Triangle Petroleum (TPLMQ) 10-Q 8 Dec 15 2016 Q3 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	9 Months Ended
	Oct. 31, 2015	Dec. 07, 2015
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Oct. 31, 2015
Document Fiscal Period Focus	Q3
Document Fiscal Year Focus	2,016
Entity Registrant Name	Triangle Petroleum Corp
Entity Central Index Key	1,281,922
Current Fiscal Year End Date	--01-31
Entity Filer Category	Accelerated Filer
Entity Current Reporting Status	Yes
Entity Common Stock, Shares Outstanding		75,713,104

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Oct. 31, 2015	Jan. 31, 2015
CURRENT ASSETS
Cash and cash equivalents	$ 36,250	$ 67,871
Accounts receivable	63,494	171,911
Commodity derivatives	8,329	54,775
Other current assets	8,667	14,952
Total current assets	116,740	309,509
Oil and natural gas properties, at cost, full cost method of accounting:
Proved properties	1,332,121	1,159,584
Unproved properties and properties under development, not being amortized	107,226	142,896
Total oil and natural gas properties	1,439,347	1,302,480
Accumulated amortization	(909,998)	(176,390)
Net oil and natural gas properties	529,349	1,126,090
Oilfield services equipment - net	64,210	87,549
Other property and equipment, net	47,924	47,367
Net property, plant and equipment	641,483	1,261,006
Other Assets
Deferred loan costs	12,782	14,038
Equity investment	73,389	64,411
Commodity derivatives	463
Other	5,601	5,906
Total other assets	92,235	84,355
Total assets	850,458	1,654,870
CURRENT LIABILITIES
Accounts payable and accrued capital expenditures	82,670	176,182
Other accrued liabilities	46,006	73,440
Current portion of long-term debt	1,641	503
Interest payable	8,717	2,250
Deferred income taxes		19,467
Total current liabilities	139,034	271,842
LONG-TERM LIABILITIES
Borrowings on credit facilities	243,402	224,159
TUSA 6.75% notes	415,889	429,500
5% convertible note	141,037	135,877
Other notes and mortgages payable	12,566	10,102
Deferred income taxes		33,974
Commodity derivatives	470
Other	4,585	4,398
Total liabilities	$ 956,983	$ 1,109,852
COMMITMENT AND CONTINGENCIES
STOCKHOLDERS' EQUITY (DEFICIT)
Common stock, $0.00001 par value, 140,000,000 shares authorized; 75,174,442 and 75,679,808 shares issued and outstanding at January 31, 2015 and October 31, 2015, respectively	$ 1	$ 1
Additional paid-in capital	554,018	545,017
Retained earnings (accumulated deficit)	(660,544)
Total stockholders' equity (deficit)	(106,525)	545,018
Total liabilities and stockholders’ equity (deficit)	$ 850,458	$ 1,654,870

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Oct. 31, 2015	Jan. 31, 2015
Common stock, par value	$ 0.00001	$ 0.00001
Common stock, shares authorized	140,000,000	140,000,000
Common stock, shares issued	75,679,808	75,174,442
Common stock, shares outstanding	75,679,808	75,174,442
Convertible Notes [Member]
Debt instrument, interest rate	5.00%	5.00%
TUSA 6.75% Notes [Member]
Debt instrument, interest rate	6.75%	6.75%

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Oct. 31, 2015	Oct. 31, 2014	Oct. 31, 2015	Oct. 31, 2014
REVENUES
Oil, natural gas and natural gas liquids sales	$ 42,871	$ 80,139	$ 145,912	$ 221,479
Oilfield services	22,273	94,057	147,253	194,488
Total revenues	65,144	174,196	293,165	415,967
EXPENSES:
Lease operating expenses	10,135	7,317	32,413	18,741
Gathering, transportation and processing	6,537	4,380	19,526	11,915
Production taxes	4,052	8,637	14,288	23,662
Depreciation and amortization	28,396	32,471	98,446	80,465
Impairment of oil and natural gas properties	261,000		659,000
Accretion of asset retirement obligations	75	259	222	324
Oilfield services	21,700	70,805	133,883	142,069
General and administrative, net of amounts capitalized	18,434	16,793	47,882	44,285
Total operating expenses	350,329	140,662	1,005,660	321,461
INCOME (LOSS) FROM OPERATIONS	(285,185)	33,534	(712,495)	94,506
OTHER INCOME (EXPENSE):
Interest expense, net	(9,877)	(8,984)	(28,849)	(15,874)
Amortization of deferred loan costs	(852)	(479)	(2,199)	(1,838)
Gain on extinguishment of debt	4,175		5,331
Realized commodity derivative gains (losses)	27,857	688	64,341	(3,084)
Unrealized commodity derivative gains (losses)	(21,044)	19,134	(46,453)	16,529
Equity investment income (loss)	450	393	1,848	457
Gain (loss) on equity investment derivatives	(1,118)	742	3,398	3,662
Gain on Caliber capital transactions			2,880
Other income (expense), net	(1,405)	(330)	(1,787)	(216)
Total other income (expense)	(1,814)	11,164	(1,490)	(364)
INCOME (LOSS) BEFORE INCOME TAXES	(286,999)	44,698	(713,985)	94,142
INCOME TAX PROVISION (BENEFIT)		19,300	(53,441)	39,650
NET INCOME (LOSS)	(286,999)	25,398	(660,544)	54,492
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCKHOLDERS	$ (286,999)	$ 25,398	$ (660,544)	$ 54,492
Earnings (loss) per common share outstanding:
Basic	$ (3.80)	$ 0.30	$ (8.76)	$ 0.64
Diluted	$ (3.80)	$ 0.26	$ (8.76)	$ 0.55
Weighted average common shares outstanding:
Basic	75,588	85,242	75,419	85,769
Diluted	75,588	102,954	75,419	103,421

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Oct. 31, 2015	Oct. 31, 2014	Oct. 31, 2015	Oct. 31, 2014	Jan. 31, 2015	Jan. 31, 2014
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$ (286,999)	$ 25,398	$ (660,544)	$ 54,492
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	28,396	32,471	98,446	80,465
Impairment of oil and natural gas properties	261,000		659,000
Share-based compensation			13,900	5,642
Interest expense not paid in cash			5,160	4,910
Amortization of deferred loan costs	852	479	2,199	1,838
Gain on extinguishment of debt	(4,175)		(5,331)
Accretion of asset retirement obligations	75	259	222	324
Unrealized commodity derivative (gains) losses	21,044	(19,134)	46,453	(16,529)
Equity investment income (loss)	(450)	(393)	(1,848)	(457)
Gain on equity investment derivatives			(3,398)	(3,662)
Gain on Caliber capital transactions			(2,880)
Loss on sale of equipment			1,077
Deferred income taxes			(53,441)	38,823
Changes in related current assets and current liabilities:
Accounts receivable			108,417	(92,317)
Other current assets			6,285	(157)
Accounts payable and accrued liabilities			(69,241)	28,854
Asset retirement expenditures			(1,521)	(137)
Other			(481)	334
Cash provided by operating activities			142,474	102,423
CASH FLOWS FROM INVESTING ACTIVITIES:
Oil and natural gas expenditures			(182,198)	(218,313)
Acquisitions of oil and natural gas properties			(837)	(132,843)
Purchase of oil field services equipment			(7,275)	(41,263)
Purchase of other property and equipment			(4,661)	(12,079)
Sale of oil and natural gas properties			6,000	1,500
Proceeds from sale of equipment			7,468
Other				188
Cash used in investing activities			(181,503)	(402,810)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from credit facilities			183,367	313,616
Repayments of credit facilities			(164,124)	(433,515)
Proceeds from notes payable			4,032	450,000
Repayments of other notes and mortgages payable			(463)	(300)
Early extinguishment of repurchased debt			(8,280)
Debt issuance costs			(943)	(12,714)
Payments to settle tax on vested restricted stock units			(834)	(2,666)
Distributions to RockPile B unit holders			(4,318)
Purchase of vested RockPile B units from unit holders			(1,029)
Common stock repurchased and retired				(42,548)
Cash provided by financing activities			7,408	271,873
NET INCREASE (DECREASE) IN CASH AND EQUIVALENTS					$ (31,621)	$ (28,514)
CASH AND EQUIVALENTS, BEGINNING OF PERIOD			67,871	81,750	81,750
CASH AND EQUIVALENTS, END OF PERIOD	$ 36,250	$ 53,236	$ 36,250	$ 53,236	$ 67,871	$ 81,750

Consolidated Statement of Stock

Consolidated Statement of Stockholders' Equity - 9 months ended Oct. 31, 2015 - USD ($) $ in Thousands	Common Stock [Member]	Additional Paid-In Capital [Member]	Accumulated Deficit [Member]	Total
Balance at Jan. 31, 2015	$ 1	$ 545,017		$ 545,018
Balance, shares at Jan. 31, 2015	75,174,442			75,174,442
Vesting of restricted stock units (net of shares surrendered for taxes)		(834)		$ (834)
Vesting of restricted stock units (net of shares surrendered for taxes), shares	505,366
Share-based compensation		15,182		15,182
Distributions to RockPile B-Unit holders		(4,318)		(4,318)
Purchase of vested RockPile B units from unit holders		(1,029)		(1,029)
Net income (loss) for the year			$ (660,544)	(660,544)
Balance at Oct. 31, 2015	$ 1	$ 554,018	$ (660,544)	$ (106,525)
Balance, shares at Oct. 31, 2015	75,679,808			75,679,808

Description Of Business

Description Of Business	9 Months Ended
	Oct. 31, 2015
Basis Of Presentation [Abstract]
Description Of Business	1. DESCRIPTION OF BUSINESS Triangle Petroleum Corporation (“Triangle,” the “Company,” “we,” “us,” “our,” or “ours”) is an independent energy holding company with three principal lines of business: oil and natural gas exploration, development, and production; oilfield services; and midstream services. We hold leasehold interests and conduct our operations in the Williston Basin of North Dakota and Montana. Our core focus area is predominantly located in McKenzie and Williams Counties, North Dakota, and eastern Roosevelt and Sheridan Counties, Montana. We conduct our exploration and production operations through our wholly-owned subsidiary, Triangle USA Petroleum Corporation (“TUSA”). In June 2011, we formed RockPile Energy Services, LLC (“RockPile”), a wholly-owned subsidiary, which provides oilfield and complementary well completion services to oil and natural gas exploration and production companies predominantly in the Williston Basin. RockPile began operations in July 2012. In September 2012, through our wholly-owned subsidiary, Triangle Caliber Holdings, LLC, we formed Caliber Midstream Partners, L.P. (“Caliber”), an unconsolidated joint venture with First Reserve Energy Infrastructure Fund. Caliber was formed for the purpose of providing oil, natural gas and water transportation and related services to oil and natural gas exploration and production companies in the Williston Basin. The Company, through its wholly-owned subsidiary, Elmworth Energy Corporation (“Elmworth”), previously conducted insignificant exploration and production activities in Canada. Elmworth has since sold all leasehold interests except for acreage in the Maritimes Basin of Nova Scotia. Elmworth has ceased all exploration and production activities in Canada except for reclaiming five wells, the drilling site and brine ponds on its Nova Scotia acreage. Elmworth has no proved reserves and its oil and natural gas properties were fully impaired as of January 31, 2012.

