Forestar Group - 10-Q quarterly report FY2015 Q3

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

_________________________________________________________

FORM 10-Q

_________________________________________________________



x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2015



¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission File Number: 001-33662

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FORESTAR GROUP INC.

(Exact Name of Registrant as Specified in Its Charter)

_________________________________________________________



Delaware		26-1336998
(State or Other Jurisdiction of Incorporation or Organization)		(I.R.S. Employer Identification No.)

6300 Bee Cave Road, Building Two, Suite 500, Austin, Texas 78746

(Address of Principal Executive Offices, Including Zip Code)

(512) 433-5200

(Registrant’s Telephone Number, Including Area Code)

_________________________________________________________

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. x Yes ¨ No

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). x Yes ¨ No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):



Large accelerated filer	¨		Accelerated filer	x

Non-accelerated filer	¨	(Do not check if a smaller reporting company)	Smaller reporting company	¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). ¨ Yes x No

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.



Title of Each Class		Number of Shares Outstanding as of November 2, 2015
Common Stock, par value $1.00 per share		33,616,255

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FORESTAR GROUP INC.

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PART I—FINANCIAL INFORMATION

Item 1. Financial Statements

FORESTAR GROUP INC.

Consolidated Balance Sheets

(Unaudited)



	Third Quarter-End			Year-End
	2015			2014
	(In thousands, except share data)
ASSETS
Cash and cash equivalents	$	92,640		$	170,127
Real estate, net	620,813			575,756
Oil and gas properties and equipment, net	121,775			263,493
Investment in unconsolidated ventures	85,325			65,005
Timber	8,320			8,315
Receivables, net	13,212			24,589
Income taxes receivable	3,878			7,503
Prepaid expenses	2,714			6,000
Property and equipment, net	10,727			11,627
Deferred tax asset, net	1,118			40,624
Goodwill and other intangible assets	63,440			66,131
Other assets	17,254			19,029
TOTAL ASSETS	$	1,041,216		$	1,258,199
LIABILITIES AND EQUITY
Accounts payable	$	13,976		$	20,400
Accrued employee compensation and benefits	8,532			8,323
Accrued property taxes	7,839			5,966
Accrued interest	7,607			3,451
Earnest money deposits	10,172			10,045
Other accrued expenses	21,573			35,729
Other liabilities	27,817			31,799
Debt	435,295			432,744
TOTAL LIABILITIES	532,811			548,457
COMMITMENTS AND CONTINGENCIES
EQUITY
Forestar Group Inc. shareholders’ equity:
Common stock, par value $1.00 per share, 200,000,000 authorized shares, 36,946,603 issued at third quarter-end 2015 and year-end 2014	36,947			36,947
Additional paid-in capital	562,591			558,945
Retained earnings (Accumulated deficit)	(39,880		)	167,001
Treasury stock, at cost, 3,329,060 shares at third quarter-end 2015 and 3,485,278 shares at year-end 2014	(53,085		)	(55,691		)
Total Forestar Group Inc. shareholders’ equity	506,573			707,202
Noncontrolling interests	1,832			2,540
TOTAL EQUITY	508,405			709,742
TOTAL LIABILITIES AND EQUITY	$	1,041,216		$	1,258,199

Please read the notes to consolidated financial statements.

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FORESTAR GROUP INC.

Consolidated Statements of Income and Comprehensive Income

(Unaudited)



	Third Quarter						First Nine Months
	2015			2014			2015			2014
	(In thousands, except per share amounts)
REVENUES
Real estate sales and other	$	18,369		$	23,067		$	68,630		$	122,738
Commercial and income producing properties	9,588			9,378			31,566			30,360
Real estate	27,957			32,445			100,196			153,098
Oil and gas	13,485			24,145			42,835			66,076
Other natural resources	1,726			2,250			5,372			7,284
	43,168			58,840			148,403			226,458
COSTS AND EXPENSES
Cost of real estate sales and other	(9,588		)	(10,662		)	(33,840		)	(60,145		)
Cost of commercial and income producing properties	(6,780		)	(9,391		)	(22,020		)	(28,117		)
Cost of oil and gas producing activities	(95,553		)	(18,470		)	(177,236		)	(48,016		)
Cost of other natural resources	(819		)	(711		)	(2,599		)	(2,288		)
Other operating	(13,963		)	(12,860		)	(45,665		)	(43,187		)
General and administrative	(9,467		)	(5,140		)	(22,510		)	(17,141		)
	(136,170		)	(57,234		)	(303,870		)	(198,894		)
GAIN (LOSS) ON SALE OF ASSETS	(1,749		)	11,110			265			27,977
OPERATING INCOME (LOSS)	(94,751		)	12,716			(155,202		)	55,541
Equity in earnings of unconsolidated ventures	2,909			2,016			11,538			3,965
Interest expense	(8,315		)	(8,634		)	(25,851		)	(21,507		)
Other non-operating income	62			1,896			1,762			6,459
INCOME (LOSS) BEFORE TAXES	(100,095		)	7,994			(167,753		)	44,458
Income tax benefit (expense)	(64,236		)	(2,755		)	(39,133		)	(15,464		)
CONSOLIDATED NET INCOME (LOSS)	(164,331		)	5,239			(206,886		)	28,994
Less: Net (income) loss attributable to noncontrolling interests	115			(12		)	5			(611		)
NET INCOME (LOSS) ATTRIBUTABLE TO FORESTAR GROUP INC.	$	(164,216	)	$	5,227		$	(206,881	)	$	28,383
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING
Basic	34,299			35,498			34,248			35,437
Diluted	34,299			43,868			34,248			43,750
NET INCOME (LOSS) PER COMMON SHARE
Basic	$	(4.79	)	$	0.12		$	(6.04	)	$	0.66
Diluted	$	(4.79	)	$	0.12		$	(6.04	)	$	0.65
TOTAL COMPREHENSIVE INCOME (LOSS)	$	(164,216	)	$	5,227		$	(206,881	)	$	28,383

Please read the notes to consolidated financial statements.

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FORESTAR GROUP INC.

Consolidated Statements of Cash Flows

(Unaudited)



	First Nine Months
	2015			2014
	(In thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
Consolidated net income (loss)	$	(206,886	)	$	28,994
Adjustments:
Depreciation, depletion and amortization	36,780			29,109
Change in deferred income taxes	39,106			10,649
Equity in earnings of unconsolidated ventures	(11,538		)	(3,965		)
Distributions of earnings of unconsolidated ventures	7,343			2,817
Share-based compensation	5,531			4,523
Real estate cost of sales	33,575			59,251
Dry hole and unproved leasehold impairment charges	46,722			11,541
Real estate development and acquisition expenditures, net	(81,055		)	(82,864		)
Reimbursements from utility and improvement districts	8,285			8,554
Other changes in real estate	338			3,148
Changes in deferred income	(191		)	102
Asset impairments	91,146			94
Gain on sale of assets	(265		)	(27,977		)
Other	2,243			1,603
Changes in:
Notes and accounts receivable	9,395			(6,300		)
Prepaid expenses and other	3,106			4,232
Accounts payable and other accrued liabilities	(2,300		)	(3,249		)
Income taxes	3,625			(3,876		)
Net cash provided by (used for) operating activities	(15,040		)	36,386
CASH FLOWS FROM INVESTING ACTIVITIES:
Property, equipment, software, reforestation and other	(10,882		)	(13,583		)
Oil and gas properties and equipment	(47,043		)	(65,661		)
Acquisition of partner's interest in unconsolidated multifamily venture, net of cash	—			(20,155		)
Investment in unconsolidated ventures	(23,908		)	(5,016		)
Proceeds from sales of assets	13,571			19,885
Return of investment in unconsolidated ventures	7,783			1,601
Net cash used for investing activities	(60,479		)	(82,929		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from issuance of senior secured notes, net	—			241,947
Payments of debt	(7,527		)	(222,468		)
Additions to debt	7,105			17,169
Deferred financing fees	(153		)	(3,114		)
Distributions to noncontrolling interests, net	(703		)	(1,070		)
Purchase of noncontrolling interests	—			(7,971		)
Exercise of stock options	31			1,197
Payroll taxes on issuance of stock-based awards	(722		)	(1,024		)
Excess income tax benefit from share-based compensation	1			176
Net cash provided by (used for) financing activities	(1,968		)	24,842

Net decrease in cash and cash equivalents	(77,487		)	(21,701		)
Cash and cash equivalents at beginning of period	170,127			192,307
Cash and cash equivalents at end of period	$	92,640		$	170,606

Please read the notes to consolidated financial statements.

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FORESTAR GROUP INC.

Notes to Consolidated Financial Statements

(Unaudited)

Note 1—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 eliminate all material intercompany accounts and transactions. Noncontrolling interests in consolidated pass-through entities are recognized before income taxes.

We prepare our unaudited interim financial statements in accordance with U.S. generally accepted accounting principles and Securities and Exchange Commission requirements for interim financial statements. As a result, they do not include all the information and disclosures required for complete financial statements. However, in our opinion, all adjustments considered necessary for a fair presentation have been included. Such adjustments consist only of normal recurring items unless otherwise noted. We make estimates and assumptions about future events. Actual results can, and probably will, differ from those we currently estimate including those principally 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. These interim operating results are not necessarily indicative of the results that may be expected for the entire year. For further information, please read the financial statements included in our 2014 Annual Report on Form 10-K.

Note 2—New and Pending Accounting Pronouncements

Pending Accounting Standards

In May 2014, the FASB issued Accounting Standards Update (ASU) 2014-09, Revenue from Contracts with Customers (Topic 606), requiring an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The updated standard will replace most existing revenue recognition guidance in U.S. GAAP when it becomes effective and permits the use of either the retrospective or cumulative effect transition method. Early adoption is not permitted. The updated standard becomes effective for annual and interim periods beginning after December 15, 2016. In July 2015, the FASB decided to defer the effective date of the new standard by one year. This deferral results in the new standard being effective after December 15, 2017. We have not yet selected a transition method and we are currently evaluating the effect that the updated standard will have on our earnings, financial position and disclosures.

In February 2015, the FASB issued ASU 2015-02, Consolidation: Amendments to the Consolidation Analysis (Topic 810), requiring entities to evaluate whether they should consolidate certain legal entities. All legal entities are subject to reevaluation under the revised consolidation model. The revised consolidation model: (1) modifies the evaluation of whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities, (2) eliminates the presumption that a general partner should consolidate a limited partnership, (3) affects the consolidation analysis of reporting entities that are involved with VIEs, and (4) provides a scope exception from consolidation guidance for reporting entities with interests in certain legal entities. The updated standard is effective for financial statements issued for annual and interim periods beginning after December 15, 2015. Early adoption is permitted. The updated standard may be applied retrospectively or using a modified retrospective approach by recording a cumulative-effect adjustment to equity as of the beginning of the fiscal year of adoption. We are currently evaluating the effect that the updated standard will have on our earnings, financial position and disclosures.

In April 2015, the FASB issued ASU 2015-03, Interest – Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs, as part of its initiative to reduce complexity in accounting standards. To simplify presentation of debt issuance costs, the amendments in this update require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. In August 2015, the FASB issued ASU 2015-15, Interest-Imputation of Interest (Subtopic 835-30), Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements - Amendments to SEC Paragraphs Pursuant to Staff Announcement at June 18, 2015 EITF Meeting (SEC Update), which allows an entity to defer and present debt issuance costs as an asset and subsequently amortize the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. The updated standards are effective for financial statements issued for annual and interim periods beginning after December 15, 2015. The updated standards are not expected to materially impact our financial position or disclosures.

In April 2015, the FASB issued ASU 2015-05, Customer's Accounting for Fees Paid in a Cloud Computing Arrangement (Subtopic 350-40), in order to provide clarification on whether a cloud computing arrangement includes a software license. If a

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software license is included, the customer should account for the license consistent with its accounting of other software licenses. If a software license is not included, the arrangement should be accounted for as a service contract. The update is effective for reporting periods beginning after December 15, 2015. Early adoption is permitted. We are currently evaluating the effect that the updated standard will have on our financial position and disclosures.

In June 2015, the FASB issued ASU 2015-10, Technical Corrections and Updates. The amendments in this update cover a wide range of topics in the codification and are generally categorized as follows: Amendments Related to Differences between Original Guidance and the Codification; Guidance Clarification and Reference Corrections; Simplification; and, Minor Improvements. The amendments are effective for fiscal years and interim periods within those fiscal years, beginning after December 15, 2015. Early adoption is permitted. The adoption of this standard is not expected to impact our financial position or results of operations.

Note 3—Real Estate

Real estate consists of:



	Third Quarter-End 2015							Year-End 2014
	Carrying Value		Accumulated Depreciation			Net Carrying Value		Carrying Value		Accumulated Depreciation			Net Carrying Value
	(In thousands)
Entitled, developed and under development projects	$	359,532	$	—		$	359,532	$	321,273	$	—		$	321,273
Undeveloped land (includes land in entitlement)	93,824		—			93,824		93,182		—			93,182
Commercial
Radisson Hotel	62,693		(28,396		)	34,297		59,773		(29,062		)	30,711
Harbor Lakes golf course and country club	—		—			—		2,054		(1,508		)	546
Income producing properties
Eleven	53,906		(2,312		)	51,594		53,958		(576		)	53,382
Midtown	34,952		(1,399		)	33,553		33,293		(231		)	33,062
Dillon ^(a)	18,120		—			18,120		15,203		—			15,203
Music Row ^(a)	8,483		—			8,483		7,675		—			7,675
Downtown Edge	12,335		—			12,335		11,856		—			11,856
West Austin	9,075		—			9,075		8,866		—			8,866
	$	652,920	$	(32,107	)	$	620,813	$	607,133	$	(31,377	)	$	575,756

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^(a)	Construction in progress at third quarter-end 2015.

