

Share_Based_Compensation_Share

Share Based Compensation - Share Based Compensation Expense Included in Operating Expense (Income) (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	$3,417	$16,809	$14,929
General and Administrative Expense [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	1,001	7,779	7,144
Other Operating Expenses [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation	$2,416	$9,030	$7,785

Share_Based_Compensation_Addit

Share Based Compensation - Additional Information (Detail) (USD $)	12 Months Ended			3 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award Accelerated Compensation Cost	$760,000	$590,000	$595,000
Unrecognized share-based compensation expense related to non-vested equity-settled awards, restricted stock and stock options	7,160,000
Weighted average period over which amount will be recognized	2 years
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures	215,561	137,943
Vesting of restricted stock awards and exercises of stock options, shares withheld	55,238	59,219
Payroll taxes on restricted stock and stock options	1,043,000	1,137,000	968,000
Fair value of awards settled in cash	3,467,000	7,237,000	5,299,000
Stock price of non-vested cash-settled awards	$15.40
Cash Settled Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Fair value of vested cash-settled awards	9,560,000
Aggregate current value of non-vested cash-settled awards	2,850,000
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	$12.54	$11.96	$11.38
Aggregate current value of non-vested cash-settled restricted stock units	458,000	580,000	866,000
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	0
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	86,000
Number of shares to be issued if stock price increases by fifty percent	129,000
Numbers of shares to be issued if stock price decreases by fifty percent	43,000
Equity-settled awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized share-based compensation expense related to non-vested equity-settled awards, restricted stock and stock options	5,975,000
Weighted average period over which amount will be recognized	2 years
Nonvested, weighted average grant date fair value	$19.24	$19.50	$18.99
Aggregate current value of non-vested cash-settled restricted stock units	710,000	581,000	409,000
Granted, Equivalent Units	512,000
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]
Unrecognized share-based compensation expense related to non-vested equity-settled awards, restricted stock and stock options	138,000
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	$17.56	$14.99	$16.95
Aggregate current value of non-vested cash-settled restricted stock units	17,000	47,000	211,000
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 Arrangement by Share-based Payment Award, Options, Vested in Period, Fair Value	21,000	1,355,000	429,000
Unrecognized share-based compensation expense related to non-vested equity-settled awards, restricted stock and stock options	1,047,000
Weighted average period over which amount will be recognized	2 years
Period over or after performance stock unit vest	4 years
Share-based Compensation Arrangement by Share-based Payment Award, Expiration Period	10 years
Intrinsic value of options exercised	568,000	562,000	0
Options Outstanding	1,861,000	2,006,000
Weighted average exercise price	$21.86
Weighted Average Remaining Contractual Term	6 years	7 years
Aggregate intrinsic value	643,000	6,433,000
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	$18.49	$17.90	$17.03
Aggregate current value of non-vested cash-settled restricted stock units	185,000	233,000	350,000
Granted, Equivalent Units	93,000
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
Granted, Equivalent Units	270,000
Performance Stock Units Psu [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance Awards to be issued	0
Performance Stock Units Psu [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance Awards to be issued	540,000
Temple Inland Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Intrinsic value of options exercised				$1,132,000
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	56,000
Weighted average exercise price	$27.03
Weighted Average Remaining Contractual Term	1 year

Share_Based_Compensation_Summa

Share Based Compensation - Summarized Activity of Cash Settled Restricted Stock Unit Awards (Detail) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2012
Stock Appreciation Rights (SARs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Balance at beginning of year	580,000	866,000
Granted, Equivalent Units	0
Forfeited, Equivalent Units	-6,000
Balance at end of period	458,000	866,000
Non-vested at beginning of year, Weighted Average Grant Date Fair Value	$11.96	$11.38
Forfeited, Weighted Average Grant Date Fair Value	$17.80
Non-vested at end of period, Weighted Average Grant Date Fair Value	$12.54	$11.38
Cash Settled Restricted Stock Unit [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Balance at beginning of year	233,000	350,000
Granted, Equivalent Units	93,000
Vested, Equivalent Units	-132,000
Forfeited, Equivalent Units	-9,000
Balance at end of period	185,000	350,000
Non-vested at beginning of year, Weighted Average Grant Date Fair Value	$17.90	$17.03
Granted, Weighted Average Grant Date Fair Value	$18.96
Vested, Weighted Average Grant Date Fair Value	$17.86
Forfeited, Weighted Average Grant Date Fair Value	$17.42
Non-vested at end of period, Weighted Average Grant Date Fair Value	$18.49	$17.03