Summary Of Significant Accounti

Summary Of Significant Accounting Policies	9 Months Ended
	Oct. 31, 2015
Summary Of Significant Accounting Policies [Abstract]
Summary Of Significant Accounting Policies	2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Basis of Presentation. These unaudited condensed consolidated financial statements and related notes are presented in accordance with accounting principles generally accepted in the United States of America (“GAAP”), and are expressed in U.S. dollars. Preparation in accordance with GAAP requires us to (i) adopt accounting policies within accounting rules set by the Financial Accounting Standards Board (“FASB”) and by the Securities and Exchange Commission (“SEC”), and (ii) make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses, and other disclosed amounts. Certain information and footnote disclosures normally included in our annual financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to SEC rules and regulations. We believe the disclosures made are adequate to make the information not misleading. We recommend that these unaudited condensed consolidated financial statements be read in conjunction with our audited consolidated financial statements and notes included in our Annual Report on Form 10-K for the fiscal year ended January 31, 2015, as filed with the SEC (“Fiscal 2015 Form 10-K”). In the opinion of management, all material adjustments considered necessary for a fair presentation of the Company’s interim results have been reflected. All such adjustments are considered to be of a normal recurring nature. The results for interim periods are not necessarily indicative of annual results. No condensed consolidated statement of comprehensive income (loss) is presented because the Company had no comprehensive income or loss activity in the periods presented . Use of Estimates. In the course of preparing its condensed consolidated financial statements, management makes various assumptions, judgments, and estimates to determine the reported amount of assets, liabilities, revenue, and expenses, and in the disclosures of commitments and contingencies. Changes in these assumptions, judgments and estimates will occur as a result of the passage of time and the occurrence of future events and, accordingly, actual results could differ from amounts initially established. Significant areas requiring the use of assumptions, judgments and estimates include (i) oil and natural gas reserves; (ii) cash flow estimates used in ceiling tests of oil and natural gas properties; (iii) depreciation and amortization; (iv) impairment of unproved properties and other assets; (v) assigning fair value and allocating purchase price in connection with business combinations; (vi) accrued revenue and related receivables; (vii) valuation of commodity derivative instruments and equity derivative instruments; (viii) accrued expenses and related liabilities; (ix) valuation of share-based payments and (x) income taxes. Although management believes these estimates are reasonable, actual results could differ from these estimates. The Company has evaluated subsequent events and transactions for matters that may require recognition or disclosure in these condensed consolidated financial statements. Principles of Consolidation. The accounts of Triangle and its wholly-owned subsidiaries are presented in the accompanying condensed consolidated financial statements. All significant intercompany transactions and balances are eliminated in consolidation. Triangle generally uses the equity method of accounting for investments in entities in which Triangle has an ownership between 20% and 50% and exercises significant influence. The investment in Caliber is accounted for utilizing the equity method of accounting . Oil and Natural Gas Properties. We use the full cost method of accounting, which involves capitalizing all acquisition, exploration, exploitation and development costs of oil and natural gas properties. Once we incur costs, they are recorded in the amortizable pool of proved properties or in unproved properties, collectively, the full cost pool. We review our unproved oil and natural gas property costs on a quarterly basis to assess for impairment or the need to transfer unproved costs to proved properties as a result of extensions or discoveries from drilling operations. At the end of each quarterly period, we must compute a limitation on capitalized costs, which is equal to the sum of the present value of estimated future net revenues from our proved reserves by applying the average price as prescribed by the SEC (unweighted arithmetic average of commodity prices in effect on the first day of each of the previous twelve months), less estimated future expenditures (based on current costs) to develop and produce the proved reserves, discounted at 10%, plus the cost of properties not being amortized and the lower of cost or estimated fair value of unproved properties included in the costs being amortized, net of income tax effects. We then conduct a “ceiling test” that compares the net book value of the full cost pool, after taxes, to the full cost ceiling limitation. In the event the full cost ceiling limitation is less than the full cost pool, we are required to record an impairment of our oil and natural gas properties. The ceiling test for each period presented was based on the following average spot prices, in each case adjusted for quality factors and regional differentials to derive estimated future net revenues. Prices presented in the table below are the trailing 12 month simple average spot prices at the first of the month for natural gas at Henry Hub (“HH”) and West Texas Intermediate (“WTI”) crude oil at Cushing, Oklahoma. The fluctuations demonstrate the volatility in oil and natural gas prices between each of the periods and have a significant impact on our ceiling test limitation. Trailing 12 Month Simple Average Spot Prices January 31, 2015 April 30, 2015 July 31, 2015 October 31, 2015 Oil (per Bbl) $ $ $ $ Natural gas (per MMbtu) $ $ $ $ Natural gas liquids (per Bbl) $ $ $ $ We recognized impairments to our proved oil and natural gas properties of $261.0 million and $659.0 million for the three and nine months ended October 31, 2015, respectively, primarily due to the decline in oil, natural gas and natural gas liquids prices. We did not recognize impairments to our proved oil and natural gas properties for the three and nine months ended October 31, 2014. We will incur additional impairments to our oil and natural gas properties in future quarters if prices stay at current levels or decline further. The amount of any future impairment is difficult to predict, and will depend, in part, upon future oil, natural gas and natural gas liquids prices to be utilized in the ceiling test, estimates of proved reserves and future capital expenditures and operating costs. The ceiling limitation is not intended to be indicative of the fair market value of our proved reserves or future results. Impairment charges do not affect cash flow from operating activities but do adversely affect our net income and stockholders’ equity. Any recorded impairment of oil and natural gas properties is not reversible at a later date. The evaluation of impairment of our oil and natural gas properties includes estimates of proved reserves. There are numerous uncertainties inherent in estimating quantities of proved reserves, in projecting the future rates of production and in the timing of development activities. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Results of drilling, testing and production subsequent to the date of the estimate may justify revisions of such estimate. Accordingly, reserve estimates often differ from the quantities of oil and natural gas that are ultimately recovered. Oilfield Services Equipment and Other Property and Equipment . Oilfield services equipment and other property and equipment consisted of the following as of: (in thousands) January 31, 2015 October 31, 2015 Oilfield services equipment $ $ Accumulated depreciation Depreciable assets, net Assets not placed in service Total oilfield services equipment, net $ $ Land $ $ Building and leasehold improvements Vehicles Software, computers and office equipment Capital leases Accumulated depreciation Depreciable assets, net Assets not placed in service Total other property and equipment, net $ $ Income Taxes . The Company computes its quarterly tax provision using the effective tax rate method based on applying the anticipated annual effective rate to its year-to-date income or loss, except for discrete items. Income tax on discrete items is computed and recorded in the period in which the specific transaction occurs. As noted above, the carrying value of our oil and natural gas properties exceeded the calculated value of the ceiling limitation resulting in an impairment of $659.0 million for the nine months ended October 31, 2015. This impairment results in Triangle having three years of cumulative historical pre-tax losses and a net deferred tax asset position. Additionally, Triangle will likely be required to recognize additional impairments of its oil and natural gas properties in future periods if oil and natural gas prices remain at current levels or continue to decline and such impairments will likely be material. Triangle also had net operating loss carryovers (“NOLs”) for federal income tax purposes of $ 143.1 million at January 31, 2015. These losses and expected future losses were a key consideration that led Triangle to provide a valuation allowance against its net deferred tax assets as of April 30, July 31, and October 31, 2015 since it cannot conclude that it is more likely than not that its net deferred tax assets will be fully realized in future periods. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. At each reporting period, management considers the scheduled reversal of deferred tax liabilities, available taxes in carryback periods, tax planning strategies and projected future taxable income in making this assessment. Future events or new evidence which may lead the Company to conclude that it is more likely than not that its net deferred tax assets will be realized include, but are not limited to, cumulative historical pre-tax earnings, sustained or continued improvements in oil prices, and taxable events that could result from one or more transactions. The Company will continue to evaluate whether the valuation allowance is needed in future reporting periods. In the first quarter of fiscal year 2016 the Company recorded the benefit of reversing its net deferred tax liability. As long as the Company concludes that it will continue to have a need for a valuation allowance against its net deferred tax assets, the Company likely will not have any additional income tax expense or benefit other than for federal a lternative minimum tax expense or for state income taxes. As of October 31, 2015, the Company had no unrecognized tax benefits. The Company’s management does not believe that there are any new items or changes in facts or judgments that should impact the Company’s position during the first nine months of fiscal year 2016. Given the substantial net operating loss carryforwards at both the federal and state levels, neither significant interest expense nor penalties charged for any examining agents’ tax adjustments of income tax returns are anticipated, as any such adjustments would very likely only adjust net operating loss carryforwards. Earnings per Share. Basic earnings per common share is computed by dividing net income (loss) attributable to the common stockholders by the weighted average number of common shares outstanding during the reporting period. Diluted earnings per common share reflects increases in average shares outstanding from the potential dilution, under the treasury stock method, that could occur upon (i) exercise of stock options, (ii) vesting of restricted stock units, and (iii) conversion of convertible debt. The treasury stock method assumes exercise, vesting or conversion at the beginning of a period for securities outstanding at the end of a period. Also, the treasury stock method for calculating dilution assumes that the increase in the number of shares is reduced by the number of shares which could have been repurchased by the Company at the quarter’s average stock price using assumed proceeds from (a) the exercise cost of the options and (b) the foregone future compensation expense of hypothetical early vesting of the outstanding restricted stock units. The assumed proceeds are adjusted for income tax effects. In the event of a net loss, no potential common shares are included in the calculation of shares outstanding, as their inclusion would be anti-dilutive. The following table details the weighted average dilutive and anti-dilutive securities, which consist of options and unvested restricted stock, for the periods presented : For the Three Months Ended For the Nine Months Ended October 31, October 31, (in thousands) 2014 2015 2014 2015 Dilutive — — Anti-dilutive shares The table below sets forth the computations of net income (loss) per common share (basic and diluted) for the periods presented: For the Three Months Ended For the Nine Months Ended October 31, October 31, (in thousands, except per share data) 2014 2015 2014 2015 Net income (loss) attributable to common stockholders $ $ $ $ Effect of 5% convertible note conversion — — Net income (loss) attributable to common stockholders after effect of 5% convertible note conversion $ $ $ $ Basic weighted average common shares outstanding Effect of dilutive securities — — Diluted weighted average common shares outstanding Basic net income (loss) per share $ $ $ $ Diluted net income (loss) per share $ $ $ $ Reclassifications . Certain amounts in our unaudited condensed consolidated statements of operations for the three and nine months ended October 31, 2014 have been reclassified to conform to the financial statement presentation for the periods ended October 31, 2015. The unaudited condensed consolidated statements of operations reclassifications relate to the break out of amortization of deferred loan costs from interest expense and amounts related to revisions in the Elmworth abandonment obligation that were reclassified from accretion of asset retirement obligations to depreciation and amortization expense. Such reclassifications had no impact on consolidated total assets, stockholders’ equity or net income previously repor ted .