Our estimated costs of assets for which we expect to be reimbursed by utility and improvement districts were $67,925,000 at third quarter-end 2015 and $65,212,000 at year-end 2014, including $21,438,000 at third quarter-end 2015 and $31,913,000 at year-end 2014 related to our Cibolo Canyons project near San Antonio, Texas. In first nine months 2015, we have collected $7,860,000 in reimbursements that were previously submitted to these districts. At third quarter-end 2015, our inception to-date submitted and approved reimbursements for the Cibolo Canyons project were $54,376,000 of which we have collected $34,703,000. These costs are principally for water, sewer and other infrastructure assets that we have incurred and submitted or will submit to utility or improvement districts for approval and reimbursement. We expect to be reimbursed by utility and improvement districts when these districts achieve adequate tax basis or otherwise have funds available to support payment.

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Note 4—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 follows:



	Third Quarter-End			Year-End
	2015			2014
	(In thousands)
Unproved leasehold interests	$	44,387		$	90,446
Proved oil and gas properties	133,246			221,299
Total costs	177,633			311,745
Less: accumulated depreciation, depletion and amortization	(55,858		)	(48,252		)
	$	121,775		$	263,493

We review unproved oil and gas properties for impairment based on our current exploration plans and proved oil and gas properties by comparing the expected undiscounted future cash flows at a producing field level to the unamortized capitalized cost of the asset.

In third quarter 2015, we recognized $81,240,000 in non-cash impairment charges of which $65,382,000 is related to our proved oil and gas properties, primarily in North Dakota, Nebraska and Kansas and $15,858,000 is related to our unproved leasehold interests primarily in North Dakota. These non-cash impairment charges are a result of continued decline in oil prices and our current exploration plans. West Texas Intermediate (WTI) oil prices (the principal benchmark price for our oil sales), declined approximately 24 percent during third quarter 2015. Impairment charges are included in cost of oil and gas producing activities on our consolidated statements of income and comprehensive income.

Third quarter 2015 non-cash impairment charges included $1,361,000 of write-down associated with certain producing properties that met the assets held for sale criteria. Carrying value of these assets was adjusted to fair value and $1,534,000 were reclassified from oil and gas properties to assets held for sale which is included in other assets on our consolidated balance sheet. Upon classification as held for sale, long-lived assets are no longer depreciated or depleted, and a measurement for impairment is performed to identify and expense any excess of carrying value over fair value less estimated costs to sell.

In first nine months 2015, we recognized non-cash impairment charges of $36,768,000 on our unproved leasehold interests and $90,417,000 on our proved properties principally due to a significant decline in oil prices, drilling results, a change in our plans to develop acreage and increased likelihood that certain non-core oil and gas assets will be sold. Dry hole costs in first nine months 2015 were $9,952,000, which includes a $9,674,000 charge in second quarter 2015 primarily associated with an exploratory well in Oklahoma. In addition, in second quarter 2015 we expensed $917,000 of capitalized costs related to pre-drilling activities associated with non-core oil and gas properties in Oklahoma.

In first nine months 2015, we recorded a net loss of ($1,320,000) on the sale of 27,662 net mineral acres leased from others and the disposition of 29 gross (5 net) producing oil and gas wells in Nebraska, Texas, Colorado, North Dakota and Oklahoma for total sales proceeds of $13,111,000.

Note 5—Goodwill and Other Intangible Assets

Carrying value of goodwill and other intangible assets follows:



	Third Quarter-End		Year-End
	2015		2014
	(In thousands)
Goodwill	$	61,452	$	63,423
Identified intangibles, net	1,988		2,708
	$	63,440	$	66,131

Goodwill related to our oil and gas properties is $57,578,000 and $59,549,000 at third quarter-end 2015 and year-end 2014. Goodwill associated with our water resources initiatives is $3,874,000 at third quarter-end 2015 and year-end 2014. The change in goodwill for oil and gas properties is related to goodwill allocated to properties sold or held for sale in first nine months 2015.

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Identified intangibles include $1,681,000 in indefinite lived groundwater leases associated with our water resources initiatives and $307,000 related to patents with definite lives associated with the Calliope Gas Recovery System, a process to increase natural gas production.

Note 6—Equity

A reconciliation of changes in equity at third quarter-end 2015 follows:



	Forestar Group Inc.			Noncontrolling Interests			Total
	(In thousands)
Balance at year-end 2014	$	707,202		$	2,540		$	709,742
Net income (loss)	(206,881		)	(5		)	(206,886		)
Distributions to noncontrolling interests	—			(703		)	(703		)
Other (primarily share-based compensation)	6,252			—			6,252
	$	506,573		$	1,832		$	508,405

Note 7—Investment in Unconsolidated Ventures

At third quarter-end 2015, we have ownership interests in 20 ventures that we account for using the equity method.

Combined summarized balance sheet information for our ventures accounted for using the equity method follows:



	Venture Assets				Venture Borrowings^(a)				Venture Equity						Our Investment
	Third Quarter-End		Year-End		Third Quarter-End		Year-End		Third Quarter-End			Year-End			Third Quarter-End		Year-End
	2015		2014		2015		2014		2015			2014			2015		2014
	(In thousands)
242, LLC ^(b)	$	27,647	$	33,021	$	—	$	6,940	$	25,822		$	21,789		$	12,239	$	10,098
CL Ashton Woods, LP ^(c)	8,453		13,269		—		—		5,671			11,453			2,620		6,015
CL Realty, LLC	8,246		7,960		—		—		8,084			7,738			4,042		3,869
CREA FMF Nashville LLC ^(b)	57,193		40,014		49,960		29,660		4,780			5,987			4,309		5,516
Elan 99, LLC	25,572		10,070		5,726		1		15,885			9,643			14,297		8,679
FOR/SR Forsyth LLC	6,300		—		—		—		6,300			—			5,670		—
FMF Littleton LLC	43,828		26,953		15,665		—		24,585			24,435			6,324		6,287
FMF Peakview LLC	48,984		43,638		29,426		23,070		16,924			17,464			3,467		3,575
HM Stonewall Estates, Ltd ^(c)	3,054		3,750		—		669		3,054			3,081			1,822		1,752
LM Land Holdings, LP ^(c)	33,397		25,561		8,015		4,448		23,679			18,500			11,033		9,322
MRECV DT Holdings LLC	3,899		—		—		—		3,899			—			3,510		—
MRECV Edelweiss LLC	2,000		—		—		—		2,000			—			1,800		—
MRECV Juniper Ridge LLC	1,796		—		—		—		1,796			—			1,616		—
Miramonte Boulder Pass, LLC	12,429		—		5,360		—		5,533			—			5,403		—
PSW Communities, LP	14,060		16,045		6,880		10,515		6,557			4,415			4,123		3,924
Temco Associates, LLC	5,813		11,756		—		—		5,232			11,556			2,616		5,778
Other ventures^(d)	6,605		8,453		22,956		26,944		(31,306		)	(25,614		)	434		190
	$	309,276	$	240,490	$	143,988	$	102,247	$	128,495		$	110,447		$	85,325	$	65,005

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Combined summarized income statement information for our ventures accounted for using the equity method follows:



	Venture Revenues								Venture Earnings (Loss)												Our Share of Earnings (Loss)
	Third Quarter				First Nine Months				Third Quarter						First Nine Months						Third Quarter						First Nine Months
	2015		2014		2015		2014		2015			2014			2015			2014			2015			2014			2015			2014
	(In thousands)
242, LLC ^(b)	$	2,884	$	88	$	20,583	$	1,563	$	1,161		$	(32	)	$	9,034		$	448		$	597		$	(15	)	$	4,642		$	236
CL Ashton Woods, LP ^(c)	3,958		790		6,369		1,859		1,341			277			2,719			573			1,849			373			3,405			826
CL Realty, LLC	205		413		674		1,240		103			294			346			846			52			147			174			423
CREA FMF Nashville LLC ^(b)	442		—		477		—		(991		)	—			(1,207		)	(25		)	(991		)	—			(1,207		)	(25		)
Elan 99, LLC	—		—		—		—		—			—			(2		)	—			—			—			(2		)	—
FMF Littleton LLC	6		—		6		—		(152		)	—			(152		)	—			(38		)	—			(38		)	—
FMF Peakview LLC	628		3		1,280		3		(286		)	(109		)	(1,020		)	(261		)	(58		)	(21		)	(204		)	(52		)
FOR/SR Forsyth LLC	—		—		—		—		—			—			—			—			—			—			—			—
HM Stonewall Estates, Ltd ^(c)	921		292		2,590		1,727		480			91			1,292			613			157			36			730			245
LM Land Holdings, LP^(c)	1,857		4,604		8,154		13,897		1,391			3,397			5,179			10,368			423			1,200			1,710			3,097
MRECV DT Holdings LLC	—		—		—		—		167			—			167			—			—			—			—			—
MRECV Edelweiss LLC	—		—		—		—		125			—			125			—			65			—			65			—
MRECV Juniper Ridge LLC	—		—		—		—		105			—			105			—			—			—			—			—
Miramonte Boulder Pass, LLC	—		—		—		—		(92		)	—			(141		)	—			(46		)	—			(71		)	—
PSW Communities, LP	5,145		—		21,214		—		613			(11		)	3,141			(231		)	127			(9		)	1,088			(204		)
Temco Associates, LLC	8,019		79		9,163		793		1,618			42			2,077			158			809			21			1,039			79
Other ventures^(d)	71		2,427		3,772		3,546		242			386			(16		)	(454		)	(37		)	284			207			(660		)
	$	24,136	$	8,696	$	74,282	$	24,628	$	5,825		$	4,335		$	21,647		$	12,035		$	2,909		$	2,016		$	11,538		$	3,965

_____________________


^(a)	Total includes current maturities of $72,637,000 at third quarter-end 2015, of which $40,902,000 is non-recourse to us, and $65,795,000 at year-end 2014, of which $42,566,000 is non-recourse to us.


^(b)	Includes unamortized deferred gains on real estate contributed by us to ventures. We recognize deferred gains as income as real estate is sold to third parties. Deferred gains of $1,496,000 are reflected as a reduction to our investment in unconsolidated ventures at third quarter-end 2015.


^(c)	Includes unrecognized basis difference of $588,000 which is reflected as a reduction of our investment in unconsolidated ventures at third quarter-end 2015. The difference will be accreted as income or expense over the life of the investment and included in our share of earnings (loss) from the respective ventures.


^(d)	Our investment in other ventures reflects our ownership interests, excluding venture losses that exceed our investment where we are not obligated to fund those losses. Please read Note 16—Variable Interest Entities for additional information.

In first nine months 2015, we invested $23,908,000 in these ventures and received $15,126,000 in distributions. In first nine months 2014, we invested $5,016,000 in these ventures and received $4,418,000 in distributions. Distributions include both return of investments and distribution of earnings.

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Note 8—Receivables

Receivables consist of:



	Third Quarter-End			Year-End
	2015			2014
	(In thousands)
Oil and gas revenue accruals	$	5,825		$	7,293
Other receivables and accrued interest	4,146			6,505
Oil and gas joint interest billing receivables	1,439			5,738
Other loans secured by real estate, average interest rates of 11.12% at third quarter-end 2015 and 4.41% at year-end 2014	2,045			1,737
Loan secured by real estate	—			3,574
	13,455			24,847
Allowance for bad debts	(243		)	(258		)
	$	13,212		$	24,589

In second quarter 2011, we acquired a non-performing loan that was secured by a lien on developed and undeveloped real estate located near Houston designated for single-family residential and commercial development. In first quarter 2015, the loan was paid in full and we received principal payments of $4,394,000 and interest payments of $49,000.

Estimated accretable yield follows:



	Third Quarter-End
	2015
	(In thousands)
Beginning of period (year-end 2014)	$	839
Change in accretable yield due to change in timing of estimated cash flows	30
Interest income recognized (in first nine months 2015)	(869		)
End of period	$	—

Other loans secured by real estate generally are secured by a deed of trust and due within three years.

Note 9—Debt

Debt consists of:



	Third Quarter-End		Year-End
	2015		2014
	(In thousands)
8.50% senior secured notes due 2022	$	250,000	$	250,000
3.75% convertible senior notes due 2020, net of discount	105,672		103,194
6.00% tangible equity unit notes, net of discount	10,899		17,154
Secured promissory notes — average interest rates of 3.19% at third quarter-end 2015 and 3.17% at year-end 2014	15,400		15,400
Other indebtedness — interest rates ranging from 2.25% to 5.50%	53,324		46,996
	$	435,295	$	432,744

Our debt agreements contain financial covenants customary for such agreements including minimum levels of interest coverage and limitations on leverage. On September 30, 2015, we received a waiver of the consolidated tangible net worth maintenance covenant requirement of our senior credit facility for third quarter 2015, and amended the consolidated tangible net worth maintenance covenant requirement to an amount equal to 80 percent of the actual consolidated tangible net worth as calculated using the September 30, 2015 financial statements. The amendment provides us with additional flexibility given the on-going volatility and continued decline in oil prices, which resulted in approximately $81,240,000 of additional non-cash asset impairment charges in the oil and gas segment in third quarter 2015. At third quarter-end 2015, we were in compliance with the financial covenants of these agreements.

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The revolving line of credit includes a $100,000,000 sublimit for letters of credit, of which $16,184,000 is outstanding at third quarter-end 2015. Total borrowings under our senior secured credit facility (including the face amount of letters of credit) may not exceed a borrowing base formula. At third quarter-end 2015, we had $283,816,000 in net unused borrowing capacity under our senior secured 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.

At third quarter-end 2015, secured promissory notes represent a $15,400,000 loan collateralized by a 413 guest room hotel located in Austin with a carrying value of $34,297,000. Other indebtedness principally represents $48,103,000 of senior secured loans for two wholly-owned multifamily properties, our 257-unit multifamily project in Austin and our 354-unit multifamily property near Dallas. The combined carrying value of these two multifamily properties is $85,147,000 at third quarter-end 2015.