Share_Based_Compensation_Summa1

Share Based Compensation - Summarized Activity of Cash-Settled Stock Appreciation Rights (Detail) (Stock Appreciation Rights (SARs) [Member], USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Stock Appreciation Rights (SARs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Outstanding, Weighted Average Remaining Contractual Terms	4 years	5 years
Balance at beginning of year	580,000	866,000
Granted, Rights Outstanding	0
Exercised, Rights Outstanding	-116,000
Forfeited, Rights Outstanding	-6,000
Balance at end of period	458,000	580,000
Exercisable at end of period, Rights Outstanding	458,000
Non-vested at beginning of year, Weighted Average Grant Date Fair Value	$11.96	$11.38
Granted, Weighted Average Exercise Price	$0
Exercised, Weighted Average Exercise Price	$9.41
Forfeited, Weighted Average Grant Date Fair Value	$17.80
Non-vested at end of period, Weighted Average Grant Date Fair Value	$12.54	$11.96
Exercisable at end of period, Weighted Average Exercise Price	$12.54
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Exercisable Weighted Average Remaining Contractual Term	4 years
Aggregate Intrinsic Value	$1,732	$5,400
Exercisable at end of period, Aggregate Intrinsic Value	$1,732

Share_Based_Compensation_Equit

Share Based Compensation - Equity-Settled Awards (Detail) (Equity-settled awards [Member], USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2012
Equity-settled awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Balance at beginning of year	581,000	409,000
Granted, Equivalent Units	512,000
Vested, Equivalent Units	-259,000
Forfeited, Equivalent Units	-124,000
Balance at end of period	710,000	409,000
Non-vested at beginning of year, Weighted Average Grant Date Fair Value	$19.50	$18.99
Granted, Weighted Average Grant Date Fair Value	$19.18
Vested, Weighted Average Grant Date Fair Value	$20.01
Forfeited, Weighted Average Grant Date Fair Value	$18.58
Non-vested at end of period, Weighted Average Grant Date Fair Value	$19.24	$18.99

Share_Based_Compensation_Summa2

Share Based Compensation - Summarized Activity of Restricted Stock Awards (Detail) (Restricted Stock [Member], USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2012
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Balance at beginning of year	47,000	211,000
Granted, Equivalent Units	0
Vested, Equivalent Units	-20,000
Forfeited, Equivalent Units	-10,000
Balance at end of period	17,000	211,000
Non-vested at beginning of year, Weighted Average Grant Date Fair Value	$14.99	$16.95
Granted, Weighted Average Grant Date Fair Value	$0
Vested, Weighted Average Grant Date Fair Value	$12.74
Forfeited, Weighted Average Grant Date Fair Value	$15.02
Non-vested at end of period, Weighted Average Grant Date Fair Value	$17.56	$16.95

Share_Based_Compensation_Summa3

Share Based Compensation - Summarized Activity of Stock Option Awards (Detail) (Stock Options [Member], USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Balance at beginning of year, Options Outstanding	2,006,000
Granted, Options Outstanding	0
Exercised, Options Outstanding	-56,000
Forfeited, Options Outstanding	-89,000
Balance at end of period, Options Outstanding	1,861,000	2,006,000
Exercisable at end of period, Options Outstanding	1,364,000
Balance at beginning of year, Weighted Average Exercise Price	$20.30
Granted, Weighted Average Exercise Price	$0
Exercised, Weighted Average Exercise Price	$9.64
Forfeited, Weighted Average Exercise Price	$17.65
Balance at end of period, Weighted Average Exercise Price	$20.74	$20.30
Exercisable at end of period, Weighted Average Exercise Price	$21.86
Weighted Average Remaining Contractual Term	6 years	7 years
Exercisable at end of period, Weighted Average Remaining Contractual Term	5 years
Aggregate intrinsic value	$643	$6,433
Exercisable at end of period, Aggregate Intrinsic Value	$620

Share_Based_Compensation_Fair_

Share Based Compensation - Fair Value of Stock Options Using Black-Scholes Option Pricing Model (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Expected stock price volatility	66.80%	60.20%
Risk-free interest rate	1.40%	1.30%
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	$11.47	$9.22

Retirement_Plans_Additional_In

Retirement Plans - Additional Information (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Compensation and Retirement Disclosure [Abstract]
Expense of defined contribution retirement plans	$1,651	$1,456	$1,393
Unfunded liability for supplemental plan	$715	$586