Segment Reporting

Segment Reporting	9 Months Ended
	Oct. 31, 2015
Segment Reporting [Abstract]
Segment Reporting	3. SEGMENT REPORTING We conduct our operations within two reportable operating segments. We identified each segment based on management’s responsibility and the nature of their products, services, and costs. There are no major distinctions in geographical areas served as nearly all operations are in the Williston Basin of the United States. The Exploration and Production operating segment, consisting of TUSA and several insignificant oil and natural gas subsidiaries, is responsible for finding and producing oil and natural gas. The Oilfield Services segment, consisting of RockPile and its subsidiaries, is responsible for a variety of oilfield and well completion services for both TUSA-operated wells and wells operated by third-parties. Corporate and Other includes our corporate office and several subsidiaries that management does not consider to be part of the Exploration and Production or Oilfield Services segments. Also included in Corporate and Other are our results from our investment in Caliber, including any changes in the fair value of our equity investment derivatives. Management evaluates the performance of our segments based upon net income (loss) before income taxes. The following tables present selected financial information for our operating segments for the three months ended October 31, 2015 and 2014. For the Three Months Ended October 31, 2015 Exploration Corporate and Oilfield and Consolidated (in thousands) Production Services Other Eliminations Total Revenues: Oil, natural gas and natural gas liquids sales $ $ — $ — $ — $ Oilfield services for third parties — — Intersegment revenues — — — Total revenues — Expenses: Lease operating and production taxes — — — Gathering, transportation and processing — — — Depreciation and amortization Impairment of oil and natural gas properties — — — Accretion of asset retirement obligations — — — Oilfield services — — General and administrative, net of amounts capitalized: Salaries and benefits — Share-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense) Income (loss) before income taxes $ $ $ $ $ For the Three Months Ended October 31, 2014 Exploration Corporate and Oilfield and Consolidated (in thousands) Production Services Other Eliminations Total Revenues: Oil, natural gas and natural gas liquids sales $ $ — $ — $ — $ Oilfield services for third parties — — Intersegment revenues — — — Total revenues — Expenses: Lease operating and production taxes — — — Gathering, transportation and processing — — — Depreciation and amortization Accretion of asset retirement obligations — — — Oilfield services — — General and administrative, net of amounts capitalized: Salaries and benefits — Share-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense) Net income (loss) before income taxes $ $ $ $ $ The following tables present selected financial information for our operating segments for the nine months ended October 31, 2015 and 2014. For the Nine Months Ended October 31, 2015 Exploration Corporate and Oilfield and Consolidated (in thousands) Production Services Other Eliminations Total Revenues: Oil, natural gas and natural gas liquids sales $ $ — $ — $ — $ Oilfield services for third parties — — Intersegment revenues — — — Total revenues — Expenses: Lease operating and production taxes — — — Gathering, transportation and processing — — — Depreciation and amortization Impairment of oil and natural gas properties — — — Accretion of asset retirement obligations — — — Oilfield services — — General and administrative, net of amounts capitalized: Salaries and benefits — Share-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense) Income (loss) before income taxes $ $ $ $ $ As of October 31, 2015: Net oil and natural gas properties $ $ — $ — $ $ Oilfield services equipment, net $ — $ $ — $ — $ Other property and equipment, net $ $ $ $ — $ Total assets $ $ $ $ $ Total liabilities $ $ $ $ $ For the Nine Months Ended October 31, 2014 Exploration Corporate and Oilfield and Consolidated (in thousands) Production Services Other Eliminations Total Revenues: Oil, natural gas and natural gas liquids sales $ $ — $ — $ $ Oilfield services for third parties — — Intersegment revenues — — — Total revenues — Expenses: Lease operating and production taxes — — — Gathering, transportation and processing — — — Depreciation and amortization Accretion of asset retirement obligations — — — Oilfield services — — General and administrative, net of amounts capitalized: Salaries and benefits — Share-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense) Income (loss) before income taxes $ $ $ $ $ Certain income statement reclassifications were made as previously noted, as well as changes to reflect the Exploration and Production depreciation and amortization expense gross rather than net of consolidating eliminations. Eliminations and Other. For consolidation, intercompany revenues and expenses are eliminated with a corresponding reduction in Triangle’s capitalized well costs. Under the full cost method of accounting, we defer recognition of oilfield services income (intersegment revenues less cost of oilfield services and related depreciation) for wells that we operate and this deferred income is credited to proved oil and natural gas properties. In addition, we eliminate our non-operating partners’ share of oilfield services income for well completion activities on properties we operate. We also defer Caliber gross profit from our share of its income associated with services it provided that were capitalized by TUSA, by charging such gross profit against income from equity investment and crediting proved oil and natural gas properties. The above deferred income is indirectly recognized in future periods through a lower amortization rate as proved reserves are produced. For the three months ended October 31, 2015 and 2014, $(0.4) million and $2.4 million, respectively, of the depreciation and amortization elimination relates to the Exploration and Production segment and the balance relates to the Oilfield Services segment. For the nine months ended October 31, 2015 and 2014, $0.2 million and $6.7 million, respectively, of the depreciation and amortization elimination relates to the Exploration and Production segment and the balance relates to the Oilfield Services segment. These differences, as well as differing amounts for impairments, result in basis differences between the net oil and gas property amounts presented in Triangle’s financial statements compared to those presented in TUSA’s standalone financial statemen ts.