At third quarter-end 2015 and year-end 2014, we have $12,407,000 and $15,168,000 in unamortized deferred financing fees which are included in other assets. Amortization of deferred financing fees was $2,992,000 and $3,089,000 in first nine months 2015 and 2014 and is included in interest expense.

Note 10—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, oil and gas properties, assets held for sale, goodwill and other intangible assets, which are measured for impairment.

In first nine months 2015, we recognized proved oil and gas properties non-cash impairment charges of $90,417,000 principally due to a significant decline in oil and gas prices and an increased likelihood that certain non-core oil and gas assets will be sold. The fair value of these properties was determined using Level 3 inputs and the income valuation method. We used a discount rate of ten percent as of third quarter-end 2015 which is commensurate with current market and risk conditions associated with realizing the expected cash flows projected for these investments. Fair value of assets held for sale was based on net realizable value less cost to sell. Fair value of certain unproved leasehold interests that were impaired was based on market comparables.

In first nine months 2015, we recognized real estate non-cash asset impairment of $729,000, of which $504,000 was recognized in first quarter 2015 related to a residential development with golf course and country club property located near Fort Worth which was sold in April 2015 and $225,000 was recognized in second quarter 2015 related to an owned project near Atlanta where the remaining lots were sold in August 2015.

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Non-financial assets measured at fair value on a non-recurring basis are as follows:



	Third Quarter-End 2015								Year-End 2014
	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
Proved oil and gas properties	$	—	$	—	$	80,551	$	80,551	$	—	$	—	$	3,655	$	3,655
Unproved leasehold interests	$	—	$	1,226	$	11,489	$	12,715	$	—	$	—	$	—	$	—
Assets held for sale - oil and gas properties	$	—	$	1,534	$	—	$	1,534	$	—	$	—	$	—	$	—

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:



	Third Quarter-End 2015						Year-End 2014
	Carrying Amount			Fair Value			Carrying Amount			Fair Value			Valuation Technique
	(In thousands)
Loan secured by real estate	$	—		$	—		$	3,574		$	4,859		Level 2
Fixed rate debt	$	(366,571	)	$	(357,857	)	$	(370,348	)	$	(359,131	)	Level 2

Note 11—Capital Stock

In first quarter 2015, we accelerated the expiration date of our shareholder rights plan from December 11, 2017 to March 13, 2015, resulting in termination of the plan.

Please read Note 17—Share-Based and Long-Term Incentive Compensation for information about additional shares of common stock that could be issued under terms of our share-based compensation plans.

At third quarter-end 2015, personnel of former affiliates held options to purchase 501,000 shares of our common stock. The options have a weighted average exercise price of $28.62 and a weighted average remaining contractual term of one year. At third quarter-end 2015, the options have an aggregate intrinsic value of $0.

Note 12—Net Income (Loss) 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 (Units) are participating securities. Per share amounts are computed by dividing earnings available to common shareholders by the weighted average shares outstanding during each period. In periods with a net loss, no such adjustment is made to earnings as the holders of the participating securities have no obligation to fund losses.

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Due to a net loss in third quarter and first nine months 2015, as the effect of potentially dilutive securities would be anti-dilutive, basic and diluted loss per share are the same. The computations of basic and diluted earnings per share are as follows:



	Third Quarter						First Nine Months
	2015			2014			2015			2014
	(In thousands)
Numerator:
Consolidated net income (loss)	$	(164,331	)	$	5,239		$	(206,886	)	$	28,994
Less: Net (income) loss attributable to noncontrolling interest	115			(12		)	5			(611		)
Earnings (loss) available for diluted earnings per share	$	(164,216	)	$	5,227		$	(206,881	)	$	28,383
Less: Undistributed net income allocated to participating securities	—			(947		)	—			(5,151		)
Earnings (loss) available to common shareholders for basic earnings per share	$	(164,216	)	$	4,280		$	(206,881	)	$	23,232

Denominator:
Weighted average common shares outstanding — basic	34,299			35,498			34,248			35,437
Weighted average common shares upon conversion of participating securities ^(a)	—			7,857			—			7,857
Dilutive effect of stock options, restricted stock and equity-settled awards	—			513			—			456
Total weighted average shares outstanding — diluted	34,299			43,868			34,248			43,750
Anti-dilutive awards excluded from diluted weighted average shares	10,933			1,959			10,835			2,171

___________________


^(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 our convertible senior notes (Convertible Notes) in cash upon conversion with only the amount in excess of par value of the Convertible Notes to be settled in shares of our common stock. Therefore, our calculation of diluted net income per share using the treasury stock method includes only the amount, if any, in excess of par value of the Convertible Notes. As such, the Convertible Notes have no impact on diluted net income per share until the price of our common stock exceeds the $24.49 conversion price of the Convertible Notes. The average price of our common stock in third quarter 2015 did not exceed the conversion price which resulted in no additional diluted outstanding shares.

Note 13—Income Taxes

Our provision for income taxes including the impact of deferred tax asset valuation allowance is as follows:



	Third Quarter						First Nine Months
	2015			2014			2015			2014
	(In thousands)
Current income tax benefit (expense)	$	(27	)	$	(200	)	$	(27	)	$	(4,815	)
Deferred income tax benefit (expense)	34,678			(2,555		)	60,844			(10,649		)
Deferred tax asset valuation allowance benefit (expense)	(98,887		)	—			(99,950		)	—
Income tax benefit (expense)	$	(64,236	)	$	(2,755	)	$	(39,133	)	$	(15,464	)

Our effective tax rate was 64 percent in third quarter 2015 and 23 percent in first nine months 2015. Excluding the impact of valuation allowance, our effective tax rate was a 35 percent benefit in third quarter 2015 and 36 percent benefit in first nine months 2015. Our effective tax rate was 35 percent in third quarter and first nine months 2014. Our effective tax rates include the effect of state income taxes, noncontrolling interests, nondeductible items and benefits of percentage depletion.

We assess available positive and negative evidence to estimate whether sufficient future taxable income will be generated to permit use of the existing deferred tax asset. In determining our valuation allowance, a significant piece of objective negative evidence evaluated was the cumulative loss incurred over the three-year period ended September 30, 2015, principally driven by impairments of oil and gas assets. Such evidence limits our ability to consider other subjective evidence, such as our projected future taxable income.

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estimates of future taxable income are reduced or increased or if objective negative evidence in the form of cumulative losses is no longer present and additional weight is given to subjective evidence, such as our projected future taxable income.

Note 14—Commitments and 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. However, it is possible 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. In third quarter 2015, we increased our reserves for environmental remediation by $388,000 due to additional testing and remediation requirements by state regulatory agencies. We estimate the remaining cost to complete remediation activities will be approximately $600,000, 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 third quarter-end 2015 and year-end 2014, our asset retirement obligation was $1,748,000 and $1,807,000, which is included in other liabilities.

Unallocated Severance-related Costs

In connection with the departures of our former Chief Executive Officer and Chief Financial Officer in September 2015, we recorded one-time severance-related charges of $3,314,000 which are included in general and administrative expense on our consolidated statements of income and comprehensive income. Approximately $2,721,000 of these severance-related charges will be paid in fourth quarter 2015 with the balance to be paid in 2016.

Oil and Gas Restructuring Costs

In connection with review of strategic alternatives with respect to our oil and gas business that was announced in December 2014, we offered retention bonuses to key personnel provided they remain our employees through December 2015. We are expensing retention bonus costs over the retention period. In first nine months 2015, we incurred severance expenses related to staff reductions, paid a portion of the December 2014 accrual under written severance agreements and incurred costs associated with closure of our Fort Worth office. Office closure costs include a $1,750,000 lease termination charge and $391,000 for write off of leasehold improvements which were partially offset by a deferred lease credit of $364,000. These restructuring costs are included in other operating expense on our consolidated statements of income and comprehensive income. We may incur additional costs related to our strategic initiatives associated with lowering capital expenditures and operating costs in our oil and gas segment.

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The following table summarizes activity related to liabilities associated with our oil and gas restructuring activities in first nine months 2015:



	Employee-Related Costs			Lease Termination Charge			Total
	(In thousands)
Balance at year-end 2014	$	(2,367	)	$	—		$	(2,367	)
Additions	(1,979		)	(1,750		)	(3,729		)
Payments	2,047			1,750			3,797
Balance at third quarter-end 2015	$	(2,299	)	$	—		$	(2,299	)

Note 15—Segment Information

We manage our operations through three 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.

Total assets allocated by segment are as follows:



	Third Quarter-End		Year-End
	2015		2014
	(In thousands)
Real estate	$	713,912	$	654,774
Oil and gas	191,328		342,703
Other natural resources	20,034		22,531
Assets not allocated to segments ^(a)	115,942		238,191
	$	1,041,216	$	1,258,199

_________________________


^(a)	Assets not allocated to segments at third quarter-end 2015 principally consist of cash and cash equivalents of $92,640,000 and a net deferred tax asset of $1,118,000. Assets not allocated to segments at year-end 2014 principally consist of cash and cash equivalents of $170,127,000 and a net deferred tax asset of $40,624,000.

We evaluate performance based on segment earnings (loss) before unallocated items and income taxes. Segment earnings (loss) consist of operating income, equity in earnings (loss) of unconsolidated ventures, gain on sales of assets, interest income on loans secured by real estate and net (income) loss attributable to noncontrolling interests. Items not allocated to our business segments consist of general and administrative expense, share-based and long-term incentive compensation, gain on sale of strategic timberland, interest expense and other corporate non-operating income and expense. The accounting policies of the segments are the same as those described in Note 1—Basis of Presentation. Our revenues are derived from U.S. operations and all of our assets are located in the U.S. In third quarter 2015, no single customer accounted for more than ten percent of our total revenues.

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Segment revenues and earnings are as follows:



	Third Quarter						First Nine Months
	2015			2014			2015			2014
	(In thousands)
Revenues:
Real estate	$	27,957		$	32,445		$	100,196		$	153,098
Oil and gas	13,485			24,145			42,835			66,076
Other natural resources	1,726			2,250			5,372			7,284
Total revenues	$	43,168		$	58,840		$	148,403		$	226,458
Segment earnings (loss):
Real estate	$	5,154		$	15,987		$	29,747		$	66,859
Oil and gas	(86,192		)	6,002			(146,000		)	16,331
Other natural resources	(77		)	669			(511		)	2,220
Total segment earnings (loss)	(81,115		)	22,658			(116,764		)	85,410
Items not allocated to segments ^(a)	(18,865		)	(14,676		)	(50,984		)	(41,563		)
Income (loss) before taxes attributable to Forestar Group Inc.	$	(99,980	)	$	7,982		$	(167,748	)	$	43,847

_________________________


^(a)	Items not allocated to segments consist of:



	Third Quarter						First Nine Months
	2015			2014			2015			2014
	(In thousands)
General and administrative expense	$	(8,343	)	$	(5,190	)	$	(19,540	)	$	(15,924	)
Shared-based and long-term incentive compensation expense	(2,245		)	(991		)	(5,726		)	(4,523		)
Interest expense	(8,315		)	(8,634		)	(25,851		)	(21,507		)
Other corporate non-operating income	38			139			133			391
	$	(18,865	)	$	(14,676	)	$	(50,984	)	$	(41,563	)

Note 16—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 Variable Interest Entities (VIEs) in which an enterprise has a controlling financial interest and is the primary beneficiary. A controlling financial interest will have both of the following characteristics: (a) the power to direct the VIE activities that most significantly impact economic performance and (b) the obligation to absorb the VIE losses and right to receive benefits that are significant to the VIE. We examine specific criteria and use judgment when determining whether we are the primary beneficiary and must consolidate a VIE. We perform this review initially at the time we enter into venture agreements and continuously reassess to see if we are the primary beneficiary of a VIE.

At third quarter-end 2015, we have four VIEs. We account for these VIEs using the equity method since 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 third quarter-end 2015, these VIEs have total assets of $77,672,000, substantially all of which represent developed and undeveloped real estate, and total liabilities of $97,828,000, which includes $29,835,000 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 7—Investment in Unconsolidated Ventures. At third quarter-end 2015, our investment in these VIEs is $8,822,000 and is included in investment in unconsolidated ventures. In first nine months 2015, we contributed $111,000 to these VIEs. Our maximum exposure to loss related to one of these VIEs is estimated at $3,808,000, 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.

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Note 17—Share-Based and Long-Term Incentive Compensation

Share-based and long-term incentive compensation expense consists of:



	Third Quarter					First Nine Months
	2015		2014			2015			2014
	(In thousands)
Cash-settled awards	$	146	$	(801	)	$	(1,005	)	$	(1,996	)
Equity-settled awards	1,654		1,307			4,569			4,897
Restricted stock	16		22			13			101
Stock options	388		463			1,954			1,521
Total share-based compensation	2,204		991			5,531			4,523
Deferred cash	41		—			195			—
	$	2,245	$	991		$	5,726		$	4,523

Share-based and long-term incentive compensation expense is included in:



	Third Quarter					First Nine Months
	2015		2014			2015		2014
	(In thousands)
General and administrative expense	$	1,124	$	(50	)	$	2,970	$	1,217
Other operating expense	1,121		1,041			2,756		3,306
	$	2,245	$	991		$	5,726	$	4,523

Share-Based Compensation

In first quarter 2015, we granted 89,900 cash-settled stock appreciation rights awards and 598,600 equity-settled awards. 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, or disability or if there is a change in control. Equity-settled awards granted to employees include market-leveraged stock units (MSUs) and stock options. Equity-settled MSUs will be settled in common stock based upon our stock price performance over three years from the date of grant. Stock options have a ten-year term, generally become exercisable ratably over four years and provide for accelerated or continued vesting upon retirement, death, or disability or if there is a change in control. Equity-settled awards in the form of restricted stock units granted to our directors are fully vested at the time of grant and are issued upon retirement.