Supplemental_Oil_and_Gas_Discl2

Supplemental Oil and Gas Disclosures (Unaudited) - Additional Information (Detail) (USD $)	12 Months Ended						0 Months Ended	1 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Sep. 28, 2012	Sep. 28, 2012
	Well		Well		Well
Supplemental Oil And Gas Reserve Information [Line Items]
Percentage of acquired outstanding common shares							100.00%	100.00%
New well addition	106		88		27
Credo [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Cash transaction per share							$14.50	$14.50
Business acquisition cost							$146,445,000
Outstanding debt paid								$8,770,000
Crude Oil and NGL [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Average spot price	94.99		96.91		94.71
Natural Gas in Mmbtu [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Average spot price	4.35		3.67		2.76
Consolidated Entities [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates	608,000		800,000
Equity Method Investee [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Downward revisions in natural gas reserves for consolidated entities			330,000
Oil [Member] | Consolidated Entities [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Extensions and discoveries	2,191,000	[1]	3,085,000	[1]	86,000	[1]
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place	105,000	[1]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates	608,000	[1]	182,000	[1]	45,000	[1]
Oil [Member] | Equity Method Investee [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates	0	[1]	0	[1]	0	[1]
Oil [Member] | New PDP Reserves [Member] | Consolidated Entities [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Extensions and discoveries	694,000
Oil [Member] | New PUD Reserves [Member] | Consolidated Entities [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Extensions and discoveries	913,000
Natural Gas [Member] | Consolidated Entities [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Extensions and discoveries	774,000		2,046,000		241,000
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place	218,000
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates	293,000		1,243,000		-2,163,000
Natural Gas [Member] | Equity Method Investee [Member]
Supplemental Oil And Gas Reserve Information [Line Items]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates	-382,000		7,000		-390,000
[1]	Includes natural gas liquids (NGLs).

Supplemental_Oil_and_Gas_Discl3

Supplemental Oil and Gas Disclosures (Unaudited) - Summary of Estimated Quantities of Proved Developed Oil and Natural Gas Reserves (Detail)	12 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2010
	bbl		bbl		bbl		bbl
Oil [Member]
Reserve Quantities [Line Items]
Proved developed reserves	5,269,000	[1]	3,893,000	[1]	2,416,000	[1]
Proved undeveloped reserves	2,403,000	[1]	1,931,000	[1]	804,000	[1]
Ending Balance	7,672,000	[1]	5,824,000	[1]	3,220,000	[1]
Natural Gas [Member]
Reserve Quantities [Line Items]
Proved developed reserves	12,599,000		13,717,000		13,020,000
Proved undeveloped reserves	1,801,000		2,245,000		1,274,000
Ending Balance	14,400,000		15,962,000		14,294,000
Consolidated Entities [Member]
Reserve Quantities [Line Items]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates	608,000		800,000
Consolidated Entities [Member] | Oil [Member]
Reserve Quantities [Line Items]
Beginning Balance	5,824,000	[1]	3,220,000	[1]			1,064,000	[1]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates	608,000	[1]	182,000	[1]	45,000	[1]
Extensions and discoveries	2,191,000	[1]	3,085,000	[1]	86,000	[1]
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place	-105,000	[1]
Acquisitions	85,000	[1]	35,000	[1]	2,396,000	[1]
Production	-931,000	[1]	-698,000	[1]	-371,000	[1]
Ending Balance	7,672,000	[1]	5,824,000	[1]	3,220,000	[1]	1,064,000	[1]
Consolidated Entities [Member] | Natural Gas [Member]
Reserve Quantities [Line Items]
Beginning Balance	13,630,000		11,722,000				8,203,000
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates	293,000		1,243,000		-2,163,000
Extensions and discoveries	774,000		2,046,000		241,000
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place	-218,000
Acquisitions	31,000		531,000		7,109,000
Production	-1,861,000		-1,912,000		-1,668,000
Ending Balance	12,649,000		13,630,000		11,722,000		8,203,000
Equity Method Investee [Member] | Oil [Member]
Reserve Quantities [Line Items]
Beginning Balance	0	[1]	0	[1]			0	[1]
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates	0	[1]	0	[1]	0	[1]
Production	0	[1]	0	[1]	0	[1]
Ending Balance	0	[1]	0	[1]	0	[1]	0	[1]
Equity Method Investee [Member] | Natural Gas [Member]
Reserve Quantities [Line Items]
Beginning Balance	2,332,000		2,572,000				3,283,000
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates	-382,000		7,000		-390,000
Production	-199,000		-247,000		-321,000
Ending Balance	1,751,000		2,332,000		2,572,000		3,283,000
[1]	Includes natural gas liquids (NGLs).