Long-Term Debt

Long-Term Debt	9 Months Ended
	Oct. 31, 2015
Long-Term Debt [Abstract]
Long-term Debt	4. LONG-TERM DEBT T he Company’s long-term debt consisted of the following as of January 31, 2015 and October 31, 2015: (in thousands) January 31, 2015 October 31, 2015 TUSA credit facility due October 2018 $ $ RockPile credit facility due March 2019 TUSA 6.75% notes due July 2022 5% convertible note Other notes and mortgages payable Total debt Less current portion of debt: Other notes and mortgages payable Total long-term debt $ $ TUSA Credit Facility. On April 11, 2013, TUSA entered into an Amended and Restated Credit Agreement, which was subsequently amended on various dates. On November 25, 2014, TUSA entered into a Second Amended and Restated Credit Agreement, which provides for a $1.0 billion senior secured revolving credit facility, with a sublimit for the issuance of letters of credit equal to $15.0 million. The TUSA credit facility has a maturity date of October 16, 2018. On April 30, 2015, TUSA entered into Amendment No. 1 to its Second Amended and Restated Credit Agreement (“Amendment No. 1”) to, among other things, replace the existing total funded debt leverage ratio with a senior secured leverage ratio, add an interest coverage ratio, and add an equity cure right for non-compliance with financial covenants. The May 2015 semi-annual redetermination of the borrowing base was conducted concurrently with the execution of Amendment No. 1, and the borrowing base was adjusted from $435.0 million to $350.0 million. The November 2015 semi-annual redetermination of the borrowing base was reaffirmed at $350.0 million. Borrowings under the TUSA credit facility bear interest, at TUSA’s option, at either (i) the adjusted base rate (the highest of (A) the administrative agent’s prime rate, (B) the federal funds rate plus 0.50% , or (C) the one month Eurodollar rate (as defined in the agreement) plus 1.0%) , plus an applicable margin that ranges between 0.50% and 1.50% , depending on TUSA’s utilization percentage of the then effective borrowing base, or (ii) the Eurodollar rate plus an applicable margin that ranges between 1.50% and 2.50% , depending on TUSA’s utilization percentage of the then effective borrowing base. The lenders will redetermine the borrowing base under the TUSA credit facility on a semi-annual basis by May 1 and November 1. In addition, each of TUSA and the lenders may request an unscheduled borrowing base redetermination twice during each calendar year. If at any time the borrowing base is less than the amount of outstanding credit exposure under the TUSA credit facility, TUSA will be required to (i) prepay the principal amount of the loans in an amount sufficient to eliminate the excess, (ii) pledge additional collateral, (iii) prepay the excess in three equal monthly installments, or (iv) any combination of options (i) through (iii). TUSA will pay a commitment fee that ranges between 0.375% and 0.50% per annum on the unused availability under the TUSA credit facility. The TUSA credit facility is collateralized by certain of TUSA’s assets, including (1) at least 80% of the adjusted engineered value of TUSA’s oil and natural gas interests evaluated in determining the borrowing base for the facility, and (2) all of the personal property of TUSA and its subsidiaries. The obligations under the TUSA credit facility are guaranteed by TUSA’s subsidiaries, but Triangle is not a guarantor . The TUSA credit facility contains various covenants and restrictive provisions that may, among other things, limit TUSA’s ability to sell assets, incur additional indebtedness, pay dividends, make investments or loans and create liens. In addition, the facility contains financial covenants requiring TUSA to maintain specified ratios of consolidated current assets to consolidated current liabilities, consolidated senior secured debt to consolidated EBITDAX, and interest to consolidated EBITDAX. As of October 31, 2015, TUSA was in compliance with all covenants under the TUSA credit facility. RockPile Credit Facility . On March 25, 2014, RockPile entered into a Credit Agreement to provide a $100.0 million senior secured revolving credit facility. On November 13, 2014, RockPile entered into Amendment No. 1 to Credit Agreement and Incremental Commitment Agreement, which amended the credit facility to increase the borrowing capacity under the facility from $100.0 million to $150.0 million. The RockPile credit facility has a maturity date of March 25, 2019. Borrowings under the RockPile credit facility bear interest, at RockPile’s option, at either (i) the alternative base rate (the highest of (a) the administrative agent’s prime rate, (b) the federal funds rate plus 0.5% , or (c) the one-month adjusted Eurodollar rate (as defined in the agreement) plus 1.0% ), plus an applicable margin that ranges between 1.5% and 2.25% , depending on RockPile’s leverage ratio as of the last day of RockPile’s most recently completed fiscal quarter, or (ii) the Eurodollar rate plus an applicable margin that ranges between 2.50% and 3.25% , depending on RockPile’s leverage ratio as of the last day of RockPile’s most recently completed fiscal quarter. RockPile pays a commitment fee that ranges between 0.375% and 0.50% per annum on the unused availability under the RockPile credit facility. RockPile also pays a per annum fee on all letters of credit issued under the RockPile credit facility, which will equal the applicable margin for loans accruing interest based on the Eurodollar rate and a fronting fee to the issuing lender equal to 0.125% of the letter of credit amount. The obligations under the RockPile credit facility are guaranteed by RockPile’s subsidiaries, but Triangle is not a guarantor. The RockPile credit facility contains financial covenants requiring RockPile to maintain specified ratios of consolidated debt to EBITDA and Adjusted EBITDA to Fixed Charges. Amendment No. 1 also modified covenants in the RockPile credit facility related to certain restrictions on the payment of dividends and distributions and increased the amount of permitted capital expenditures. As of October 31, 2015, RockPile was in compliance with all financial covenants under the RockPile credit facility. Although it is difficult to forecast future operations in this low commodity price environment, RockPile could breach its ratio of consolidated debt to EBITDA (as defined in the credit agreement) in future quarters. If RockPile were to breach this covenant in a future period, RockPile has a cure right to obtain a cash capital contribution from Triangle or another investor approved by Triangle (“Equity Cure”) on or before ten days following the date that its compliance certificates are due ( 45 days after quarter ends and 120 days after its fiscal year end) to cure such a breach. The cure amount is defined as the amount which, if added to EBITDA for the test period in which a default of the financial covenant occurred, would cause the financial covenant for such test period to be satisfied. RockPile may exercise this cure right in no more than two of any four consecutive fiscal quarters and no more than five times during the term of the credit facility. To date, RockPile has not exercised an Equity Cure right. TUSA 6.75% Notes . On July 18, 2014, TUSA entered into an Indenture (the “Indenture”) among TUSA, a TUSA wholly-owned subsidiary as guarantor , and Wells Fargo Bank, National Association, as trustee, governing the terms of TUSA’s $450.0 million aggregate principal amount of 6.75% Notes due 2022 (the “TUSA 6.75% Notes”). The TUSA 6.75% Notes were issued in a private offering exempt from the registration requirements of the Securities Act of 1933, as amended (the “Securities Act”), to qualified institutional buyers in accordance with Rule 144A and to persons outside of the United States pursuant to Regulation S under the Securities Act. The TUSA 6.75% Notes are senior unsecured obligations of TUSA and are guaranteed on a senior unsecured basis by the initial guarantor and another TUSA wholly-owned subsidiary that became a guarantor of the TUSA 6.75% Notes in early December 2014. The TUSA 6.75% Notes have not been registered under the Securities Act and may not be offered or sold in the United States absent registration or an applicable exemption from registration requirements. The TUSA 6.75% Notes bear interest at a rate of 6.75% per year, accruing from July 18, 2014. Interest on the TUSA 6.75% Notes is payable semiannually in arrears on January 15 and July 15 of each year. The TUSA 6.75% Notes will mature on July 15, 2022, subject to earlier repurchase or redemption in accordance with the terms of the Indenture. The Company incurred $10.5 million of offering costs which have been deferred and are being recognized using the effective interest method over the life of the notes. TUSA may redeem some or all of the TUSA 6.75% Notes at any time prior to July 15, 2017 at a price equal to 100% of the principal amount of the notes redeemed plus accrued and unpaid interest, if any, to the redemption date and a make-whole premium set forth in the Indenture. On or after July 15, 2017, TUSA may redeem some or all of the TUSA 6.75% Notes at any time at a price equal to 105% of the principal amount of the notes redeemed ( 103% after July 15, 2018, 102% after July 15, 2019 and 100% after July 15, 2020), plus accrued and unpaid interest, if any, to the redemption date. In addition, at any time prior to July 15, 2017, TUSA may redeem up to 35% of the aggregate principal amount of the TUSA 6.75% Notes at a specified redemption price set forth in the Indenture plus accrued and unpaid interest, if any, to the redemption date, with the net cash proceeds of certain equity offerings. If TUSA experiences certain change of control events, TUSA must offer to repurchase the TUSA 6.75% Notes at 101% of their principal amount, plus accrued and unpaid interest, if any, to the redemption date. The Indenture permits TUSA to purchase TUSA 6.75% Notes in the open market. In fiscal year 2015, TUSA repurchased TUSA 6.75% Notes with a face value of $20.5 million for $13.9 million, immediately retired the repurchased notes, and recognized a gain on extinguishment of debt of $6.6 million. During the nine months ended October 31, 2015, TUSA repurchased additional TUSA 6.75% Notes with a face value of $13.6 million for $8. 3 million, immediately retired the repurchased notes, and recognized a gain on extinguishment of debt of $5.3 million. The Indenture contains covenants that, among other things, restrict TUSA’s ability and the ability of any guarantor subsidiary to sell certain assets; make certain dividends, distributions, investments and other restricted payments; incur certain additional indebtedness and issue preferred stock; create certain liens; enter into transactions with affiliates; designate subsidiaries as unrestricted subsidiaries, and consolidate, merge or sell substantially all of TUSA’s assets. These covenants are subject to a number of important exceptions and qualifications. As of October 31, 2015, TUSA was in compliance with all covenants under the TUSA 6.75% Notes. Convertible Note. On October 31, 2012, the Company sold to NGP Triangle Holdings, LLC a 5% convertible note with an initial principal amount of $120.0 million (the “Convertible Note”) that became convertible after November 16, 2012, in whole or in part, into the Company’s common stock at a conversion rate of one share per $8.00 of outstanding balance. The Convertible Note accrues interest at a rate of 5.0% per annum, compounded quarterly, on each December 31, March 31, June 30 and September 30, and on the date of any redemption, conversion or exchange of the Convertible Note. Such interest is paid-in-kind by adding to the principal balance of the Convertible Note, provided that, after September 30, 2017, the Company has the option to make such interest payments in cash. As of October 31, 2015, $21.0 million of accrued interest has been added to the principal balance of the Convertible Note. The Convertible Note does not have a stated maturity. Following July 31, 2017, if the trading price of the Company’s common stock exceeds $11.00 per share for 20 consecutive trading days and certain trading volume requirements are met, the Company can elect to redeem all (but not less than all) of the Convertible Note at a price equal to the outstanding principal amount plus accrued and unpaid interest, payable, at the Company’s option, in cash or common stock. Following July 31, 2020, the Company can elect to redeem all (but not less than all) of the Convertible Note at a price equal to the outstanding principal plus accrued and unpaid interest, payable in cash. Further, following July 31, 2022 or a change of control of the Company, the holder of the Convertible Note will have the right to require the Company to redeem the Convertible Note at a price equal to the outstanding principal amount plus accrued and unpaid interest, with an additional make-whole payment for scheduled interest payments remaining if such right is exercised prior to July 31, 2017.