In third quarter 2015, we granted 141,300 stock option awards in connection with management promotions. These awards have a ten-year term, vest ratably over three years and are exercisable only when our stock price exceeds $17.50 per share. We also granted 24,200 cash-settled restricted stock units which vest after three years and provide for accelerated or continued vesting upon death, disability or if there is a change in control. In addition, 36,100 cash-settled restricted stock units were awarded to certain key employees as retention grants. These awards vest over three years and are not eligible for retirement acceleration.

The fair value of awards granted to retirement eligible employees expensed at the date of grant was $517,000 and $760,000 in first nine months 2015 and 2014. Unrecognized share-based compensation expense related to non-vested equity-settled awards, restricted stock and stock options is $6,160,000 at third quarter-end 2015.

In first nine months 2015 and 2014, we issued 159,867 and 211,333 shares out of our treasury stock associated with vesting of stock-based awards or exercise of stock options, net of 48,636 and 54,272 shares withheld having a value of $722,000 and $1,024,000 for payroll taxes in connection with vesting of stock-based awards or exercise of stock options.

Long-Term Incentive Compensation

In first quarter 2015, we granted $587,000 of long-term incentive compensation in the form of deferred cash compensation. Deferred cash will be paid out after the earlier of three years or the employee's retirement eligibility date and the expense is recognized ratably over the vesting period. The accrued liability was $195,000 at third quarter-end 2015 and is included in other liabilities.

Note 18—Subsequent Event

On October 16, 2015, we obtained a senior secured construction loan in the amount of $52,000,000 from PNC Bank, National Association to finance the construction of a 379-unit multifamily project (Dillon) located in Charlotte, North

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Carolina. The loan is secured by a lien on the land and improvements to be constructed, and by a collateral assignment of present and future leases and rents. The loan bears interest at the LIBOR rate plus 2.20 percent, payable monthly, has an initial term of 48 months and may be extended for two additional 12-month periods following the initial term, subject to payment of extension fees and fulfillment of specified conditions.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the financial statements and Management’s Discussion and Analysis of Financial Condition and Results of Operations in our 2014 Annual Report on Form 10-K. Unless otherwise indicated, information is presented as of third quarter-end 2015, and references to acreage owned includes all acres owned by ventures regardless of our ownership interest in a venture.

Forward-Looking Statements

This Quarterly Report on Form 10-Q and other materials we have filed or may file with the Securities and Exchange Commission contain “forward-looking statements” within the meaning of the federal securities laws. These forward-looking statements are identified by their use of terms and phrases such as “believe,” “anticipate,” “could,” “estimate,” “likely,” “intend,” “may,” “plan,” “expect,” and similar expressions, including references to assumptions. These statements reflect our current views with respect to future events and are subject to risks and uncertainties. We note that a variety of factors and uncertainties could cause our actual results to differ significantly from the results discussed in the forward-looking statements. Factors and uncertainties that might cause such differences include, but are not limited to:


•	general economic, market or business conditions in Texas or Georgia, where our real estate activities are concentrated, or on a national or global scale;


•	our ability to achieve some or all of our strategic initiatives;


•	the opportunities (or lack thereof) that may be presented to us and that we may pursue;


•	our ability to hire and retain key personnel;


•	future residential, multifamily or commercial entitlements, development approvals and the ability to obtain such approvals;


•	obtaining approvals of reimbursements and other payments from special improvement districts and the timing of such payments;

•

accuracy of estimates and other assumptions related to investment in and development of real estate, the expected timing and pricing of land and lot sales and related cost of real estate sales, impairment of long-lived assets, income taxes, share-based compensation, oil and gas reserves, revenues, capital expenditures and lease operating expense accruals associated with our oil and gas working interests, and depletion of our oil and gas properties;


•	the levels of resale housing inventory and potential impact of foreclosures in our mixed-use development projects and the regions in which they are located;


•	fluctuations in costs and expenses, including impacts from shortages in materials or labor;


•	demand for new housing, which can be affected by a number of factors including the availability of mortgage credit, job growth and fluctuations in commodity prices;


•	demand for multifamily communities, which can be affected by a number of factors including local markets and economic conditions;


•	competitive actions by other companies;


•	changes in governmental policies, laws or regulations and actions or restrictions of regulatory agencies;


•	risks associated with oil and gas exploration, drilling and production activities;


•	fluctuations in oil and gas commodity prices;


•	our ability to fully realize our deferred tax assets is dependent upon generating future taxable income, executing tax planning strategies, and reversals of existing taxable temporary differences;


•	government regulation of exploration and production technology, including hydraulic fracturing;


•	the results of financing efforts, including our ability to obtain financing with favorable terms, or at all;


•	our ability to make interest and principal payments on our debt or amend and satisfy the other covenants contained in our senior secured credit facility, indentures and other debt agreements;


•	our partners’ ability to fund their capital commitments and otherwise fulfill their operating and financial obligations;


•	the effect of limitations, restrictions and natural events on our ability to harvest and deliver timber;


•	inability to obtain permits for, or changes in laws, governmental policies or regulations affecting, water withdrawal or usage;


•	the final resolutions or outcomes with respect to our contingent and other liabilities related to our business; and

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•	our ability to execute our growth strategy and deliver acceptable returns from acquisitions and other investments.

Other factors, including the risk factors described in Item 1A of our 2014 Annual Report on Form 10-K, may also cause actual results to differ materially from those projected by our forward-looking statements. New factors emerge from time to time and it is not possible for us to predict all such factors, nor can we assess the impact of any such factor on our business or the extent to which any factor, or combination of factors, may cause results to differ materially from those contained in any forward-looking statement.

Any forward-looking statement speaks only as of the date on which such statement is made, and, except as required by law, we expressly disclaim any obligation or undertaking to disseminate any updates or revisions to any forward-looking statement to reflect events or circumstances after the date on which such statement is made or to reflect the occurrence of unanticipated events.

Results of Operations

A summary of our consolidated results by business segment follows:



	Third Quarter						First Nine Months
	2015			2014			2015			2014
	(In thousands)
Revenues:
Real estate	$	27,957		$	32,445		$	100,196		$	153,098
Oil and gas	13,485			24,145			42,835			66,076
Other natural resources	1,726			2,250			5,372			7,284
Total revenues	$	43,168		$	58,840		$	148,403		$	226,458
Segment earnings (loss):
Real estate	$	5,154		$	15,987		$	29,747		$	66,859
Oil and gas	(86,192		)	6,002			(146,000		)	16,331
Other natural resources	(77		)	669			(511		)	2,220
Total segment earnings (loss)	(81,115		)	22,658			(116,764		)	85,410
Items not allocated to segments:
General and administrative expense	(8,343		)	(5,190		)	(19,540		)	(15,924		)
Share-based and long-term incentive compensation expense	(2,245		)	(991		)	(5,726		)	(4,523		)
Interest expense	(8,315		)	(8,634		)	(25,851		)	(21,507		)
Other corporate non-operating income	38			139			133			391
Income (loss) before taxes	(99,980		)	7,982			(167,748		)	43,847
Income tax benefit (expense)	(64,236		)	(2,755		)	(39,133		)	(15,464		)
Net income (loss) attributable to Forestar Group Inc.	$	(164,216	)	$	5,227		$	(206,881	)	$	28,383

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Significant aspects of our results of operations follow:

Third Quarter and First Nine Months 2015

•

Third quarter 2015 real estate earnings declined principally due to a $7,610,000 gain in third quarter 2014 associated with the acquisition of our partner's interest in the Eleven multifamily venture, decreased residential lot sales activity and $1,757,000 of interest income in third quarter 2014 related to a loan secured by a mixed-use real estate community in Houston. First nine months 2015 real estate segment earnings declined principally due to lower undeveloped land sales, a $10,476,000 gain in second quarter 2014 associated with a non-monetary exchange of leasehold timber rights for 5,400 acres of undeveloped land with a partner in a consolidated venture, a $7,610,000 gain in third quarter 2014 associated with the acquisition of our partner's interest in the Eleven multifamily venture, decreased residential lot sales activity and $1,757,000 interest income in third quarter 2014 related to a loan secured by a mixed-use real estate community in Houston.

•

Third quarter 2015 oil and gas segment earnings were down compared with third quarter 2014 principally due to non-cash asset impairment charges of $81,240,000, of which $65,382,000 is related to proved oil and gas properties and $15,858,000 is related to unproved leasehold interests, principally driven by current and projected future lower oil and gas prices. In addition, lower realized oil and gas prices negatively impacted results despite an increase in production volumes, which were partially offset by lower operating costs. First nine months 2015 oil and gas segment results include $138,054,000 of non-cash charges, which include impairments of $90,417,000 for proved oil and gas properties and $36,768,000 for unproved leasehold interests, and exploratory dry hole costs and pre-drilling costs of $10,869,000. First nine months 2015 results also include $1,979,000 of employee severance and retention bonus costs as part of our initiative to significantly reduce oil and gas operating costs and a lease termination charge of $1,750,000 associated with the closure of our office in Fort Worth, Texas.


•	General and administrative expense increased principally as a result of one-time severance-related charges of $3,314,000 related to departures of our former Chief Executive officer (CEO) and Chief Financial Officer (CFO).

Current Market Conditions

Sales of new U.S. single-family homes were 468,000 units in September 2015, on a seasonally adjusted annualized basis, up two percent compared with September 2014, but down over 11 percent compared with the downwardly-revised August 2015 results, representing the lowest level of new homes sales since November 2014, indicating the housing recovery remains tentative. Inventories of new homes are at or below historical levels in many areas. In addition, declining finished lot inventories and supply of economically developable raw land has resulted in demand for our developed lots. However, national and global economic weakness and uncertainty, and a restrictive mortgage lending environment continue to threaten a robust recovery in the housing market, despite low interest rates. Multifamily market conditions continue to be strong, with many markets experiencing healthy occupancy levels and positive rent growth. This improvement has been driven primarily by limited housing inventory, reduced single-family mortgage credit availability, and the increased propensity to rent among the 18 to 34 year old demographic of the U.S. population.

West Texas Intermediate crude oil prices at third quarter-end 2015 declined over 50 percent compared with third quarter-end 2014, driven by a combination of lower worldwide economic growth, record inventory levels and concern over higher oil exports from Iran. In response to the significant decline in crude oil prices, exploration and development activity in the U.S. has declined sharply, however production has remained at historically high levels, aided by increased drilling efficiencies and lower costs. U.S. production continues to be liquids focused principally due to the premium price of oil over gas when comparing energy equivalency and current estimates of domestic gas producing supplies are believed to be sufficient.

Henry Hub natural gas prices at third quarter-end 2015 were down approximately 40 percent compared with third quarter-end 2014, and remain significantly lower than realized prices over the last decade. The decline in natural gas prices is principally driven by higher inventories, which are 35 percent higher than year ago levels, and modestly above the previous five year average. Despite low prices, natural gas production in the U.S. remains high, driven by continued improvements in drilling efficiency and lower operating costs, which is expected to result in additional inventory growth.

Business Segments

We manage our operations through three business segments:


•	Real estate,


•	Oil and gas, and


•	Other natural resources.

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We evaluate performance based on segment earnings (loss) before unallocated items and income taxes. Segment earnings (loss) consist of operating income, equity in earnings (loss) of unconsolidated ventures, gain on sales of assets, interest income on loans secured by real estate and net (income) loss attributable to noncontrolling interests. Items not allocated to our business segments consist of general and administrative expense, share-based and long-term incentive compensation, gain on sale of strategic timberland, interest expense and other corporate non-operating income and expense. The accounting policies of the segments are the same as those described in the accounting policy note to the consolidated financial statements.

We operate in cyclical industries. Our operations are affected to varying degrees by supply and demand factors and economic conditions including changes in interest rates, availability of mortgage credit, consumer and home builder sentiment, new housing starts, real estate values, employment levels, changes in the market prices for oil, gas and timber, and the overall strength or weakness of the U.S. economy.

Real Estate

We own directly or through ventures approximately 106,000 acres of real estate located in 12 states and 15 markets. Our real estate segment secures entitlements and develops infrastructure on our lands, primarily for single-family residential and mixed-use communities. We own approximately 82,000 acres in a broad area around Atlanta, Georgia, with the balance located primarily in Texas. We target investments principally in our strategic growth corridors, regions across the southern half of the United States that possess key demographic and growth characteristics that we believe make them attractive for long-term real estate investment. We own and manage our projects either directly or through ventures. Our real estate segment revenues are principally derived from the sales of residential single-family lots and tracts, undeveloped land and commercial real estate, and from the operation of income producing properties, primarily a hotel and multifamily properties.

A summary of our real estate results follows:



	Third Quarter						First Nine Months
	2015			2014			2015			2014
	(In thousands)
Revenues	$	27,957		$	32,445		$	100,196		$	153,098
Cost of sales	(16,368		)	(20,053		)	(55,860		)	(88,262		)
Operating expenses	(9,831		)	(7,604		)	(29,107		)	(24,994		)
	1,758			4,788			15,229			39,842
Interest income	24			1,757			1,629			6,068
Gain on sale of assets	425			7,610			1,585			18,086
Equity in earnings of unconsolidated ventures	2,832			1,844			11,299			3,474
Less: Net (income) loss attributable to noncontrolling interests	115			(12		)	5			(611		)
Segment earnings	$	5,154		$	15,987		$	29,747		$	66,859

Revenues in our owned and consolidated ventures consist of:



	Third Quarter				First Nine Months
	2015		2014		2015		2014
	(In thousands)
Residential real estate	$	15,488	$	20,714	$	57,630	$	89,876
Commercial real estate	60		166		2,914		946
Undeveloped land	2,157		2,021		6,922		29,031
Commercial and income producing properties	9,588		9,378		31,566		30,361
Other	664		166		1,164		2,884
	$	27,957	$	32,445	$	100,196	$	153,098

Residential real estate revenues principally consist of the sale of single-family lots to local, regional and national homebuilders. Revenues decreased in third quarter 2015 compared with third quarter 2014 primarily due to lower residential lot sales caused by construction and inspection delays associated with abnormally wet weather conditions in second quarter 2015. Decrease in revenues in first nine months 2015 compared with first nine months 2014 is primarily due to lower residential lot sales and reduced undeveloped land sales. In addition, in first nine months 2015, we sold 1,002 acres of residential tracts for $4,659,000 which generated segment earnings of $1,499,000, compared to 910 acres of residential tracts for $6,567,000 which generated segment earnings of $2,678,000 in first nine months 2014.