Supplemental_Oil_and_Gas_Discl4

Supplemental Oil and Gas Disclosures (Unaudited) - Capitalized Cost Related to Oil and Natural Gas Producing Activities (Detail) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Capitalized Costs Relating To Oil And Gas Producing Activities [Line Items]
Total costs	$311,745	$255,582
Consolidated Entities [Member]
Capitalized Costs Relating To Oil And Gas Producing Activities [Line Items]
Unproved oil and gas properties	90,446	100,320
Proved oil and gas properties	221,299	155,262
Total costs	311,745	255,582
Less accumulated depreciation, depletion and amortization	-48,252	-22,941
Net capitalized costs	$263,493	$232,641

Supplemental_Oil_and_Gas_Discl5

Supplemental Oil and Gas Disclosures (Unaudited) - Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2010
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	$165,616	$136,853	$107,956	$56,206
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Entity's Share of Equity Method Investees' Standardized Discounted Future Net Cash Flows	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	665,657	544,098	322,098
Costs Incurred, Acquisition of Oil and Gas Properties with Proved Reserves	2,001	0	0
Costs Incurred, Acquisition of Unproved Oil and Gas Properties	25,666	35,806	4,418
Exploration costs	39,399	10,486	1,752
Development costs	40,277	54,538	15,938
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities	107,343	100,830	22,108
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Production Costs	271,735	231,801	104,441
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Income Tax Expense	106,002	77,361	50,350
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Net Cash Flows	287,920	234,936	167,307
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Ten Percent Annual Discount for Estimated Timing of Cash Flows	124,079	99,383	60,764
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves	$163,841	$135,553	$106,543	$52,698

Supplemental_Oil_and_Gas_Discl6

Supplemental Oil and Gas Disclosures (Unaudited) - Estimates of Future Cash Flows from Proved Developed Oil and Natural Gas Reserves (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2010
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Standardized measure of discounted future net cash flows	$165,616	$136,853	$107,956	$56,206
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Entity's Share of Equity Method Investees' Standardized Discounted Future Net Cash Flows	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	665,657	544,098	322,098
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Production Costs	-271,735	-231,801	-104,441
Future income tax expenses	-106,002	-77,361	-50,350
Future net cash flows	287,920	234,936	167,307
10% annual discount for estimated timing of cash flows	-124,079	-99,383	-60,764
Standardized measure of discounted future net cash flows	163,841	135,553	106,543	52,698
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	6,186	4,765	5,125
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Production Costs	-664	-512	-551
Future income tax expenses	-2,098	-1,616	-1,738
Future net cash flows	3,424	2,637	2,836
10% annual discount for estimated timing of cash flows	-1,649	-1,337	-1,423
Standardized measure of discounted future net cash flows	$1,775	$1,300	$1,413	$3,508

Supplemental_Oil_and_Gas_Discl7

Supplemental Oil and Gas Disclosures (Unaudited) - Changes in Standardized Measure of Discounted Future Net Cash Flow (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2010
Schedule Of Changes In Standardized Measure Of Discounted Future Net Cash Flows [Line Items]
Beginning Balance	$136,853	$107,956		$56,206
Changes resulting from:
Net change in sales prices and production costs	507	23,837	-8,206
Net change in future development costs	1,308	-2,897	-1,834
Sales of oil and gas, net of production costs	-63,979	-57,360	-32,364
Net change due to extensions and discoveries	58,228	54,539	5,596
Increase Due to Purchases of Minerals in Place	2,778	1,160	86,013
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place	-5,804
Net change due to revisions of quantity estimates	14,960	8,679	-2,236
Previously estimated development costs incurred	15,497	4,124	1,007
Accretion of discount	18,277	13,768	7,778
Standardized Measure of Discounted Future Net Cash Flow of Proved Oil and Gas Reserves, Other	4,313	-749
Net change in income taxes	-17,322	-16,204	-4,004
Aggregate change for the year	28,763	28,897	51,750
Ending Balance	165,616	136,853	107,956	56,206
Consolidated Entities [Member]
Schedule Of Changes In Standardized Measure Of Discounted Future Net Cash Flows [Line Items]
Beginning Balance	135,553	106,543		52,698
Changes resulting from:
Net change in sales prices and production costs	-1,064	23,422	-5,709
Net change in future development costs	1,308	-2,897	-1,834
Sales of oil and gas, net of production costs	-63,192	-56,559	-31,732
Net change due to extensions and discoveries	58,228	54,539	5,596
Increase Due to Purchases of Minerals in Place	2,778	1,160	86,013
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place	-5,804
Net change due to revisions of quantity estimates	15,303	8,673	-2,254
Previously estimated development costs incurred	15,497	4,124	1,007
Accretion of discount	18,067	13,540	7,377
Standardized Measure of Discounted Future Net Cash Flow of Proved Oil and Gas Reserves, Other	4,198	-718
Net change in income taxes	-17,031	-16,274	-4,619
Aggregate change for the year	28,288	29,010	53,845
Ending Balance	163,841	135,553	106,543	52,698
Equity Method Investee [Member]
Schedule Of Changes In Standardized Measure Of Discounted Future Net Cash Flows [Line Items]
Beginning Balance	1,300	1,413		3,508
Changes resulting from:
Net change in sales prices and production costs	1,571	415	-2,497
Net change in future development costs	0	0	0
Sales of oil and gas, net of production costs	-787	-801	-632
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	-343	6	18
Previously estimated development costs incurred	0	0	0
Accretion of discount	210	228	401
Standardized Measure of Discounted Future Net Cash Flow of Proved Oil and Gas Reserves, Other	115	-31
Net change in income taxes	-291	70	615
Aggregate change for the year	475	-113	-2,095
Ending Balance	$1,775	$1,300	$1,413	$3,508