Hedging And Commodity Derivativ

Hedging And Commodity Derivative Financial Instruments	9 Months Ended
	Oct. 31, 2015
Commodity Derivative Instruments [Abstract]
Commodity Derivative Instruments	5. HEDGING AND COMMODITY DERIVATIVE FINANCIAL INSTRUMENTS Through TUSA, the Company has entered into commodity derivative instruments utilizing costless collars and swaps to reduce the effect of price changes on a portion of our future oil production. A collar requires us to pay the counterparty if the settlement price is above the ceiling price, and requires the counterparty to pay us if the settlement price is below the floor price. The objective of the Company’s use of derivative financial instruments is to achieve more predictable cash flows in an environment of volatile oil and natural gas prices and to manage its exposure to commodity price risk. While the use of these derivative instruments limits the downside risk of adverse price movements, such use may also limit the Company’s ability to benefit from favorable price movements. The Company may, from time to time, add incremental derivatives to hedge additional production, restructure or reduce existing derivative contracts, or enter into new transactions to modify the terms of current contracts in order to realize the current value of the Company’s existing positions. The Company does not enter into derivative contracts for speculative purposes. The use of derivatives involves the risk that the counterparties to such instruments will be unable to meet the financial terms of such contracts. The Company’s derivative contracts are currently with six counterparties. The Company has netting arrangements with each counterparty that provide for the offset of payables against receivables from separate derivative arrangements with the same underlier with the counterparty in the event of contract termination. The derivative contracts may be terminated by a non-defaulting party in the event of default by one of the parties to the agreement. The Company’s commodity derivative instruments are measured at fair value. The Company has not designated any of its derivative contracts as fair value or cash flow hedges. Therefore, the Company does not apply hedge accounting to its commodity derivative instruments. Net gains and losses on derivative activities are recorded based on the changes in the fair values of the derivative instruments. The Company’s cash flows are only impacted when the actual settlements under the commodity derivative contracts result in a payment to or from the counterparty. These settlements under the commodity derivative contracts are reflected as operating activities in the Company’s consolidated statements of cash flows. The components of commodity derivative gains (losses) in the consolidated statements of operations are as follows: For the Three Months Ended For the Nine Months Ended October 31, October 31, (in thousands) 2014 2015 2014 2015 Realized commodity derivative gains (losses) $ $ $ $ Unrealized commodity derivative gains (losses) Commodity derivative gains (losses), net $ $ $ $ The Company’s commodity derivative contracts as of October 31, 2015 are summarized below: Weighted Weighted Weighted Contract Quantity Average Average Average Type Basis (1) (Bbl/d) Put Strike Call Strike Price November 1, 2015 to January 31, 2016 Collar NYMEX $ $ n/a November 1, 2015 to January 31, 2016 Swap NYMEX n/a n/a $ February 1, 2016 to January 31, 2017 Swap NYMEX n/a n/a $ February 1, 2017 to January 31, 2018 Swap NYMEX n/a n/a $ (1) “NYMEX” refers to West Texas Intermediate crude oil prices at Cushing, Oklahoma as quoted on the New York Mercantile Exchange. In August 2015, the Company unwound certain commodity derivative swap contracts and realized a gain of $9.3 million. The early settled contracts were for 2,000 barrels of oil per day at an average fixed price of $60.34 for the period from January 1, 2016 to December 31, 2016. The estimated fair values of commodity derivatives included in the consolidated balance sheets at January 31, 2015 and October 31, 2015 are summarized below. The Company does not offset asset and liability positions with the same counterparties within the consolidated financial statements; rather, all contracts are presented at their gross estimated fair value. As of the dates indicated, the Company’s derivative assets and liabilities are presented below. These balances represent the estimated fair value of the contracts. The Company has not designated any of its derivative contracts as cash-flow hedging instruments for accounting purposes. The main headings represent the balance sheet captions for the contracts presented. (in thousands) January 31, 2015 October 31, 2015 Current Assets: Crude oil derivative contracts $ $ Other Long-Term Assets: Crude oil derivative contracts — Total derivative asset $ $ Long-Term Liabilities: Crude oil derivative contracts $ — $ Total derivative liability $ — $

Oil And Natural Gas Properties

Oil And Natural Gas Properties	9 Months Ended
	Oct. 31, 2015
Oil And Natural Gas Properties [Abstract]
Oil And Natural Gas Properties	6. ACQUISITIONS In June 2014, we acquired from Marathon Oil Company (“Marathon”) certain oil and natural gas leaseholds and related producing properties located in Williams County, North Dakota, Sheridan County, Montana, and Roosevelt County, Montana comprising approximately 41,100 net acres and various other related rights, permits, contracts, equipment and other assets for approximately $90.4 million in cash, net of certain closing adjustments of $9.6 million. The acquisition was accounted for using the acquisition method under ASC-805, Business Combinations, which requires the assets acquired and liabilities assumed to be recorded at fair value as of the acquisition date of June 30, 2014. The following unaudited pro forma financial information represents the combined results for the Company and the properties acquired from Marathon, in June of 2014, as if the acquisitions had occurred on February 1, 2014. For the Nine Months Ended (in thousands, except per share data) October 31, 2014 Operating revenues $ Net income (loss) $ Earnings (loss) per common share Basic $ Diluted $ Weighted average common shares outstanding: Basic Diluted The pro forma information includes the effects of adjustments for depreciation and amortization expense of $3.4 million for the nine month period ended October 31, 2014. The pro forma results do not include any cost savings that may result from the acquisition or any estimated costs that have been or will be incurred by the Company to integrate the properties acquired. The pro forma results are not necessarily indicative of what actually would have occurred if the transactions had been completed as of the beginning of the period, nor are they necessarily indicative of future results .

Equity Investment And Equity In

Equity Investment And Equity Investment Derivatives	9 Months Ended
	Oct. 31, 2015
Equity Investment [Abstract]
Equity Investment	7. EQUITY INVESTMENT AND EQUITY INVESTMENT DERIVATIVES Equity Investment . On October 1, 2012, Triangle Caliber Holdings, LLC (“Triangle Caliber Holdings”), a wholly-owned subsidiary of Triangle, entered into a joint venture with FREIF Caliber Holdings LLC (“FREIF”), a wholly-owned subsidiary of First Reserve Energy Infrastructure Fund. The joint venture entity, Caliber, was formed to provide crude oil, natural gas and water transportation and related services to the Company and third parties primarily within the Williston Basin of North Dakota and Montana. On January 31, 2015, Triangle Caliber Holdings entered into a series of agreements modifying its joint venture with FREIF. In connection with the modifications, Triangle Caliber Holdings entered into a Second Amended and Restated Contribution Agreement, dated January 31, 2015 (the “2nd A&R Contribution Agreement”), with FREIF and the general partner of Caliber, which is owned and controlled equally between Triangle Caliber Holdings and FREIF. Pursuant to the terms of the 2nd A&R Contribution Agreement, FREIF agreed to contribute an additional $34.0 million to Caliber in exchange for 2,720,000 Class A Units. FREIF funded the $34.0 million contribution, and the additional 2,720,000 Class A Units were issued, on February 2, 2015. Triangle made no capital contribution to Caliber in connection with the 2nd A&R Contribution Agreement or the issuance of the 2,720,000 Class A Units. Following the issuance, FREIF holds 17,720,000 Class A Units, representing an approximate 71.7% Class A Units ownership interest in Caliber, and Triangle Caliber Holdings holds 7,000,000 Class A Units, representing an approximate 28.3% Class A Units ownership interest in Caliber. Triangle recognized a gain in the first nine months of fiscal year 2016 of $2.9 million related to Caliber’s issuance of these 2,720,000 Class A Units to FREIF. Also pursuant to the terms of the 2nd A&R Contribution Agreement, Triangle Caliber Holdings received warrants for the purchase of an additional 3,626,667 Class A Units, and FREIF received warrants (Series 5) for the purchase of an additional 906,667 Class A Units. The warrants received by Triangle Caliber Holdings on February 2, 2015 included 2,357,334 Class A (Series 1 through 4) Warrants at strike prices and expiration dates noted below and 1,269,333 Class A (Series 6) Warrants with a strike price of $12.50 and an expiration date of February 2, 2018. The following summarizes the Company’s equity investment holdings in Caliber as of January 31, 2015 and October 31, 2015 and the strike prices for exercising warrants as of October 31, 2015: Expiration Strike Price at As of As of Date October 31, 2015 January 31, 2015 October 31, 2015 Class A Units — $ — Series 1 Warrants October 1, 2024 $ Series 2 Warrants October 1, 2024 $ Series 3 Warrants September 12, 2025 $ Series 4 Warrants September 12, 2025 $ Series 6 Warrants February 2, 2018 $ — The following summarizes the activities related to the Company’s equity investment in Caliber for the nine months ended October 31, 2015: For the Nine Months Ended (in thousands) October 31, 2015 Balance at January 31, 2015 $ Capital contributions — Distributions — Equity investment share of net income before intra-company profit eliminations Change in fair value of warrants Gain on Caliber capital transactions Balance at October 31, 2015 $ Fair value of warrants at October 31, 2015 $ Equity Investment Derivatives. At January 31, 2015 and October 31, 2015, the Company held Class A (Series 1 through Series 4 and Series 6) Warrants to acquire additional ownership in Caliber. These instruments are considered to be equity investment derivatives and are valued at each reporting period using valuation techniques for which the inputs are generally less observable than from objective sources .

Capital Stock

Capital Stock	9 Months Ended
	Oct. 31, 2015
Capital Stock [Abstract]
Capital Stock	8. CAPITAL STOCK The Company had 106.8 million shares of common stock issued or reserved for issuance at October 31, 2015. At October 31, 2015, the Company had 75.7 million shares of common stock issued and outstanding . The Company also had 1.7 million shares of common stock reserved for issuance pursuant to outstanding awards under its 2011 Omnibus Incentive Plan, 6.0 million shares of common stock reserved for issuance under its CEO Stand-Alone Stock Option Agreement, 3.1 million shares of common stock reserved for issuance pursuant to outstanding awards under its 2014 Equity Incentive Plan (the “2014 Plan”), and 2.7 million shares of reserved common stock that remained available for issuance under the 2014 Plan. Lastly, the Company had 17.6 million shares of common stock reserved for issuance pursuant to the Convertible Note. The Company’s Board of Directors (the “Board”) approved a program authorizing the repurchase of outstanding shares of the Company’s common stock in amounts equal to the aggregate of (i) $25.0 million of the Company’s common stock (“Tranche 1”), (ii) up to the number of shares of common stock authorized for issuance under the Company’s 2014 Equity Incentive Plan and its CEO Stand-Alone Stock Option Agreement (“Tranche 2”), and (iii) up to the number of shares of common stock potentially issuable, at any given time, pursuant to the paid-in-kind interest accrued on the Convertible Note (“Tranche 3”). The program stipulates that shares of common stock may be repurchased from time to time, in amounts and at prices that the Company deems appropriate, subject to market and business conditions and other considerations. The repurchase program has no expiration date and may be suspended or discontinued at any time without prior notice. There were no common stock repurchases for the three and nine months ended October 31, 2015. As of October 31, 2015, the number of shares of common stock remaining available for repurchase under the Board approved program was 5,591,645 shares.