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In first nine months 2015, we sold 2,378 acres of undeveloped land for $6,922,000, or approximately $2,911 per acre, generating approximately $5,242,000 in segment earnings, as compared with 12,916 acres sold for $29,031,000 or approximately $2,248 per acre, generating approximately $22,257,000 in segment earnings in first nine months 2014.

Commercial and income producing properties revenue include revenues from hotel room sales and other guest services, rental revenues from our operating multifamily properties and reimbursement for costs paid to subcontractors plus development and construction fees from certain multifamily projects. Third quarter and first nine months 2015 include $1,449,000 and $6,003,000 in construction revenues associated with one multifamily fixed fee contract as general contractor. The construction of this multifamily project is expected to be substantially completed by year-end 2015. Revenues associated with multifamily construction contracts for third quarter and first nine months 2014 were $2,865,000 and $9,559,000. Rental revenues from our multifamily operating properties for third quarter and first nine months 2015 were $2,347,000 and $6,150,000 compared with $40,000 and $48,000 in third quarter and first nine months 2014, primarily due to the substantial completion of the Eleven multifamily project at the end of second quarter 2014 and acquiring our partner's interest in the multifamily venture in third quarter 2014. In addition, our Midtown Cedar Hill multifamily project near Dallas was substantially completed in second quarter 2015 and is 91 percent occupied at third quarter-end 2015. Midtown Cedar Hill is under contract for sale with closing scheduled for late December 2015.

Units sold consist of:



	Third Quarter				First Nine Months
	2015		2014		2015		2014
Owned and consolidated ventures:
Residential lots sold	186		286		699		1,603
Revenue per lot sold	$	76,232	$	72,352	$	73,287	$	52,052
Commercial acres sold	3		—		27		3
Revenue per commercial acre sold	$	28,037	$	—	$	109,802	$	96,774
Undeveloped acres sold	744		637		2,378		12,916
Revenue per acre sold	$	2,900	$	3,179	$	2,911	$	2,248
Ventures accounted for using the equity method:
Residential lots sold	115		37		410		231
Revenue per lot sold	$	77,256	$	83,711	$	77,973	$	70,325
Commercial acres sold	—		4		29		4
Revenue per commercial acre sold	$	—	$	589,203	$	311,995	$	589,203
Undeveloped acres sold	3,872		—		4,217		258
Revenue per acre sold	$	2,053	$	—	$	2,129	$	2,306

Cost of sales in third quarter and first nine months 2015 include $2,083,000 and $7,209,000 related to multifamily construction contract costs we incurred as general contractor and paid to subcontractors associated with our development of a multifamily venture property near Denver, compared with $4,649,000 and $13,690,000 associated with two multifamily venture properties in third quarter and first nine months 2014, of which one was completed in second quarter 2014. Included in multifamily construction contract costs are charges of $634,000 and $1,206,000 in third quarter and first nine months 2015 reflecting estimated cost increases associated with our fixed fee contracts as general contractor for one multifamily venture property compared with charges of $1,784,000 and $4,131,000 associated with two multifamily venture properties in third quarter and first nine months 2014. Cost of sales in first nine months 2015 also includes $729,000 of non-cash asset impairment charges, of which $504,000 was recognized in first quarter 2015 associated with a residential development with golf course and country club property located near Fort Worth which was sold in April 2015 and $225,000 was recognized in second quarter 2015 related to one owned project near Atlanta where the remaining lots were sold in August 2015.

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Operating expenses consist of:



	Third Quarter				First Nine Months
	2015		2014		2015		2014
	(In thousands)
Employee compensation and benefits	$	2,166	$	2,605	$	6,492	$	8,118
Property taxes	2,154		1,558		6,991		5,043
Professional services	1,093		807		3,629		4,218
Depreciation and amortization	2,125		725		5,854		2,068
Other	2,293		1,909		6,141		5,547
	$	9,831	$	7,604	$	29,107	$	24,994

The increase in operating expenses for third quarter and first nine months 2015 is principally related to increase in depreciation and amortization and property taxes associated with the Eleven multifamily project which was completed in second quarter 2014 and Midtown Cedar Hill multifamily project which was substantially completed in second quarter 2015. In third quarter 2014, we acquired full ownership of the Eleven multifamily project in Austin in which we previously held a 25 percent equity interest.

Interest income principally represents earnings from a loan secured by a mixed-use real estate community in Houston that was paid in full in first quarter 2015 and interest income received on reimbursements from utility and improvement districts.

In first nine months 2015, we recorded a gain of $1,585,000, of which $1,160,000 was associated with the reduction of a surety bond in connection with the Cibolo Canyons Special Improvement District (CCSID) bond offering in 2014 and $425,000 of excess hotel occupancy and sales and use tax pledged revenues from CCSID after their payments to the debt service fund. In first nine months 2014, $18,086,000 of gain includes a $10,476,000 gain associated with 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 and a $7,610,000 gain associated with the acquisition of our partner's interest in the Eleven multifamily venture.

Increase in equity earnings from our unconsolidated ventures in third quarter 2015 compared with third quarter 2014 is primarily due to sale of 3,872 acres of undeveloped land for $2,053 per acre from a venture in Atlanta, Georgia which generated equity earnings of $1,007,000. Increase in equity earnings from our unconsolidated ventures in first nine months 2015 compared with first nine months 2014 is primarily related to increased lot sales activity associated with two projects in Houston, Texas and increased undeveloped land sales associated with a venture in Atlanta, Georgia.

Information about our real estate projects and our real estate ventures follows:



	Third Quarter-End
	2015	2014
Owned and consolidated ventures:
Entitled, developed and under development projects
Number of projects	67	65
Residential lots remaining	14,695	14,772
Commercial acres remaining	1,721	1,722
Undeveloped land and land in the entitlement process
Number of projects	11	11
Acres in entitlement process	24,430	24,430
Acres undeveloped	70,291	78,918
Ventures accounted for using the equity method:
Ventures’ entitled, developed and under development projects
Number of projects	13	8
Residential lots remaining	2,672	2,984
Commercial acres remaining	182	236
Ventures’ undeveloped land and land in the entitlement process
Acres undeveloped	478	5,073

We underwrite development projects based on a variety of assumptions incorporated into our development plans, including the timing and pricing of sales and leasing and costs to complete development. Our development plans are periodically reviewed in comparison to our return projections and expectations, and we may revise our plans as business conditions warrant. If as a result of changes to our development plans the anticipated future net cash flows are reduced such

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that our basis in a project is not fully recoverable, we may be required to recognize a non-cash impairment charge for such project.

Our net investment in owned and consolidated real estate by geographic location follows:



State	Entitled, Developed, and Under Development Projects		Undeveloped Land and Land in Entitlement Process		Commercial and Income Producing Properties		Total
	(In thousands)
Texas	$	264,963	$	5,710	$	140,853	$	411,526
Georgia	13,827		62,992		—		76,819
California	8,915		24,219		—		33,134
North Carolina	12,333		95		18,121		30,549
Colorado	25,356		618		—		25,974
Tennessee	17,936		140		8,483		26,559
Other	16,202		50		—		16,252
	$	359,532	$	93,824	$	167,457	$	620,813

Oil and Gas

Our oil and gas segment is focused on the exploration, development and production of oil and gas on our mineral and leasehold interests.

We lease portions of our 590,000 owned net mineral acres located principally in Texas, Louisiana, Georgia and Alabama to other oil and gas companies in return for a lease bonus, delay rentals and a royalty interest. At third quarter-end 2015, we have about 22,000 net acres leased to others, about 36,000 net acres leased to others that are held by production and 532 gross productive wells operated by others on our owned mineral acres. Most leases are for a three to five year term although all or a portion of a lease may be extended as long as actual production is occurring.

At third quarter-end 2015, our leasehold interests include 324,000 net mineral acres leased from others principally located in Nebraska and Kansas primarily targeting the Lansing-Kansas City formation, in Oklahoma targeting various formations in the Anadarko Basin, in the Texas Panhandle primarily targeting the Tonkawa and Cleveland formations and in North Dakota primarily targeting the Bakken and Three Forks formations. Our leasehold interests include 9,000 net mineral acres in the Bakken/Three Forks formation. We have 45,000 net acres of leasehold interests held by production and 382 gross oil and gas wells with working interest ownership, of which 129 are operated by us.

A summary of our oil and gas results follows:



	Third Quarter						First Nine Months
	2015			2014			2015			2014
	(In thousands)
Revenues	$	13,485		$	24,145		$	42,835		$	66,076
Cost of oil and gas producing activities	(95,553		)	(18,470		)	(177,236		)	(48,016		)
Operating expenses	(2,017		)	(3,164		)	(10,499		)	(11,235		)
	(84,085		)	2,511			(144,900		)	6,825
Gain (loss) on sale of assets	(2,174		)	3,335			(1,320		)	9,041
Equity in earnings of unconsolidated ventures	67			156			220			465
Segment earnings (loss)	$	(86,192	)	$	6,002		$	(146,000	)	$	16,331

Revenues consist of:



	Third Quarter				First Nine Months
	2015		2014		2015		2014
	(In thousands)
Oil production ^(a)	$	11,691	$	22,053	$	37,453	$	59,057
Gas production	1,174		1,913		4,078		5,694
Other (principally lease bonus and delay rentals)	620		179		1,304		1,325
	$	13,485	$	24,145	$	42,835	$	66,076

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_________________________


^(a)	Oil production includes revenues from oil, condensate and natural gas liquids (NGLs).

In third quarter and first nine months 2015, oil and gas production revenues decreased principally as a result of lower oil and gas prices despite an increase in oil and gas production volumes as compared with 2014. The decline in oil prices negatively impacted revenues by $14,338,000 and $41,030,000 in third quarter and first nine months 2015 as compared with the previous year. This decline was partially offset by a $3,977,000 and $19,418,000 increase in revenues as a result of higher oil production volumes in third quarter and first nine months 2015, respectively. The decline in gas prices negatively impacted revenues by $971,000 and $2,525,000 in third quarter and first nine months 2015, partially offset by a $231,000 and $916,000 increase in revenues as a result of increased gas production volumes in third quarter and first nine months 2015 as compared with the previous year.

Other revenues include $996,000 in lease bonuses received from leasing 3,300 net mineral acres owned in Texas and Louisiana during the first nine months 2015 as compared with $1,236,000 in lease bonuses received from leasing approximately 3,900 net mineral acres owned in Texas and Louisiana in 2014.

Cost of oil and gas producing activities consists of:



	Third Quarter				First Nine Months
	2015		2014		2015		2014
	(In thousands)
Depletion and amortization	$	8,970	$	8,098	$	23,853	$	19,907
Production costs	4,950		5,389		14,341		13,694
Exploration costs	242		4,029		10,536		12,008
Non-cash impairment of proved oil and gas properties and unproved leasehold interests	81,240		735		127,185		2,074
Other	151		219		1,321		333
	$	95,553	$	18,470	$	177,236	$	48,016

Cost of oil and gas producing activities increased in third quarter 2015 principally as a result of non-cash impairment charges of $65,382,000 for proved oil and gas properties and $15,858,000 for unproved leasehold interests principally in North Dakota, Oklahoma, Nebraska and Kansas. Cost of oil and gas producing activities in first nine months 2015 includes non-cash impairment charges of $90,417,000 for proved oil and gas properties, $36,768,000 for unproved leasehold interests principally in North Dakota, Oklahoma, Nebraska and Kansas and exploratory dry hole and pre-drilling costs of $10,869,000 related to oil and gas properties in Oklahoma. We may incur additional near-term impairments due to continuation of declining oil and gas prices, changes in production rates, future development costs and levels of proved reserves. First nine months 2014 included non-cash impairment charges of $2,074,000 associated with expiring leasehold interests related to our unproved leasehold interests. In third quarter and first nine months 2015, cost of oil and gas producing activities were also affected by an increase in depletion expenses due to higher oil and gas production volumes, as compared with 2014. Depletion and amortization represent the non-cash cost of producing oil and gas associated with our working interests and is computed based on the units of production method.

Exploration costs principally represent exploratory dry hole costs, geological and geophysical and seismic study costs. Dry hole costs in first nine months 2015 were $9,952,000, which includes a $9,674,000 charge in second quarter 2015 primarily associated with an exploratory well in Oklahoma. Dry hole costs in first nine months 2014 were $9,467,000, which includes $4,938,000 primarily in Kansas and Nebraska, $2,338,000 associated with an exploratory well in Oklahoma and $2,191,000 in east Texas.

Production costs principally represent lease operating expenses associated with producing working interest wells and our share of production severance taxes related to both our royalty and working interests.