Supplemental_Oil_and_Gas_Discl8

Supplemental Oil and Gas Disclosures (Unaudited) - Information About Results of Operations of Oil and Natural Gas Interests (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Consolidated entities
Results of operations	($19,703)	$8,490	$12,236
Consolidated Entities [Member]
Consolidated entities
Revenues	82,919	69,036	36,204	[1]
Production costs	-19,727	-12,477	-4,472	[1]
Exploration costs	-17,416	-10,486	-1,754	[1]
Depreciation, depletion, amortization	-29,442	-19,552	-4,905	[1]
Results of Operations, Impairment of Oil and Gas Properties	32,665	473	0	[1]
Oil and gas administrative expenses	-17,000	-14,407	-8,332	[1]
Results of Operations, Accretion of Asset Retirement Obligations	-121	-94	-26	[1]
Income tax expenses	-13,398	3,471	4,841
Results of operations	-20,054	8,076	11,874	[1]
Equity Method Investee [Member]
Consolidated entities
Royalty revenues	786	801	770
Production costs	-105	-123	-138
Oil and gas administrative expenses	-95	-86	-123
Income tax expenses	-235	-178	-147
Results of operations	$351	$414	$362
[1]	2012 includes only three months of operations from Credo due to our third quarter 2012 acquisition.

Summary_of_Quarterly_Results_o2

Summary of Quarterly Results of Operations - Summary of Quarterly Results of Operations (Detail) (USD $)	3 Months Ended									12 Months Ended
	Dec. 31, 2014		Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Quarterly Financial Information Disclosure [Abstract]
Impairment of Oil and Gas Properties	$30,591,000									$15,535,000
Total revenues	80,316,000	[1]	58,840,000	83,013,000	84,605,000	98,388,000	75,107,000	60,079,000	97,471,000	306,774,000	331,045,000	172,591,000
Gross profit	-6,259,000	[1]	19,606,000	33,261,000	35,025,000	39,181,000	32,608,000	22,463,000	35,899,000
Operating income (loss)	-16,783,000	[1]	12,716,000	26,942,000	15,883,000	22,891,000	10,612,000	3,554,000	9,520,000	38,758,000	46,577,000	27,165,000
Equity in earnings of unconsolidated ventures	4,720,000	[1]	2,016,000	958,000	991,000	2,133,000	3,125,000	2,566,000	913,000	8,685,000	8,737,000	14,469,000
Income (loss) before taxes	-18,713,000	[1]	7,994,000	22,799,000	13,665,000	23,160,000	9,965,000	2,109,000	7,035,000	25,745,000	42,269,000	25,892,000
Net income (loss) attributable to Forestar Group Inc.	($11,800,000)	[1]	$5,227,000	$14,822,000	$8,334,000	$12,999,000	$11,830,000	$541,000	$3,951,000	$16,583,000	$29,321,000	$12,942,000
Net income (loss) per share - basic	($0.34)	[1]	$0.12	$0.34	$0.20	$0.34	$0.33	$0.02	$0.11	$0.38	$0.81	$0.37
Net income (loss) per share - diluted	($0.34)	[1]	$0.12	$0.34	$0.19	$0.33	$0.33	$0.02	$0.11	$0.38	$0.80	$0.36
[1]	Fourth quarter 2014 results include pre-tax non-cash impairment charges of $30,591,000 for unproved leasehold interests and proved oil and gas properties.