Share-Based Compensation

Share-Based Compensation	9 Months Ended
	Oct. 31, 2015
Share-Based Compensation [Abstract]
Share-Based Compensation	9. SHARE-BASED COMPENSATION The Company has granted equity awards to officers, directors, and certain employees of the Company including restricted stock units and stock options. In addition, RockPile has granted Series B Units which represent interests in future RockPile profits. The Company measures its awards based on the award’s grant date fair value which is recognized ratably over the applicable vesting period. On May 27, 2014, the Board approved the 2014 Plan, which was approved by the Company’s stockholders on October 17, 2014. No additional awards may be granted under prior plans but all outstanding awards under prior plans shall continue in accordance with their applicable terms and conditions. The 2014 Plan authorizes the Company to issue stock options, SARs, restricted stock, restricted stock units, cash awards, and other awards to any employees, officers, directors, and consultants of the Company and its subsidiaries. The maximum number of shares of common stock issuable under the 2014 Plan is 6.0 million shares, subject to adjustment for certain transactions. For the three and nine months ended October 31, 2014 and 2015, the Company recorded share-based compensation as follows : For the Three Months Ended For the Nine Months Ended October 31, October 31, (in thousands) 2014 2015 2014 2015 Restricted stock units $ $ $ $ Stock options RockPile Series B Units Less amounts capitalized to oil and natural gas properties Compensation expense $ $ $ $ Restricted Stock Units. During the nine months ended October 31, 2015, the Company granted 1,983,843 restricted stock units as compensation to employees, officers, and directors which generally vest over one to five years. As of October 31, 2015, there was approximately $19.7 million of total unrecognized compensation expense related to unvested restricted stock units. This compensation expense is expected to be recognized over the remaining vesting period of the related awards of approximately 3.2 years on a weighted average basis. When restricted stock units vest, the holder has the right to receive one share of the Company’s common stock per vesting unit. The following table summarizes the activity for our restricted stock units during the nine months ended October 31, 201 5 : Weighted Average Number of Award Date Shares Fair Value Restricted stock units outstanding - January 31, 2015 $ Units granted $ Units forfeited $ Units vested $ Restricted stock units outstanding - October 31, 2015 $ Stock Options. There were no grants , exercises or forfeitures of stock options during the nine months ended October 31, 2015. The following table summarizes the stock options outstanding at October 31, 2015 : Remaining Exercise Price Contractual Life Number of Shares per Share (years) Outstanding Exercisable $ 7.68 $ 7.68 $ 7.68 $ 7.68 $ 7.68 $ 5.86 $ 5.86 $ 8.87 Weighted average exercise price per share $ $ Weighted average remaining contractual life As of October 31, 2015, there was approximately $12.4 million of total unrecognized compensation expense related to stock options. This compensation expense is expected to be recognized over the remaining vesting period of the related awards of approximately 2.6 years. RockPile Share-Based Compensation. RockPile currently has two classes of equity; Series A Units, which are voting units with an 8% preference, and Series B Units, which are non-voting equity awards. RockPile approved a plan that includes provisions allowing RockPile to make equity grants in the form of restricted units (“Series B Units”) pursuant to Restricted Unit Agreements. The plan authorizes RockPile to issue an aggregate of up to 6.0 million Series B Units in multiple series designated by a sequential number with the right to reissue forfeited or redeemed Series B Units. The following table summarizes the activity for RockPile’s Series B Units for the nine months ended October 31, 2015: Series Series Series Series Series Series B-1 units B-2 units B-3 units B-4 units B-5 units B-6 units Total Units outstanding - January 31, 2015 — — Units redeemed — — — — — — — Units granted — — — — Units forfeited — — — — Units outstanding - October 31, 2015 Vested — — Unvested — — Series B Units currently have a 1 to 44 month vesting schedule. Compensation costs are determined using a Black-Scholes option pricing model based upon the grant date calculated fair market value of the award and is recognized ratably over the applicable vesting period. As of October 31, 2015, there was approximately $2.5 million of unrecognized compensation expense related to unvested Series B Units. We expect to recognize such expense on a pro-rata basis on the Series B Units’ remaining vesting schedule.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Oct. 31, 2015
Fair Value Measurements [Abstract]
Fair Value Measurements	10. FAIR VALUE MEASUREMENTS The FASB’s ASC 820, Fair Value Measurement and Disclosure , establishes a hierarchy for inputs used in measuring fair value that maximizes the use of observable inputs and minimizes the use of unobservable inputs by requiring that the most observable inputs be used when available. Observable inputs are inputs that market participants would use in pricing the asset or liability developed based on market data obtained from sources independent of the Company. Unobservable inputs are inputs that reflect the Company’s assumptions of what market participants would use in pricing the asset or liability developed based on the best information available in the circumstances. The hierarchy is broken down into three levels based on the reliability of the inputs as follows: · Level 1: Quoted prices are available in active markets for identical assets or liabilities; · Level 2: Quoted prices in active markets for similar assets and liabilities that are observable for the asset or liability; and · Level 3: Unobservable pricing inputs that are generally less observable from objective sources, such as discounted cash flows models or valuations. The financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. The following table presents the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis as of January 31, 2015 and October 31, 2015, by level within the fair value hierarchy: As of January 31, 2015 (in thousands) Level 1 Level 2 Level 3 Total Assets: Commodity derivative assets $ — $ $ — $ Equity investment derivative assets $ — $ — $ $ Liabilities: RockPile earn-out liability $ — $ $ — $ As of October 31, 2015 (in thousands) Level 1 Level 2 Level 3 Total Assets: Commodity derivative assets $ — $ $ — $ Equity investment derivative assets $ — $ — $ $ Liabilities: Commodity derivative liabilities $ — $ $ — $ RockPile earn-out liability $ — $ $ — $ Commodity Derivative Instruments. The Company determines its estimate of the fair value of commodity derivative instruments using a market approach based on several factors, including quoted market prices in active markets, quotes from third-parties, the credit rating of each counterparty, and the Company’s own credit rating. In considering counterparty credit risk, the Company assessed the possibility of whether the counterparty to the derivative would default by failing to make any contractually required payments. The Company believes that each of its counterparties is creditworthy and has the financial resources and willingness to meet its potential repayment obligations associated with the derivative transactions. At October 31, 2015, commodity derivative instruments utilized by the Company consist of costless collars and swaps. The Company’s commodity derivative instruments are valued using public indices and are traded with third-party counterparties, but are not openly traded on an exchange. As such, the Company has classified these commodity derivative instruments as Level 2. Caliber Class A (Series 1 through Series 4 and Series 6) Warrants. The Company determines its estimate of the fair value of Caliber Class A Warrants using a Monte Carlo Simulation (“MCS”) model. For each MCS, the value of the Class A Units was forecasted at the end of each quarter based on a predetermined yield, and the strike price for the warrant is adjusted accordingly. At October 31, 2015, the fair value of the underlying Class A Units was estimated employing an income approach using a MCS model and discounted cash flows, and a market approach based on observed valuation multiples for comparable public companies. Key inputs into these valuation approaches are generally less observable than those from objective sources. Therefore, the Company has classified these instruments as Level 3. Earn-out Liability. The Company determined the estimated fair value of the earn-out liability relating to RockPile’s acquisition of Team Well Service, Inc. using a market approach based on information derived from an analysis performed for RockPile by an independent third-party. This analysis used publicly available information from market participants in the same industry, generally accepted methods for estimating an investor’s return requirements, and quoted market prices in active markets. As such, the earn-out liability has been classified as Level 2. Fair Value of Financial Instruments . The Company’s financial instruments consist primarily of cash and cash equivalents, accounts receivable and payable, derivatives and Caliber Class A Warrants (discussed above), and long-term debt. The carrying values of cash equivalents and accounts receivable and payable are representative of their fair values due to their short-term maturities. The carrying amount of the Company’s revolving credit facilities approximated fair value because the interest rate of the facilities is variable and t he fair values of the other notes and mortgages payable is not significantly different than their carrying values. The fair value of the TUSA 6.75% Notes is derived from quoted market prices (Level 1). The Convertible Note’s estimated fair value is based on discounted cash flows analysis and option pricing (Level 3). This disclosure does not impact our financial position, results of operations or cash flows. The carrying values and fair values of the Company’s debt instruments are as follows : January 31, 2015 October 31, 2015 Carrying Estimated Carrying Estimated (in thousands) Value Fair Value Value Fair Value Revolving credit facilities $ $ $ $ TUSA 6.75% notes 5% convertible note Other notes and mortgages payable

Related Party Transactions

Related Party Transactions	9 Months Ended
	Oct. 31, 2015
Related Party Transactions [Abstract]
Related Party Transactions	11. RELATED PARTY TRANSACTIONS TUSA and an affiliate of Caliber have entered into certain midstream services agreements for (i) crude oil gathering, stabilization, treating and redelivery; (ii) natural gas compression, gathering, dehydration, processing and redelivery; (iii) produced water transportation and disposal services; and (iv) fresh water transportation for TUSA’s oil and natural gas drilling and production operations. The agreements also include an acreage dedication from TUSA and a firm volume commitment by the Caliber affiliate for each service line. TUSA has agreed to deliver minimum monthly revenues derived from the fees paid by TUSA to the Caliber affiliate for volumes of oil, natural gas, produced water, and fresh water for a primary term of 15 years beginning in 2014. The aggregate minimum revenue commitment over the term of the agreements is $405.0 million, of which $315.4 million was outstanding at October 31, 2015. TUSA and an affiliate of Caliber have also entered into a gathering services agreement, pursuant to which the Caliber affiliate will provide certain gathering-related measurement services to TUSA, and a fresh water sales agreement that will make available certain volumes of fresh water for purchase by TUSA at a set per barrel fee for a primary term of five years from the in-service date in March 2015 . The fresh water sales agreement obligates TUSA to purchase all of the fresh water it requires for its drilling and operating activities exclusively from the Caliber affiliate, subject to availability, but it does not require TUSA to purchase a minimum volume of fresh water. During the nine months ended October 31, 2015, TUSA sold one salt water disposal well to an affiliate of Caliber for net proceeds of $6.0 milli on.