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Oil and gas produced and average unit prices related to our royalty and working interests follows:



	Third Quarter				First Nine Months
	2015		2014		2015		2014
Consolidated entities:
Oil production (barrels)	278,900		250,500		810,800		632,800
Average oil price per barrel	$	40.66	$	86.13	$	44.61	$	90.73
NGL production (barrels)	30,400		11,500		81,300		38,500
Average NGL price per barrel	$	11.52	$	41.12	$	15.80	$	42.56
Total oil production (barrels), including NGLs	309,300		262,000		892,100		671,300
Average total oil price per barrel, including NGLs	$	37.80	$	84.16	$	41.98	$	87.97
Gas production (millions of cubic feet)	505.0		450.6		1,502.0		1,293.8
Average price per thousand cubic feet	$	2.33	$	4.25	$	2.72	$	4.40
Our share of ventures accounted for using the equity method:
Gas production (millions of cubic feet)	46.8		49.1		129.2		152.3
Average price per thousand cubic feet	$	2.19	$	4.21	$	2.61	$	4.07
Total consolidated and our share of equity method ventures:
Oil production (barrels)	278,900		250,500		810,800		632,800
Average oil price per barrel	$	40.66	$	86.13	$	44.61	$	90.73
NGL production (barrels)	30,400		11,500		81,300		38,500
Average NGL price per barrel	$	11.52	$	41.12	$	15.80	$	42.56
Total oil production (barrels), including NGLs	309,300		262,000		892,100		671,300
Average total oil price per barrel, including NGLs	$	37.80	$	84.16	$	41.98	$	87.97
Gas production (millions of cubic feet)	551.8		499.7		1,631.2		1,446.1
Average price per thousand cubic feet	$	2.31	$	4.24	$	2.71	$	4.37
Total BOE (barrel of oil equivalent) ^(a)	401,200		345,400		1,163,900		912,400
Average price per barrel of oil equivalent	$	32.32	$	70.00	$	35.97	$	71.65

_________________________


^(a)	Gas is converted to barrels of oil equivalent (BOE) using a conversion of six Mcf to one barrel of oil.

Operating expenses consist of:



	Third Quarter				First Nine Months
	2015		2014		2015		2014
	(In thousands)
Employee compensation and benefits	$	1,186	$	2,291	$	5,240	$	7,305
Professional and consulting services	250		156		1,422		833
Depreciation	246		241		728		756
Other	335		476		3,109		2,341
	$	2,017	$	3,164	$	10,499	$	11,235

Operating expenses decreased in third quarter 2015 compared with third quarter 2014 primarily due to lower staffing costs as a result of a reduction in our workforce and initiatives to reduce oil and gas operating expenses, offset by $406,000 of retention bonus expense. First nine months 2015 operating expenses includes restructuring costs of $1,750,000 for a lease termination charge associated with closing our office in Fort Worth, Texas and $1,979,000 of employee severance and retention costs. These restructuring costs were partially offset by lower staffing costs as result of a reduction in our workforce and initiatives to reduce oil and gas operating expenses.

In first nine months 2015, we recorded a net loss of ($1,320,000) on the sale of 27,662 net mineral acres leased from others in Nebraska and North Dakota and the disposition of 29 gross (5 net) producing oil and gas wells in Texas, North Dakota, Nebraska, Oklahoma and Colorado for total sales proceeds of $13,111,000. In first nine months 2014, we recorded a total gain of $9,041,000 in conjunction with the sale of 102 gross (7 net) producing oil and gas wells in Oklahoma and the sale of 571 net mineral acres leased from others in North Dakota.

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Other Natural Resources

Our other natural resources segment manages our timber holdings, recreational leases and water resource initiatives. At third quarter-end 2015, we have about 95,000 real estate acres with timber we own directly or through ventures, primarily in Georgia and Texas. Our other natural resources segment revenues are principally derived from the sales of wood fiber from our land and leases for recreational uses. We have water interests in approximately 1.5 million acres, including a 45 percent nonparticipating royalty interest in groundwater produced or withdrawn for commercial purposes or sold from 1.4 million acres in Texas, Louisiana, Georgia and Alabama, and approximately 20,000 acres of groundwater leases in central Texas.

A summary of our other natural resources results follows:



	Third Quarter						First Nine Months
	2015			2014			2015			2014
	(In thousands)
Revenues	$	1,726		$	2,250		$	5,372		$	7,284
Cost of sales	(819		)	(711		)	(2,599		)	(2,288		)
Operating expenses	(994		)	(1,051		)	(3,303		)	(3,652		)
	(87		)	488			(530		)	1,344
Gain on sale and partial termination of timber lease	—			165			—			850
Equity in earnings of unconsolidated ventures	10			16			19			26
Segment earnings (loss)	$	(77	)	$	669		$	(511	)	$	2,220

Revenues consist of:



	Third Quarter				First Nine Months
	2015		2014		2015		2014
	(In thousands)
Fiber	$	1,403	$	1,770	$	4,039	$	5,514
Water	100		250		400		1,000
Recreational leases and other	223		230		933		770
	$	1,726	$	2,250	$	5,372	$	7,284

Fiber sold consists of:



	Third Quarter				First Nine Months
	2015		2014		2015		2014
Pulpwood tons sold	45,600		71,500		109,100		157,900
Average pulpwood price per ton	$	9.89	$	11.18	$	9.41	$	11.00
Sawtimber tons sold	14,400		21,500		53,800		100,000
Average sawtimber price per ton	$	20.41	$	21.31	$	21.22	$	22.38
Total tons sold	60,000		93,000		162,900		257,900
Average stumpage price per ton ^(a)	$	12.41	$	13.52	$	13.31	$	15.41

_________________________


^(a)	Average stumpage price per ton is based on gross revenues less cut and haul costs.

Water revenues are associated with a groundwater reservation agreement with Hays County, Texas, which commenced in third quarter 2013 and was terminated in second quarter 2015.

Information about our recreational leases follows:



	Third Quarter				First Nine Months
	2015		2014		2015		2014
Average recreational acres leased	97,000		107,800		99,900		111,400
Average price per leased acre	$	8.93	$	8.66	$	9.18	$	9.17

Cost of sales principally includes non-cash cost of timber cut and sold and delay rental payments paid to others related to groundwater leases in central Texas.

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Operating expenses consist of:



	Third Quarter				First Nine Months
	2015		2014		2015		2014
	(In thousands)
Employee compensation and benefits	$	511	$	602	$	1,754	$	1,711
Professional and consulting services	307		230		955		1,437
Other	176		219		594		504
	$	994	$	1,051	$	3,303	$	3,652

Operating expenses associated with our water resources initiatives for third quarter and first nine months 2015 were $516,000 and $1,792,000 compared with $449,000 and $2,120,000 in third quarter and first nine months 2014.

Gain on sale and partial termination of timber lease in first nine months 2014 includes a $685,000 gain associated with partial termination of a timber lease related to the sale of 697 acres of undeveloped land in Georgia from a consolidated venture recorded in second quarter 2014 and a $165,000 gain in third quarter 2014 associated with the sale of water rights associated with a real estate project in Colorado.

Items Not Allocated to Segments

Unallocated items represent income and expenses managed on a company-wide basis and include general and administrative expenses, share-based and long-term incentive compensation, interest expense and other corporate non-operating income and expense. General and administrative expenses principally consist of accounting and finance, tax, legal, human resources, internal audit, information technology and our board of directors. These functions support all of our business segments and are not allocated.

General and administrative expenses consist of:



	Third Quarter				First Nine Months
	2015		2014		2015		2014
	(In thousands)
Employee compensation and benefits	$	5,385	$	2,447	$	9,582	$	7,173
Professional and consulting services	1,346		935		4,595		3,301
Facility costs	216		229		670		705
Depreciation and amortization	133		168		464		463
Insurance costs	178		201		493		716
Other	1,085		1,210		3,736		3,566
	$	8,343	$	5,190	$	19,540	$	15,924

Employee compensation and benefits in third quarter and first nine months 2015 includes $3,314,000 of one-time severance-related charges related to departure of our former CEO and CFO under employment and separation agreements, of which approximately $2,721,000 will be paid in fourth quarter 2015 with the balance to be paid in 2016.

Income Taxes

Our provision for income taxes including the impact of deferred tax asset valuation allowance is as follows:



	Third Quarter						First Nine Months
	2015			2014			2015			2014
	(In thousands)
Current income tax benefit (expense)	$	(27	)	$	(200	)	$	(27	)	$	(4,815	)
Deferred income tax benefit (expense)	34,678			(2,555		)	60,844			(10,649		)
Deferred tax asset valuation allowance benefit (expense)	(98,887		)	—			(99,950		)	—
Income tax benefit (expense)	$	(64,236	)	$	(2,755	)	$	(39,133	)	$	(15,464	)

Our effective tax rate was 64 percent in third quarter 2015 and 23 percent in first nine months 2015. Excluding the impact of valuation allowance, our effective tax rate was 35 percent benefit in third quarter 2015 and 36 percent benefit in first nine months 2015. Our effective tax rate was 35 percent in third quarter and first nine months 2014. Our effective tax rates include the effect of state income taxes, noncontrolling interests, nondeductible items and benefits of percentage depletion.

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A valuation allowance was recorded for the portion of our deferred tax asset that we believe is more likely than not to be unrealizable at third quarter-end 2015. The amount of deferred tax asset considered realizable, however, could be adjusted if estimates of future taxable income are reduced or increased or if objective negative evidence in the form of cumulative losses is no longer present and additional weight is given to subjective evidence, such as our projected future taxable income.

Capital Resources and Liquidity

Sources and Uses of Cash

We operate in cyclical industries and our cash flows fluctuate accordingly. Our principal sources of cash are proceeds from the sale of real estate and timber, the cash flow from oil and gas and income producing properties, borrowings and reimbursements from utility and improvement districts. Our principal cash requirements are for the acquisition and development of real estate and investment in oil and gas leasing and production activities, either directly or indirectly through ventures, taxes, interest and compensation. Operating cash flows are affected by the timing of the payment of real estate development expenditures and the collection of proceeds from the eventual sale of the real estate, the timing of which can vary substantially depending on many factors including the size of the project, state and local permitting requirements and availability of utilities, and by the timing of oil and gas leasing and production activities. Working capital varies based on a variety of factors, including the timing of sales of real estate and timber, oil and gas leasing and production activities, collection of receivables, reimbursement from utility and improvement districts and the payment of payables and expenses.

We regularly evaluate alternatives for managing our capital structure and liquidity profile in consideration of expected cash flows, growth and operating capital requirements and capital market conditions. We may, at any time, be considering or be in discussions with respect to the purchase or sale of our common stock, debt securities, convertible securities or a combination thereof.

Cash Flows from Operating Activities

Cash flows from our real estate acquisition and development activities, undeveloped land sales, commercial and income producing properties, timber sales, income from oil and gas properties, recreational leases and reimbursements from utility and improvement districts are classified as operating cash flows.

In first nine months 2015, net cash used for operating activities was $15,040,000. The decrease in cash provided by operating activities year over year is primarily due to lower residential lot sales activity and a decrease in undeveloped land sales. In addition, our real estate development and acquisition expenditures were $81,055,000 exceeding $33,575,000 of real estate cost of sales. In first nine months 2014, net cash provided by operating activities was $36,386,000 principally due to increased residential lot sales and undeveloped land sales activity. This is partially offset by $82,864,000 of real estate development and acquisition expenditures exceeding $59,251,000 of real estate cost of sales.

Cash Flows from Investing Activities

Capital contributions to and capital distributions from unconsolidated ventures, costs incurred to acquire, develop and construct multifamily projects that will be held as commercial operating properties upon stabilization as investment property, business acquisitions and investment in oil and gas properties and equipment are classified as investing activities. In addition, proceeds from the sale of property and equipment, software costs and expenditures related to reforestation activities are also classified as investing activities.

In first nine months 2015, net cash used for investing activities was $60,479,000 principally due to our investment of $47,043,000 in oil and gas properties associated with our previously committed capital investments related to exploration and production operations. In addition, we invested $10,882,000 in property and equipment, software and reforestation, of which $5,757,000 is related to capital expenditures for our 413 guest room hotel in Austin. In first nine months 2014, net cash used in investing activities was $82,929,000 principally due to our investment of $65,661,000 in oil and gas properties and equipment associated with our exploration and production operations and purchase of our partner's interest in our 257-unit multifamily

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property in Austin for $20,155,000, net of cash. In addition, we invested $13,583,000 in property and equipment, software and reforestation, of which $6,440,000 is related to capital expenditures on our 413 guest room hotel in Austin and $4,954,000 is related to water wells development, and a net investment in unconsolidated ventures of $3,415,000. These were partially offset by proceeds of $17,017,000 related to sale of certain oil and gas properties in North Dakota and Oklahoma.

Cash Flows from Financing Activities

In first nine months 2015, net cash used for financing activities was $1,968,000 principally due to payroll taxes on share-settled equity awards and distributions to noncontrolling interests. In first nine months 2014, net cash provided by financing activities was $24,842,000 principally due to net proceeds of $241,947,000 from the issuance of 8.5% senior secured notes, partially offset by debt payments of $222,468,000, of which $200,000,000 is related to retirement of the term loan associated with our senior secured credit facility, $7,200,000 is related to payments of our amortizing notes associated with our tangible equity units, $2,878,000 is related to debt outstanding for our Lantana partnerships and the remaining associated with payment of other indebtedness.

Real Estate Acquisition and Development Activities

We secure entitlements and develop infrastructure, primarily for single family residential and mixed-use communities. We also develop and own directly or through ventures multifamily communities as income producing properties, primarily in our target markets.

We categorize real estate development and acquisition expenditures as operating activities on the statement of cash flows. These development and acquisition expenditures include costs for development of residential lots and mixed-used communities and multifamily community projects that will be marketed for sale upon stabilization.

In first nine months 2015, real estate development and acquisition expenditures were $81,055,000 which includes the acquisition of four new community development sites for $24,387,000 and real estate development costs of $56,668,000.

Oil and Gas Drilling and Other Exploration and Development Activities

At third quarter-end 2015, we had working interests in 382 gross active wells.