Schedule_III_Consolidated_Real

Schedule III - Consolidated Real Estate and Accumulated Depreciation (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Real Estate and Accumulated Depreciation [Line Items]
Encumbrances	$62,396
Land	389,035
Buildings & Improvements	57,996
Improvements less Cost of Sales and Other	150,128
Carrying Costs	9,974	[1]
Land & Land Improvements	468,521
Buildings & Improvements	138,612
Total	607,133		547,530	545,370	592,322
Accumulated depreciation	-31,377		-28,066	-28,220	-26,955
Entitled Developed and Under Development Projects [Member]
Real Estate and Accumulated Depreciation [Line Items]
Encumbrances	3,943
Land	290,166
Improvements less Cost of Sales and Other	21,133
Carrying Costs	9,974	[1]
Land & Land Improvements	321,273
Total	321,273
Entitled Developed and Under Development Projects [Member] | Other Country [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	32,304
Improvements less Cost of Sales and Other	-22,418
Carrying Costs	1,271	[1]
Land & Land Improvements	11,157
Total	11,157
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	7,045
Land & Land Improvements	14,353
Total	14,353
Date of Construction	2006
Date Acquired	2006
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	555
Land & Land Improvements	3,556
Total	3,556
Date of Construction	2006
Date Acquired	2005
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	2,046
Carrying Costs	188	[1]
Land & Land Improvements	4,983
Total	4,983
Date of Construction	2002
Date Acquired	2002
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	-1,436
Land & Land Improvements	2,442
Total	2,442
Date of Construction	2005
Date Acquired	2005
Entitled Developed and Under Development Projects [Member] | Georgia [Member] | Coweta County [Member] | Corinth Landing [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	607
Improvements less Cost of Sales and Other	585
Land & Land Improvements	1,192
Total	1,192
Entitled Developed and Under Development Projects [Member] | Georgia [Member] | Coweta County [Member] | Coweta South Industrial Park [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	532
Improvements less Cost of Sales and Other	476
Land & Land Improvements	1,008
Total	1,008
Entitled Developed and Under Development Projects [Member] | Georgia [Member] | Coweta County [Member] | Genesee [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	480
Improvements less Cost of Sales and Other	1,176
Land & Land Improvements	1,656
Total	1,656
Entitled Developed and Under Development Projects [Member] | Georgia [Member] | Dawson County [Member] | Woodlands At Burt Creek [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	71
Improvements less Cost of Sales and Other	1,670
Land & Land Improvements	1,741
Total	1,741
Entitled Developed and Under Development Projects [Member] | Georgia [Member] | Cherokee County [Member] | Heron Pond [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	1,104
Improvements less Cost of Sales and Other	1,285
Land & Land Improvements	2,389
Total	2,389
Date Acquired	2012
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	129
Land & Land Improvements	3,093
Total	3,093
Date Acquired	2012
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	1,478
Carrying Costs	239	[1]
Land & Land Improvements	5,594
Total	5,594
Date Acquired	2013
Entitled Developed and Under Development Projects [Member] | Tennessee [Member] | Williamson County [Member] | Morgan Farms [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	6,841
Improvements less Cost of Sales and Other	917
Carrying Costs	166	[1]
Land & Land Improvements	7,924
Total	7,924
Date Acquired	2013
Entitled Developed and Under Development Projects [Member] | Tennessee [Member] | Williamson County [Member] | Weatherford Estates [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	856
Improvements less Cost of Sales and Other	201
Land & Land Improvements	1,057
Total	1,057
Date Acquired	2014
Entitled Developed and Under Development Projects [Member] | Tennessee [Member] | Wilson County [Member] | Beckwith Crossing [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	1,294
Improvements less Cost of Sales and Other	185
Land & Land Improvements	1,479
Total	1,479
Date Acquired	2014
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	6,465
Carrying Costs	358	[1]
Land & Land Improvements	10,436
Total	10,436
Date of Construction	2001
Date Acquired	2001
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	12,347
Carrying Costs	161	[1]
Land & Land Improvements	21,234
Total	21,234
Date of Construction	1999
Date Acquired	1999
Entitled Developed and Under Development Projects [Member] | Texas [Member] | Bexar County [Member] | Cibolo Canyons [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	25,569
Improvements less Cost of Sales and Other	26,137
Carrying Costs	1,607	[1]
Land & Land Improvements	53,313
Total	53,313
Date of Construction	2004
Date Acquired	1986
Entitled Developed and Under Development Projects [Member] | Texas [Member] | Calhoun County [Member] | Caracol [Member]
Real Estate and Accumulated Depreciation [Line Items]
Encumbrances	3,869
Land	8,603
Improvements less Cost of Sales and Other	3,355
Carrying Costs	2,047	[1]
Land & Land Improvements	14,005
Total	14,005
Date of Construction	2006
Date Acquired	2006
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	-634
Carrying Costs	180	[1]
Land & Land Improvements	8,497
Total	8,497
Date Acquired	2012
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	-8,687