Supplemental Disclosures Of Cas

Supplemental Disclosures Of Cash Flow Information	9 Months Ended
	Oct. 31, 2015
Supplemental Disclosures of Cash Flow Information [Abstract]
Supplemental Disclosures of Cash Flow Information	12. SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION For the Nine Months Ended October 31, (in thousands) 2014 2015 Cash paid during the period for: Interest expense $ $ Income taxes $ $ - Non-cash investing activities: Additions (reductions) to oil and natural gas properties through: Increase (decrease) in accounts payable and accrued liabilities $ $ Capitalized stock based compensation $ $ Change in asset retirement obligations $ $

Summary Of Significant Accoun19

Summary Of Significant Accounting Policies (Policies)	9 Months Ended
	Oct. 31, 2015
Summary Of Significant Accounting Policies [Abstract]
Use of Estimates	Use of Estimates. In the course of preparing its condensed consolidated financial statements, management makes various assumptions, judgments, and estimates to determine the reported amount of assets, liabilities, revenue, and expenses, and in the disclosures of commitments and contingencies. Changes in these assumptions, judgments and estimates will occur as a result of the passage of time and the occurrence of future events and, accordingly, actual results could differ from amounts initially established. Significant areas requiring the use of assumptions, judgments and estimates include (i) oil and natural gas reserves; (ii) cash flow estimates used in ceiling tests of oil and natural gas properties; (iii) depreciation and amortization; (iv) impairment of unproved properties and other assets; (v) assigning fair value and allocating purchase price in connection with business combinations; (vi) accrued revenue and related receivables; (vii) valuation of commodity derivative instruments and equity derivative instruments; (viii) accrued expenses and related liabilities; (ix) valuation of share-based payments and (x) income taxes. Although management believes these estimates are reasonable, actual results could differ from these estimates. The Company has evaluated subsequent events and transactions for matters that may require recognition or disclosure in these condensed consolidated financial statements.
Principles of Consolidation	Principles of Consolidation. The accounts of Triangle and its wholly-owned subsidiaries are presented in the accompanying condensed consolidated financial statements. All significant intercompany transactions and balances are eliminated in consolidation. Triangle generally uses the equity method of accounting for investments in entities in which Triangle has an ownership between 20% and 50% and exercises significant influence. The investment in Caliber is accounted for utilizing the equity method of accounting
Oil And Natural Gas Properties	Oil and Natural Gas Properties. We use the full cost method of accounting, which involves capitalizing all acquisition, exploration, exploitation and development costs of oil and natural gas properties. Once we incur costs, they are recorded in the amortizable pool of proved properties or in unproved properties, collectively, the full cost pool. We review our unproved oil and natural gas property costs on a quarterly basis to assess for impairment or the need to transfer unproved costs to proved properties as a result of extensions or discoveries from drilling operations. At the end of each quarterly period, we must compute a limitation on capitalized costs, which is equal to the sum of the present value of estimated future net revenues from our proved reserves by applying the average price as prescribed by the SEC (unweighted arithmetic average of commodity prices in effect on the first day of each of the previous twelve months), less estimated future expenditures (based on current costs) to develop and produce the proved reserves, discounted at 10%, plus the cost of properties not being amortized and the lower of cost or estimated fair value of unproved properties included in the costs being amortized, net of income tax effects. We then conduct a “ceiling test” that compares the net book value of the full cost pool, after taxes, to the full cost ceiling limitation. In the event the full cost ceiling limitation is less than the full cost pool, we are required to record an impairment of our oil and natural gas properties. The ceiling test for each period presented was based on the following average spot prices, in each case adjusted for quality factors and regional differentials to derive estimated future net revenues. Prices presented in the table below are the trailing 12 month simple average spot prices at the first of the month for natural gas at Henry Hub (“HH”) and West Texas Intermediate (“WTI”) crude oil at Cushing, Oklahoma. The fluctuations demonstrate the volatility in oil and natural gas prices between each of the periods and have a significant impact on our ceiling test limitation. Trailing 12 Month Simple Average Spot Prices January 31, 2015 April 30, 2015 July 31, 2015 October 31, 2015 Oil (per Bbl) $ $ $ $ Natural gas (per MMbtu) $ $ $ $ Natural gas liquids (per Bbl) $ $ $ $ We recognized impairments to our proved oil and natural gas properties of $261.0 million and $659.0 million for the three and nine months ended October 31, 2015, respectively, primarily due to the decline in oil, natural gas and natural gas liquids prices. We did not recognize impairments to our proved oil and natural gas properties for the three and nine months ended October 31, 2014. We will incur additional impairments to our oil and natural gas properties in future quarters if prices stay at current levels or decline further. The amount of any future impairment is difficult to predict, and will depend, in part, upon future oil, natural gas and natural gas liquids prices to be utilized in the ceiling test, estimates of proved reserves and future capital expenditures and operating costs. The ceiling limitation is not intended to be indicative of the fair market value of our proved reserves or future results. Impairment charges do not affect cash flow from operating activities but do adversely affect our net income and stockholders’ equity. Any recorded impairment of oil and natural gas properties is not reversible at a later date. The evaluation of impairment of our oil and natural gas properties includes estimates of proved reserves. There are numerous uncertainties inherent in estimating quantities of proved reserves, in projecting the future rates of production and in the timing of development activities. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Results of drilling, testing and production subsequent to the date of the estimate may justify revisions of such estimate. Accordingly, reserve estimates often differ from the quantities of oil and natural gas that are ultimately recovered.
Oilfield Services Equipment and Other Property And Equipment	Oilfield Services Equipment and Other Property and Equipment . Oilfield services equipment and other property and equipment consisted of the following as of: (in thousands) January 31, 2015 October 31, 2015 Oilfield services equipment $ $ Accumulated depreciation Depreciable assets, net Assets not placed in service Total oilfield services equipment, net $ $ Land $ $ Building and leasehold improvements Vehicles Software, computers and office equipment Capital leases Accumulated depreciation Depreciable assets, net Assets not placed in service Total other property and equipment, net $ $
Income Taxes	Income Taxes . The Company computes its quarterly tax provision using the effective tax rate method based on applying the anticipated annual effective rate to its year-to-date income or loss, except for discrete items. Income tax on discrete items is computed and recorded in the period in which the specific transaction occurs. As noted above, the carrying value of our oil and natural gas properties exceeded the calculated value of the ceiling limitation resulting in an impairment of $659.0 million for the nine months ended October 31, 2015. This impairment results in Triangle having three years of cumulative historical pre-tax losses and a net deferred tax asset position. Additionally, Triangle will likely be required to recognize additional impairments of its oil and natural gas properties in future periods if oil and natural gas prices remain at current levels or continue to decline and such impairments will likely be material. Triangle also had net operating loss carryovers (“NOLs”) for federal income tax purposes of $ 143.1 million at January 31, 2015. These losses and expected future losses were a key consideration that led Triangle to provide a valuation allowance against its net deferred tax assets as of April 30, July 31, and October 31, 2015 since it cannot conclude that it is more likely than not that its net deferred tax assets will be fully realized in future periods. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. At each reporting period, management considers the scheduled reversal of deferred tax liabilities, available taxes in carryback periods, tax planning strategies and projected future taxable income in making this assessment. Future events or new evidence which may lead the Company to conclude that it is more likely than not that its net deferred tax assets will be realized include, but are not limited to, cumulative historical pre-tax earnings, sustained or continued improvements in oil prices, and taxable events that could result from one or more transactions. The Company will continue to evaluate whether the valuation allowance is needed in future reporting periods. In the first quarter of fiscal year 2016 the Company recorded the benefit of reversing its net deferred tax liability. As long as the Company concludes that it will continue to have a need for a valuation allowance against its net deferred tax assets, the Company likely will not have any additional income tax expense or benefit other than for federal a lternative minimum tax expense or for state income taxes. As of October 31, 2015, the Company had no unrecognized tax benefits. The Company’s management does not believe that there are any new items or changes in facts or judgments that should impact the Company’s position during the first nine months of fiscal year 2016. Given the substantial net operating loss carryforwards at both the federal and state levels, neither significant interest expense nor penalties charged for any examining agents’ tax adjustments of income tax returns are anticipated, as any such adjustments would very likely only adjust net operating loss carryforwards.
Earnings Per Share	Earnings per Share. Basic earnings per common share is computed by dividing net income (loss) attributable to the common stockholders by the weighted average number of common shares outstanding during the reporting period. Diluted earnings per common share reflects increases in average shares outstanding from the potential dilution, under the treasury stock method, that could occur upon (i) exercise of stock options, (ii) vesting of restricted stock units, and (iii) conversion of convertible debt. The treasury stock method assumes exercise, vesting or conversion at the beginning of a period for securities outstanding at the end of a period. Also, the treasury stock method for calculating dilution assumes that the increase in the number of shares is reduced by the number of shares which could have been repurchased by the Company at the quarter’s average stock price using assumed proceeds from (a) the exercise cost of the options and (b) the foregone future compensation expense of hypothetical early vesting of the outstanding restricted stock units. The assumed proceeds are adjusted for income tax effects. In the event of a net loss, no potential common shares are included in the calculation of shares outstanding, as their inclusion would be anti-dilutive. The following table details the weighted average dilutive and anti-dilutive securities, which consist of options and unvested restricted stock, for the periods presented : For the Three Months Ended For the Nine Months Ended October 31, October 31, (in thousands) 2014 2015 2014 2015 Dilutive — — Anti-dilutive shares The table below sets forth the computations of net income (loss) per common share (basic and diluted) for the periods presented: For the Three Months Ended For the Nine Months Ended October 31, October 31, (in thousands, except per share data) 2014 2015 2014 2015 Net income (loss) attributable to common stockholders $ $ $ $ Effect of 5% convertible note conversion — — Net income (loss) attributable to common stockholders after effect of 5% convertible note conversion $ $ $ $ Basic weighted average common shares outstanding Effect of dilutive securities — — Diluted weighted average common shares outstanding Basic net income (loss) per share $ $ $ $ Diluted net income (loss) per share $ $ $ $
Reclassifications	Reclassifications . Certain amounts in our unaudited condensed consolidated statements of operations for the three and nine months ended October 31, 2014 have been reclassified to conform to the financial statement presentation for the periods ended October 31, 2015. The unaudited condensed consolidated statements of operations reclassifications relate to the break out of amortization of deferred loan costs from interest expense and amounts related to revisions in the Elmworth abandonment obligation that were reclassified from accretion of asset retirement obligations to depreciation and amortization expense. Such reclassifications had no impact on consolidated total assets, stockholders’ equity or net income previously repor ted