Our planned expenditures for 2015 are expected to be significantly lower compared with 2014 and are primarily related to existing well commitments in the Bakken/Three Forks formation of North Dakota. In first nine months 2015, drilling and completion activity was primarily related to existing well commitments with 32 gross Bakken/Three Forks wells generating initial production and two wells waiting on completion. In addition, in first nine months 2015, we have elected to participate as a non-operator in eight new gross wells for $6,664,000 in the Bakken/Three Forks formation of North Dakota. Regional allocation of our capital expenditures for drilling and completion activities in first nine months 2015 is shown below:



	First Nine Months
	2015
	(In thousands)
Bakken and Three Forks formations of North Dakota	$	27,592
Lansing - Kansas City formation of Nebraska and Kansas	3,184
Other formations principally in Oklahoma	16,267
	$	47,043

Our accrued capital expenditures for drilling and completion costs at third quarter-end 2015 were $6,979,000 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. Of the $47,043,000 of capital expenditures that we incurred and paid in first nine months 2015 for drilling and completion activities, $40,757,000 was related to settling year-end 2014 accrued capital expenditures and payment of 2014 well commitments that were completed as of third quarter-end 2015.

Our 2015 projected capital expenditures are subject to various conditions, including third-party operator drilling plans, oilfield services and equipment availability, commodity prices and drilling results. Other factors that could cause us to adjust our projections include changes in commodity prices, service or material costs, opportunities, changes in conditions, or the performance of wells. We will continue to assess the gas and oil price environment along with our liquidity position and may increase or decrease our capital expenditure budget for exploration, development, or acquisition opportunities accordingly.

Liquidity

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At third quarter-end 2015, our senior secured credit facility provides for a $300,000,000 revolving line of credit maturing May 15, 2017 (with two one-year extension options). The revolving line of credit may be prepaid at any time without penalty. The revolving line of credit includes a $100,000,000 sublimit for letters of credit, of which $16,184,000 is outstanding at third quarter-end 2015. Total borrowings under our senior secured credit facility (including the face amount of letters of credit) may not exceed a borrowing base formula.

At third quarter-end 2015, net unused borrowing capacity under our senior secured credit facility is calculated as follows:



	Senior Credit Facility
	(In thousands)
Borrowing base availability	$	300,000
Less: borrowings	—
Less: letters of credit	(16,184		)
	$	283,816

Our net unused borrowing capacity during third quarter 2015 ranged from a high of $284,511,000 to a low of $283,816,000. This facility is used primarily to fund our operating cash needs, which fluctuate due to timing of residential and commercial real estate sales, undeveloped land sales, oil and gas leasing, exploration and production activities and mineral lease bonus payments received, timber sales, reimbursements from utility and improvement districts, payment of payables and expenses and capital expenditures.

The following table details our compliance with the financial covenants calculated as provided in the senior credit facility:



Financial Covenant	Requirement	Third Quarter-End 2015
Interest Coverage Ratio ^(a)	≥2.50:1.0	2.67:1.0
Total Leverage Ratio ^(b)	≤50%	42.1	%
Tangible Net Worth ^(c)	≥$379.0 million	$473.8 million

___________________________________


^(a)	Calculated as EBITDA (earnings before interest, taxes, depreciation, depletion and amortization), plus non-cash compensation expense, plus other non-cash expenses, divided by interest expense excluding loan fees. This covenant is applied at the end of each quarter on a rolling four quarter basis.

^(b)

Calculated as total funded debt divided by adjusted asset value. Total funded debt includes indebtedness for borrowed funds, secured liabilities, reimbursement obligations with respect to letters of credit or similar instruments, and our pro-rata share of joint venture debt outstanding. Adjusted asset value is defined as the sum of unrestricted cash and cash equivalents, timberlands, high value timberlands, raw entitled lands, entitled land under development, minerals business, Credo asset value, special improvement district receipts (SIDR) reimbursements value and other real estate owned at book value without regard to any indebtedness and our pro rata share of joint ventures’ book value without regard to any indebtedness. This covenant is applied at the end of each quarter.

^(c)

Calculated as the amount by which consolidated total assets (excluding Credo acquisition goodwill over $50,000,000) exceeds consolidated total liabilities. At third quarter-end 2015, the requirement is $379,044,000 computed as: $379,044,000 plus 85 percent of the aggregate net proceeds received by us from any equity offering, plus 75 percent of all positive net income, on a cumulative basis. This covenant is applied at the end of each quarter.

To make additional discretionary investments, acquisitions, or distributions, we must maintain available liquidity equal to 10 percent of the aggregate commitments in place. At third quarter-end 2015, the minimum liquidity requirement was $30,000,000, compared with $372,623,000 in actual available liquidity based on the unused borrowing capacity under our senior secured credit facility plus unrestricted cash and cash equivalents. The failure to maintain such minimum liquidity does not constitute a default or event of default of our senior secured credit facility.

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Discretionary investments in community development may be restricted in the event that the revenue/capital expenditure ratio is less than or equal to 1.0x. At third quarter-end 2015, the revenue/capital expenditure ratio was 1.7x. Revenue is defined as total gross revenues (excluding revenues attributed to Credo and multifamily properties), plus our pro rata share of the operating revenues from unconsolidated ventures. Capital expenditures are defined as consolidated development and acquisition expenditures (excluding investments related to Credo and multifamily properties), plus our pro rata share of unconsolidated ventures’ development and acquisition expenditures.

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 third quarter-end 2015, our total leverage ratio exceeded 40 percent and our interest coverage ratio was below 3.0:1.0, and as a result we are prohibited from making restricted payments, which includes purchases of our common stock, until the foregoing conditions are satisfied.

Contractual Obligations and Off-Balance Sheet Arrangements

In 2014, FMF Littleton LLC, an equity method venture in which we own a 25 percent interest, obtained a senior secured construction loan in the amount of $46,384,000 to develop a 385-unit multifamily project located in Littleton, Colorado. The outstanding balance was $15,665,000 at third quarter-end 2015. We provided the lender with a guaranty of completion of the improvements; a guaranty for repayment of 25 percent of the principal balance and unpaid accrued interest; and a standard nonrecourse carve-out guaranty. The principal guaranty will reduce from 25 percent of principal to ten percent upon achievement of certain conditions.

In 2014, CREA FMF Nashville LLC, an equity method venture with Massachusetts Mutual Life Insurance Co. (MassMutual) in which we own a 30 percent interest, obtained a senior secured construction loan in the amount of $51,950,000 to develop a 320-unit multifamily project located in Nashville, Tennessee. The outstanding balance at third quarter-end 2015 was $49,960,000. 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 16, 2016 (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 with a guaranty of completion of the improvements; a guaranty for repayment of 25 percent of the principal balance and unpaid accrued interest; and a standard nonrecourse carve-out guaranty. The principal guaranty will reduce from 25 percent of principal to zero percent upon achievement of certain conditions.

In 2012, FMF Peakview LLC, an equity method venture in which we own a 20 percent interest, obtained a senior secured construction loan in the amount of $31,550,000 to develop a 304-unit multifamily property in Denver. The outstanding balance at third quarter-end 2015 was $29,426,000. We provided the lender with a construction completion guaranty, a repayment guaranty for 25 percent of the principal and unpaid accrued interest, and a standard non-recourse carve-out guaranty.

Cibolo Canyons—San Antonio, Texas

Cibolo Canyons consists of the JW Marriott ^® San Antonio Hill Country Resort & Spa development owned by third parties and a mixed-use development we own. We have $58,736,000 invested in Cibolo Canyons at third quarter-end 2015, all of which is related to the mixed-use development.

Resort Hotel, Spa and Golf Development

In 2007, we entered into agreements to facilitate third party construction and ownership of the JW Marriott ^® San Antonio Hill Country Resort & Spa (the Resort), which includes a 1,002 room destination resort and two PGA Tour ^® Tournament Players Club ^® (TPC) golf courses.

In exchange for our commitment to the Resort, the third party owners assigned to us certain rights under an agreement between the third party owners and a legislatively created Cibolo Canyons Special Improvement District (CCSID). This agreement includes the right to receive from CCSID 9 percent of hotel occupancy revenues and 1.5 percent of other resort sales revenues collected as taxes by CCSID through 2034. The amount we receive will be net of annual ad valorem tax reimbursements by CCSID to the third party owners of the resort through 2020. In addition, these payments will be net of debt service on bonds issued by CCSID collateralized by hotel occupancy tax (HOT) and other resort sales tax through 2034.

The amounts we collect under this agreement are dependent on several factors including the amount of revenues generated by and ad valorem taxes imposed on the Resort and the amount of debt service incurred by CCSID.

In 2014, we received $50,550,000 from CCSID principally related to its issuance of $48,900,000 HOT and Sales and Use Tax Revenue Bonds, resulting in recovery of our full Resort investment. These bonds are obligations solely of CCSID and are

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payable from HOT and sales and use taxes levied on the Resort by CCSID. To facilitate the issuance of the bonds, we provided a $6,846,000 letter of credit to the bond trustee as security for certain debt service fund obligations in the event CCSID tax collections are not sufficient to support payment of the bonds in accordance with their terms. The letter of credit must be maintained until the earlier of redemption of the bonds or scheduled bond maturity in 2034. We also entered into an agreement with the owner of the Resort to assign its senior rights to us in exchange for consideration provided by us, including a surety bond to be drawn if CCSID tax collections are not sufficient to support ad valorem tax rebates payable. The surety bond will decrease as CCSID makes annual ad valorem tax rebate payments, which obligation is scheduled to be retired in full by 2020. All future receipts are expected to be recognized as gains in the period collected. In first nine months 2015, we recorded a gain of $1,585,000, of which $1,160,000 was associated with the reduction of the surety bond in connection with the CCSID bond offering in 2014 and $425,000 of excess hotel occupancy and sales and use tax pledged revenues from CCSID after their payments to the debt service fund.

Mixed-Use Development

The mixed-use development we own consists of 2,100 acres planned to include approximately 1,769 residential lots and 150 commercial acres designated for multifamily and retail uses, of which 954 lots and 130 commercial acres have been sold through third quarter-end 2015.

In 2007, we entered into an agreement with CCSID providing for reimbursement of certain infrastructure costs related to the mixed-use development. Reimbursements are subject to review and approval by CCSID and unreimbursed amounts accrue interest at 9.75 percent. CCSID’s funding for reimbursements is principally derived from its ad valorem tax collections and bond proceeds collateralized by ad valorem taxes, less debt service on these bonds and annual administrative and public service expenses.

Because the amount of each reimbursement is dependent on several factors, including CCSID approval and CCSID having an adequate tax base to generate funds that can be used to reimburse us, there is uncertainty as to the amount and timing of reimbursements under this agreement. We expect to recover our investment from lot and tract sales and reimbursement of approved infrastructure costs from CCSID. We have not recognized income from interest due, but not collected. As these uncertainties are clarified, we will modify our accounting accordingly.

Through third quarter-end 2015, we have submitted and were approved for reimbursement of approximately $54,376,000 of infrastructure costs, of which we have received reimbursements totaling $34,703,000. We received $1,150,000 in reimbursements from CCSID in first nine months 2015. At third quarter-end 2015, we have $19,673,000 in pending reimbursements, excluding interest.

Critical Accounting Policies and Estimates

There have been no significant changes in our critical accounting policies or estimates from those disclosed in our 2014 Annual Report on Form 10-K.

New and Pending Accounting Pronouncements

Please read Note 2—New and Pending Accounting Pronouncements to the Consolidated Financial Statements included in this Quarterly Report on Form 10-Q.

Statistical and Other Data

A summary of our real estate projects in the entitlement process^(a) at third quarter-end 2015 follows:

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Project	County	Market	Project Acres ^(b)
California
Hidden Creek Estates	Los Angeles	Los Angeles	700
Terrace at Hidden Hills	Los Angeles	Los Angeles	30
Georgia
Ball Ground	Cherokee	Atlanta	500
Crossing	Coweta	Atlanta	230
Fincher Road	Cherokee	Atlanta	3,890
Garland Mountain	Cherokee/Bartow	Atlanta	350
Martin’s Bridge	Banks	Atlanta	970
Mill Creek	Coweta	Atlanta	770
Wolf Creek	Carroll/Douglas	Atlanta	12,230
Yellow Creek	Cherokee	Atlanta	1,060
Texas
Lake Houston	Harris/Liberty	Houston	3,700
Total			24,430

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^(a)

A project is deemed to be in the entitlement process when customary steps necessary for the preparation of an application for governmental land-use approvals, like conducting pre-application meetings or similar discussions with governmental officials, have commenced, or an application has been filed. Projects listed may have significant steps remaining, and there is no assurance that entitlements ultimately will be received.


^(b)	Project acres, which are the total for the project regardless of our ownership interest, are approximate. The actual number of acres entitled may vary.