Carrying Costs	635	[1]
Land & Land Improvements	1,852
Total	1,852
Date of Construction	2000
Date Acquired	2000
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	1,294
Land & Land Improvements	3,471
Total	3,471
Date Acquired	2013
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	4,386
Land & Land Improvements	11,668
Total	11,668
Date of Construction	2007
Date Acquired	2007
Entitled Developed and Under Development Projects [Member] | Texas [Member] | Collin County [Member] | Village Park [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	6,550
Improvements less Cost of Sales and Other	-6,579
Carrying Costs	81	[1]
Land & Land Improvements	52
Total	52
Date Acquired	2012
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	941
Carrying Costs	175	[1]
Land & Land Improvements	3,037
Total	3,037
Date of Construction	2006
Date Acquired	2005
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	1,278
Carrying Costs	49	[1]
Land & Land Improvements	14,149
Total	14,149
Date of Construction	2007
Date Acquired	2007
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	-825
Land & Land Improvements	26,848
Total	26,848
Date of Construction	2000
Date Acquired	1999
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	351
Land & Land Improvements	1,578
Total	1,578
Date Acquired	2014
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	-1,884
Carrying Costs	436	[1]
Land & Land Improvements	4,407
Total	4,407
Date of Construction	2006
Date Acquired	2005
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	-169
Land & Land Improvements	4,100
Total	4,100
Date Acquired	2012
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	3
Land & Land Improvements	4,807
Total	4,807
Date Acquired	2012
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	358
Carrying Costs	90	[1]
Land & Land Improvements	3,927
Total	3,927
Date Acquired	2012
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	-5,833
Land & Land Improvements	3,117
Total	3,117
Date Acquired	2011
Entitled Developed and Under Development Projects [Member] | Texas [Member] | Harris County [Member] | City Park [Member]
Real Estate and Accumulated Depreciation [Line Items]
Encumbrances	74
Land	3,946
Improvements less Cost of Sales and Other	-1,485
Carrying Costs	1,641	[1]
Land & Land Improvements	4,102
Total	4,102
Date of Construction	2002
Date Acquired	2001
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	47
Land & Land Improvements	5,392
Total	5,392
Date Acquired	2014
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	3,104
Land & Land Improvements	15,960
Total	15,960
Date Acquired	2007
Entitled Developed and Under Development Projects [Member] | Texas [Member] | Hood County [Member] | Harbor Lakes [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	3,514
Improvements less Cost of Sales and Other	-1,970
Carrying Costs	312	[1]
Land & Land Improvements	1,856
Total	1,856
Date of Construction	2000
Date Acquired	1998
Entitled Developed and Under Development Projects [Member] | Texas [Member] | Montgomery County [Member] | Woodtrace [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	8,622
Improvements less Cost of Sales and Other	-8,621
Land & Land Improvements	1
Total	1
Date Acquired	2014
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	9,473
Land & Land Improvements	21,553
Total	21,553
Date Acquired	2006
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	-1,625
Land & Land Improvements	1,262
Total	1,262
Date Acquired	2012
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	2,330
Land & Land Improvements	3,727
Total	3,727
Date Acquired	2012
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	293	[1]
Land & Land Improvements	1,527
Total	1,527
Date Acquired	2006
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	13	[1]
Land & Land Improvements	2,856
Total	2,856
Date of Construction	2003
Date Acquired	2001
Undeveloped Land Type [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	57,541
Improvements less Cost of Sales and Other	35,641
Land & Land Improvements	93,182
Total	93,182
Undeveloped Land Type [Member] | California [Member] | Los Angeles [Member] | Land In Entitlement Process [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	3,969
Improvements less Cost of Sales and Other	18,122
Land & Land Improvements	22,091
Total	22,091
Date Acquired	1997
Undeveloped Land Type [Member] | Georgia [Member] | Coweta County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	454
Improvements less Cost of Sales and Other	380
Land & Land Improvements	834
Total	834
Undeveloped Land Type [Member] | Georgia [Member] | Coweta County [Member] | Land In Entitlement Process [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	644
Improvements less Cost of Sales and Other	222
Land & Land Improvements	866
Total	866
Undeveloped Land Type [Member] | Georgia [Member] | Dawson County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	2,157
Improvements less Cost of Sales and Other	1,485
Land & Land Improvements	3,642
Total	3,642
Undeveloped Land Type [Member] | Georgia [Member] | Bartow County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	3,551
Improvements less Cost of Sales and Other	48
Land & Land Improvements	3,599
Total	3,599
Undeveloped Land Type [Member] | Georgia [Member] | Carroll County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	4,397
Improvements less Cost of Sales and Other	107
Land & Land Improvements	4,504
Total	4,504