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A summary of activity within our active projects in the development process, which includes entitled ^(a), developed and under development real estate projects, at third quarter-end 2015 follows:



				Residential Lots ^(c)		Commercial Acres ^(d)
Project	County	Interest Owned ^(b)		Lots Sold Since Inception	Lots Remaining	Acres Sold Since Inception	Acres Remaining^(e)
Projects we own
California
San Joaquin River	Contra Costa/Sacramento	100	%	—	—	—	288
Colorado
Buffalo Highlands	Weld	100	%	—	164	—	—
Johnstown Farms	Weld	100	%	281	313	2	3
Pinery West	Douglas	100	%	86	—	20	106
Stonebraker	Weld	100	%	—	603	—	—
Georgia
Seven Hills	Paulding	100	%	843	240	26	113
The Villages at Burt Creek	Dawson	100	%	—	1,715	—	57
West Oaks	Cobb	100	%	—	57	—	—
Other projects (17)	Various	100	%	245	2,258	—	695
North & South Carolina
Habersham	York	100	%	20	167	—	—
Walden	Mecklenburg	100	%	—	387	—	—
Tennessee
Beckwith Crossing	Wilson	100	%	—	99	—	—
Morgan Farms	Williamson	100	%	86	87	—	—
Scales	Williamson	100	%	—	87	—	—
Weatherford Estates	Williamson	100	%	—	17	—	—
Texas
Arrowhead Ranch	Hays	100	%	—	381	—	11
Bar C Ranch	Tarrant	100	%	366	739	—	—
Barrington Kingwood	Harris	100	%	170	10	—	—
Cibolo Canyons	Bexar	100	%	954	815	130	56
Harbor Lakes	Hood	100	%	231	—	21	—
Hunter’s Crossing	Bastrop	100	%	510	—	54	49
Imperial Forest	Harris	100	%	—	428	—	—
La Conterra	Williamson	100	%	202	—	3	55
Lakes of Prosper	Collin	100	%	151	136	4	—
Lantana	Denton	100	%	1,220	544	14	—
Maxwell Creek	Collin	100	%	941	60	10	—
Oak Creek Estates	Comal	100	%	273	281	13	—
Parkside	Collin	100	%	8	192	—	—
River's Edge	Denton	100	%	—	202	—	—
Stoney Creek	Dallas	100	%	231	477	—	—
Summer Creek Ranch	Tarrant	100	%	983	268	35	44
Summer Lakes	Fort Bend	100	%	675	394	56	—
Summer Park	Fort Bend	100	%	69	130	28	68
The Colony	Bastrop	100	%	455	1,430	22	31
The Preserve at Pecan Creek	Denton	100	%	587	195	—	7
Village Park	Collin	100	%	567	—	3	2
Westside at Buttercup Creek	Williamson	100	%	1,496	1	66	—
Other projects (7)	Various	100	%	1,566	20	135	5
Other
Other projects (2)	Various	100	%	543	320	—	—
				13,759	13,217	642	1,590

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				Residential Lots ^(c)		Commercial Acres ^(d)
Project	County	Interest Owned ^(b)		Lots Sold Since Inception	Lots Remaining	Acres Sold Since Inception	Acres Remaining^(e)
Projects in entities we consolidate
Texas
City Park	Harris	75	%	1,311	504	52	113
Timber Creek	Collin	88	%	—	601	—	—
Willow Creek Farms II	Waller/Fort Bend	90	%	90	175	—	—
Other projects (2)	Various	Various		10	198	—	18
				1,411	1,478	52	131
Total owned and consolidated				15,170	14,695	694	1,721

Projects in ventures that we account for using the equity method
Texas
Entrada	Travis	50	%	—	821	—	—
Fannin Farms West	Tarrant	50	%	324	—	—	—
Harper’s Preserve	Montgomery	50	%	513	1,215	30	49
Lantana - Rayzor Ranch	Denton	25	%	1,163	—	50	—
Long Meadow Farms	Fort Bend	38	%	1,514	290	187	118
Southern Trails	Brazoria	80	%	870	126	1	—
Stonewall Estates	Bexar	50	%	363	27	—	—
Other projects (7)	Various	Various		—	193	—	15
Total in ventures				4,747	2,672	268	182
Combined total				19,917	17,367	962	1,903

_________________________


^(a)	A project is deemed entitled when all major discretionary governmental land-use approvals have been received. Some projects may require additional permits and/or non-governmental authorizations for development.


^(b)	Interest owned reflects our net equity interest in the project, whether owned directly or indirectly. There are some projects that have multiple ownership structures within them. Accordingly, portions of these projects may appear as owned, consolidated or accounted for using the equity method.


^(c)	Lots are for the total project, regardless of our ownership interest. Lots remaining represent vacant developed lots, lots under development and future planned lots and are subject to change based on business plan revisions.


^(d)	Commercial acres are for the total project, regardless of our ownership interest, and are net developable acres, which may be fewer than the gross acres available in the project.


^(e)	Excludes acres associated with commercial and income producing properties.

A summary of our significant commercial and mutifamily properties at third quarter-end 2015 follows:

Project

Market

Interest

Owned ^(a)

Type

Acres

Description

Radisson Hotel

Austin

100

Hotel

413 guest rooms and suites

Dillon ^(b)

Charlotte

100

Multifamily

379-unit luxury apartment

Eleven

Austin

100

Multifamily

257-unit luxury apartment

Midtown

Dallas

100

Multifamily

354-unit luxury apartment

Music Row ^(b)

Nashville

100

Multifamily

230-unit luxury apartment

Elan 99 ^(b)

Houston

Multifamily

360-unit luxury apartment

Acklen ^(b)

Nashville

Multifamily

320-unit luxury apartment

HiLine ^(b)

Denver

Multifamily

385-unit luxury apartment

360° ^(b)

Denver

Multifamily

304-unit luxury apartment

_________________________


^(a)	Interest owned reflects our total interest in the project, whether owned directly or indirectly.


^(b)	Construction in progress.

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Oil and Gas Owned Mineral Interests

A summary of our oil and gas owned mineral interests ^(a) at third quarter-end 2015 follows:



State	Unleased	Leased ^(b)	Held By Production ^(c)	Total ^(d)
		(Net acres)
Texas	209,000	16,000	27,000	252,000
Louisiana	129,000	6,000	9,000	144,000
Georgia	152,000	—	—	152,000
Alabama	40,000	—	—	40,000
California	1,000	—	—	1,000
Indiana	1,000	—	—	1,000
	532,000	22,000	36,000	590,000

_________________________


^(a)	Includes ventures.


^(b)	Includes leases in primary lease term or for which a delay rental payment has been received. In the ordinary course of business, leases covering a significant portion of leased net mineral acres may expire from time to time in a single reporting period.


^(c)	Acres being held by production are producing oil or gas in paying quantities.


^(d)	Texas, Louisiana, California and Indiana net acres are calculated as the gross number of surface acres multiplied by our percentage ownership of the mineral interest. Georgia and Alabama net acres are calculated as the gross number of surface acres multiplied by our estimated percentage ownership of the mineral interest based on county sampling.

A summary of our Texas and Louisiana owned mineral acres ^(a) by county or parish at third quarter-end 2015 follows:



Texas		Louisiana
County	Net Acres	Parish	Net Acres
Trinity	46,000	Beauregard	79,000
Angelina	42,000	Vernon	39,000
Houston	29,000	Calcasieu	17,000
Anderson	25,000	Allen	7,000
Cherokee	24,000	Rapides	1,000
Sabine	23,000	Other	1,000
Red River	14,000		144,000
Newton	13,000
San Augustine	13,000
Jasper	12,000
Other	11,000
	252,000

_________________________


^(a)	Includes ventures.

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Oil and Gas Mineral Interests Leased

A summary of our net oil and gas mineral acres leased from others at third quarter-end 2015 follows:



State	Undeveloped	Held By Production^(a)	Total
Nebraska	227,000	11,000	238,000
Kansas	9,000	7,000	16,000
Oklahoma	14,000	17,000	31,000
Texas	10,000	1,000	11,000
North Dakota	4,000	5,000	9,000
Other	15,000	4,000	19,000
	279,000	45,000	324,000

_________________________


^(a)	Excludes approximately 8,000 net acres of overriding royalty interests.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Interest Rate Sensitivity

Our interest rate risk is principally related to our variable-rate debt. Interest rate changes impact earnings due to the resulting increase or decrease in our variable-rate debt, which was $68,724,000 at third quarter-end 2015.

The following table illustrates the estimated effect on our pre-tax income of immediate, parallel, and sustained shifts in interest rates for the next 12 months on our variable-rate debt at third quarter-end 2015. This estimate assumes that debt reductions from contractual payments will be replaced with short-term, variable-rate debt; however, that may not be the financing alternative we choose.



	Third Quarter-End
Change in Interest Rates	2015
	(In thousands)
2%	$	(1,257	)
1%	$	(687	)
(1)%	$	687
(2)%	$	1,374

Foreign Currency Risk

We have no exposure to foreign currency fluctuations.

Commodity Price Risk

We have exposure to commodity price fluctuations from our oil and gas production which can materially affect our revenues and cash flows. The prices we receive for our production depend on numerous factors beyond our control. Based on our first nine months 2015 production, a 10% decrease in our average realized oil and gas prices would have reduced our oil and gas production revenues by $4,154,000. To manage our exposure to commodity price risks associated with the sale of oil and gas, we may periodically enter into derivative hedging transactions for a portion of our estimated production. We do not have any commodity derivative positions outstanding at third quarter-end 2015.

Item 4. Controls and Procedures

(a) Disclosure Controls and Procedures

Our management, with the participation of the Chief Executive Officer and Chief Financial Officer, has evaluated the effectiveness of our disclosure controls and procedures (as such term is defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (or the Exchange Act)) as of the end of the period covered by this report. Based on such evaluation, our Chief Executive Officer and Chief Financial Officer have concluded that, as of the end of such period, our disclosure controls and procedures are effective in recording, processing, summarizing and reporting, on a timely basis, information required to be disclosed by us in the reports that we file or submit under the Exchange Act and are effective in ensuring that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is

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accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.

(b) Changes in Internal Control over Financial Reporting

There have been no changes in our internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) during the period covered by this report that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II—OTHER INFORMATION

Item 1. Legal Proceedings

We are involved directly or through ventures in various legal proceedings that arise from time to time in the ordinary course of doing business. We believe we have established adequate reserves for any probable losses and that the outcome of any of the proceedings should not have a material adverse effect on our financial position, long-term results of operations or cash flows. It is possible, however, that circumstances beyond our control or significant subsequent developments could result in additional charges related to these matters that could be significant to results of operations or cash flow in any single accounting period.

Item 1A. Risk Factors

There are no material changes from the risk factors disclosed in our 2014 Annual Report on Form 10-K, as supplemented by our prior period 2015 Quarterly Reports on Form 10-Q.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

Issuer Purchases of Equity Securities ^(a)



Period	Total Number of Shares Purchased	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Maximum Number of Shares That May Yet be Purchased Under the Plans or Programs
Month 7 (7/1/2015 — 7/31/2015)	—	$	—	—	3,506,668
Month 8 (8/1/2015 — 8/31/2015)	—	$	—	—	3,506,668
Month 9 (9/1/2015 — 9/30/2015)	—	$	—	—	3,506,668
	—	$	—	—

_________________________

^(a)

On February 11, 2009, we announced that our Board of Directors authorized the repurchase of up to 7,000,000 shares of our common stock. We have purchased 3,493,332 shares under this authorization, which has no expiration date. We have no repurchase plans or programs that expired during the period covered by the table above and no repurchase plans or programs that we intend to terminate prior to expiration or under which we no longer intend to make further purchases.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

None.

Item 6. Exhibits

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Exhibit		Description

3.1		Certificate of Amendment to Amended and Restated Certificate of Incorporation of the Company dated May 12, 2015.

3.2		Fifth Amendment to the Amended and Restated Bylaws of the Company (incorporated by reference to Exhibit 3.1 of the Company's Current Report on Form 8-K filed with the Commission on September 28, 2015).

10.1		Limited Waiver and Amendment regarding the Third Amended and Restated Revolving and Term Credit Agreement dated September 30, 2015, by and among the Company; Forestar (USA) Real Estate Group Inc. and certain of its wholly-owned subsidiaries signatory thereto; KeyBank National Association, as lender, swing line lender and agent; the lenders party thereto; and the other parties thereto (incoporated by reference to Exhibit 10.1 of the Company's Current Report on Form 8-K filed with the Commission on October 6, 2015).

10.2		Construction Loan Agreement between FMF Morehead LLC and PNC Bank, National Association dated October 16, 2015 (incorporated by reference to Exhibit 10.1 of the Company’s Current Report on Form 8-K filed with the Commission on October 21, 2015).

10.3		Employment Agreement between the Company and Philip J. Weber dated October 21, 2015 (incorporated by reference to Exhibit 10.1 of the Company’s Current Report on Form 8-K filed with the Commission on October 26, 2015).

10.4		Separation Agreement and Release of All Claims between the Company and Christopher L. Nines dated October 21, 2015 (incorporated by reference to Exhibit 10.2 of the Company’s Current Report on Form 8-K filed with the Commission on October 26, 2015).

31.1		Certification of Chief Executive Officer pursuant to Exchange Act rule 13a-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2		Certification of Chief Financial Officer pursuant to Exchange Act rule 13a-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1		Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

32.2		Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

101.1		The following materials from Forestar’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2015, formatted in XBRL (Extensible Business Reporting Language): (i) Consolidated Balance Sheets, (ii) Consolidated Statements of Income and Comprehensive Income, (iii) Consolidated Statements of Cash Flows, and (iv) Notes to Consolidated Financial Statements.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



	FORESTAR GROUP INC.

Date: November 6, 2015	By:	/s/ Charles D. Jehl
		Charles D. Jehl
		Chief Financial Officer

	By:	/s/ Sabita C. Reddy
		Sabita C. Reddy
		Principal Accounting Officer

Forestar Group - 10-Q quarterly report FY2015 Q3

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PART I — FINANCIAL INFORMATION	3
Item 1. Financial Statements (Unaudited)	3
Consolidated Balance Sheets	3
Consolidated Statements of Income and Comprehensive Income	4
Consolidated Statements of Cash Flows	5
Notes to Consolidated Financial Statements	6
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	20
Item 3. Quantitative and Qualitative Disclosures About Market Risk	40
Item 4. Controls and Procedures	40
PART II — OTHER INFORMATION	41
Item 1. Legal Proceedings	41
Item 1A. Risk Factors	41
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	41
Item 3. Defaults Upon Senior Securities	41
Item 4. Mine Safety Disclosures	41
Item 5. Other Information	41
Item 6. Exhibits	41
SIGNATURES	43