Undeveloped Land Type [Member] | Georgia [Member] | Carroll County [Member] | Land In Entitlement Process [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	9,006
Improvements less Cost of Sales and Other	2,159
Land & Land Improvements	11,165
Total	11,165
Undeveloped Land Type [Member] | Georgia [Member] | Cherokee County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	3,322
Improvements less Cost of Sales and Other	92
Land & Land Improvements	3,414
Total	3,414
Undeveloped Land Type [Member] | Georgia [Member] | Cherokee County [Member] | Land In Entitlement Process [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	2,340
Improvements less Cost of Sales and Other	566
Land & Land Improvements	2,906
Total	2,906
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	26
Land & Land Improvements	2,774
Total	2,774
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	4
Land & Land Improvements	3,019
Total	3,019
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
Undeveloped Land Type [Member] | Georgia [Member] | Pickens County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	2,235
Improvements less Cost of Sales and Other	28
Land & Land Improvements	2,263
Total	2,263
Undeveloped Land Type [Member] | Georgia [Member] | Polk County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	2,354
Land & Land Improvements	2,354
Total	2,354
Undeveloped Land Type [Member] | Texas [Member] | Bexar County [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Improvements less Cost of Sales and Other	3,038
Land & Land Improvements	3,038
Total	3,038
Undeveloped Land Type [Member] | Texas [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	1,145
Land & Land Improvements	1,830
Total	1,830
Undeveloped Land Type [Member] | Texas [Member] | Other Country [Member] | Undeveloped Land [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	8,666
Improvements less Cost of Sales and Other	8,171
Land & Land Improvements	16,837
Total	16,837
Undeveloped Land Type [Member] | Texas [Member] | Other Country [Member] | Land In Entitlement Process [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	504
Improvements less Cost of Sales and Other	48
Land & Land Improvements	552
Total	552
Income Producing Properties [Member]
Real Estate and Accumulated Depreciation [Line Items]
Encumbrances	58,453
Land	41,328
Buildings & Improvements	57,996
Improvements less Cost of Sales and Other	93,354
Carrying Costs	0	[1]
Land & Land Improvements	54,066
Buildings & Improvements	138,612
Total	192,678
Accumulated depreciation	-31,377
Income Producing Properties [Member] | Tennessee [Member] | Davidson County [Member] | Westmont [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	6,607
Improvements less Cost of Sales and Other	1,068
Land & Land Improvements	7,675
Total	7,675
Date Acquired	2014
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	9,424
Land & Land Improvements	15,203
Total	15,203
Date Acquired	2012
Income Producing Properties [Member] | Texas [Member] | Dallas County [Member] | Cedar Hill [Member]
Real Estate and Accumulated Depreciation [Line Items]
Encumbrances	19,117
Land	2,526
Improvements less Cost of Sales and Other	30,767
Land & Land Improvements	2,526
Buildings & Improvements	30,767
Total	33,293
Accumulated depreciation	231
Date of Construction	2011
Date Acquired	2011
Income Producing Properties [Member] | Texas [Member] | Hood County [Member] | Harbor Lakes Golf Club [Member]
Real Estate and Accumulated Depreciation [Line Items]
Buildings & Improvements	1,446
Improvements less Cost of Sales and Other	608
Buildings & Improvements	2,054
Total	2,054
Accumulated depreciation	-1,508
Date of Construction	2000
Date Acquired	1998
Income Producing Properties [Member] | Texas [Member] | Travis County [Member] | Radisson Hotel And Suites [Member]
Real Estate and Accumulated Depreciation [Line Items]
Encumbrances	15,400
Buildings & Improvements	10,603
Improvements less Cost of Sales and Other	49,170
Land & Land Improvements	0
Buildings & Improvements	59,773
Total	59,773
Accumulated depreciation	-29,062
Income Producing Properties [Member] | Texas [Member] | Travis County [Member] | Eleven [Member]
Real Estate and Accumulated Depreciation [Line Items]
Encumbrances	23,936
Land	7,940
Buildings & Improvements	45,947
Improvements less Cost of Sales and Other	71
Land & Land Improvements	7,940
Buildings & Improvements	46,018
Total	53,958
Accumulated depreciation	576
Date of Construction	2013
Date Acquired	2014
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	654
Land & Land Improvements	11,856
Total	11,856
Date Acquired	2014
Income Producing Properties [Member] | Texas [Member] | Travis County [Member] | West Austin [Member]
Real Estate and Accumulated Depreciation [Line Items]
Land	7,274
Improvements less Cost of Sales and Other	1,592
Land & Land Improvements	8,866
Total	$8,866
Date Acquired	2014
[1]	Includes natural gas liquids (NGLs).

Schedule_III_Reconciliation_of

Schedule III - Reconciliation of Real Estate and Accumulated Depreciation (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
SEC Schedule III, Real Estate and Accumulated Depreciation Disclosure [Abstract]
Beginning balance	$547,530	$545,370	$592,322
Amounts capitalized	214,184	111,428	143,711
Amounts retired or adjusted	-154,581	-109,268	-190,663
Ending balance	607,133	547,530	545,370
Beginning balance	-28,066	-28,220	-26,955
Depreciation expense	-3,319	-2,185	-3,640
Amounts retired or adjusted	8	2,339	2,375
Ending balance	($31,377)	($28,066)	($28,220)