Summary Of Significant Accoun20

Summary Of Significant Accounting Policies (Tables)	9 Months Ended
	Oct. 31, 2015
Summary Of Significant Accounting Policies [Abstract]
Schedule of 12 month simple avgerage spot prices	Trailing 12 Month Simple Average Spot Prices January 31, 2015 April 30, 2015 July 31, 2015 October 31, 2015 Oil (per Bbl) $ $ $ $ Natural gas (per MMbtu) $ $ $ $ Natural gas liquids (per Bbl) $ $ $ $
Schedule of Oilfield services equipment and other property and equipment	Oilfield services equipment and other property and equipment consisted of the following as of: (in thousands) January 31, 2015 October 31, 2015 Oilfield services equipment $ $ Accumulated depreciation Depreciable assets, net Assets not placed in service Total oilfield services equipment, net $ $ Land $ $ Building and leasehold improvements Vehicles Software, computers and office equipment Capital leases Accumulated depreciation Depreciable assets, net Assets not placed in service Total other property and equipment, net $ $
Schedule of weighted average dilutive and anti-dilutive securities	The following table details the weighted average dilutive and anti-dilutive securities, which consist of options and unvested restricted stock, for the periods presented : For the Three Months Ended For the Nine Months Ended October 31, October 31, (in thousands) 2014 2015 2014 2015 Dilutive — — Anti-dilutive shares
Schedule of computations of net income(loss) per common share (basic and diluted)	For the Three Months Ended For the Nine Months Ended October 31, October 31, (in thousands, except per share data) 2014 2015 2014 2015 Net income (loss) attributable to common stockholders $ $ $ $ Effect of 5% convertible note conversion — — Net income (loss) attributable to common stockholders after effect of 5% convertible note conversion $ $ $ $ Basic weighted average common shares outstanding Effect of dilutive securities — — Diluted weighted average common shares outstanding Basic net income (loss) per share $ $ $ $ Diluted net income (loss) per share $ $ $ $

Segment Reporting (Tables)

Segment Reporting (Tables)	9 Months Ended
	Oct. 31, 2015
Segment Reporting [Abstract]
Schedule Of Segment Reporting	The following tables present selected financial information for our operating segments for the three months ended October 31, 2015 and 2014. For the Three Months Ended October 31, 2015 Exploration Corporate and Oilfield and Consolidated (in thousands) Production Services Other Eliminations Total Revenues: Oil, natural gas and natural gas liquids sales $ $ — $ — $ — $ Oilfield services for third parties — — Intersegment revenues — — — Total revenues — Expenses: Lease operating and production taxes — — — Gathering, transportation and processing — — — Depreciation and amortization Impairment of oil and natural gas properties — — — Accretion of asset retirement obligations — — — Oilfield services — — General and administrative, net of amounts capitalized: Salaries and benefits — Share-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense) Income (loss) before income taxes $ $ $ $ $ For the Three Months Ended October 31, 2014 Exploration Corporate and Oilfield and Consolidated (in thousands) Production Services Other Eliminations Total Revenues: Oil, natural gas and natural gas liquids sales $ $ — $ — $ — $ Oilfield services for third parties — — Intersegment revenues — — — Total revenues — Expenses: Lease operating and production taxes — — — Gathering, transportation and processing — — — Depreciation and amortization Accretion of asset retirement obligations — — — Oilfield services — — General and administrative, net of amounts capitalized: Salaries and benefits — Share-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense) Net income (loss) before income taxes $ $ $ $ $ The following tables present selected financial information for our operating segments for the nine months ended October 31, 2015 and 2014. For the Nine Months Ended October 31, 2015 Exploration Corporate and Oilfield and Consolidated (in thousands) Production Services Other Eliminations Total Revenues: Oil, natural gas and natural gas liquids sales $ $ — $ — $ — $ Oilfield services for third parties — — Intersegment revenues — — — Total revenues — Expenses: Lease operating and production taxes — — — Gathering, transportation and processing — — — Depreciation and amortization Impairment of oil and natural gas properties — — — Accretion of asset retirement obligations — — — Oilfield services — — General and administrative, net of amounts capitalized: Salaries and benefits — Share-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense) Income (loss) before income taxes $ $ $ $ $ As of October 31, 2015: Net oil and natural gas properties $ $ — $ — $ $ Oilfield services equipment, net $ — $ $ — $ — $ Other property and equipment, net $ $ $ $ — $ Total assets $ $ $ $ $ Total liabilities $ $ $ $ $ For the Nine Months Ended October 31, 2014 Exploration Corporate and Oilfield and Consolidated (in thousands) Production Services Other Eliminations Total Revenues: Oil, natural gas and natural gas liquids sales $ $ — $ — $ $ Oilfield services for third parties — — Intersegment revenues — — — Total revenues — Expenses: Lease operating and production taxes — — — Gathering, transportation and processing — — — Depreciation and amortization Accretion of asset retirement obligations — — — Oilfield services — — General and administrative, net of amounts capitalized: Salaries and benefits — Share-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense) Income (loss) before income taxes $ $ $ $ $

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended
	Oct. 31, 2015
Long-Term Debt [Abstract]
Schedule Of Debt	(in thousands) January 31, 2015 October 31, 2015 TUSA credit facility due October 2018 $ $ RockPile credit facility due March 2019 TUSA 6.75% notes due July 2022 5% convertible note Other notes and mortgages payable Total debt Less current portion of debt: Other notes and mortgages payable Total long-term debt $ $

Hedging And Commodity Derivat23

Hedging And Commodity Derivative Financial Instruments (Tables)	9 Months Ended
	Oct. 31, 2015
Commodity Derivative Instruments [Abstract]
Schedule of components of commodity derivative gains(losses)	The components of commodity derivative gains (losses) in the consolidated statements of operations are as follows: For the Three Months Ended For the Nine Months Ended October 31, October 31, (in thousands) 2014 2015 2014 2015 Realized commodity derivative gains (losses) $ $ $ $ Unrealized commodity derivative gains (losses) Commodity derivative gains (losses), net $ $ $ $
Summary Of Derivative Instruments	The Company’s commodity derivative contracts as of October 31, 2015 are summarized below: Weighted Weighted Weighted Contract Quantity Average Average Average Type Basis (1) (Bbl/d) Put Strike Call Strike Price November 1, 2015 to January 31, 2016 Collar NYMEX $ $ n/a November 1, 2015 to January 31, 2016 Swap NYMEX n/a n/a $ February 1, 2016 to January 31, 2017 Swap NYMEX n/a n/a $ February 1, 2017 to January 31, 2018 Swap NYMEX n/a n/a $ (1) “NYMEX” refers to West Texas Intermediate crude oil prices at Cushing, Oklahoma as quoted on the New York Mercantile Exchange.
Schedule Of Derivative Instruments In Statement Of Financial Position, Fair Value	The main headings represent the balance sheet captions for the contracts presented. (in thousands) January 31, 2015 October 31, 2015 Current Assets: Crude oil derivative contracts $ $ Other Long-Term Assets: Crude oil derivative contracts — Total derivative asset $ $ Long-Term Liabilities: Crude oil derivative contracts $ — $ Total derivative liability $ — $

Oil And Natural Gas Properties

Oil And Natural Gas Properties (Tables)	9 Months Ended
	Oct. 31, 2015
Oil And Natural Gas Properties [Abstract]
Proforma Schedule For Oil And Natural Gas Acquisition	The following unaudited pro forma financial information represents the combined results for the Company and the properties acquired from Marathon, in June of 2014, as if the acquisitions had occurred on February 1, 2014. For the Nine Months Ended (in thousands, except per share data) October 31, 2014 Operating revenues $ Net income (loss) $ Earnings (loss) per common share Basic $ Diluted $ Weighted average common shares outstanding: Basic Diluted

Equity Investment And Equity 25

Equity Investment And Equity Investment Derivatives (Tables)	9 Months Ended
	Oct. 31, 2015
Equity Investment [Abstract]
Schedule Of Equity Investment In Caliber	Expiration Strike Price at As of As of Date October 31, 2015 January 31, 2015 October 31, 2015 Class A Units — $ — Series 1 Warrants October 1, 2024 $ Series 2 Warrants October 1, 2024 $ Series 3 Warrants September 12, 2025 $ Series 4 Warrants September 12, 2025 $ Series 6 Warrants February 2, 2018 $ —
Summary of activities related to company's equity investment	For the Nine Months Ended (in thousands) October 31, 2015 Balance at January 31, 2015 $ Capital contributions — Distributions — Equity investment share of net income before intra-company profit eliminations Change in fair value of warrants Gain on Caliber capital transactions Balance at October 31, 2015 $ Fair value of warrants at October 31, 2015 $

Share-Based Compensation (Table

Share-Based Compensation (Tables)	9 Months Ended
	Oct. 31, 2015
Share-Based Compensation [Abstract]
Non-Cash Stock-Based Compensation Cost	For the Three Months Ended For the Nine Months Ended October 31, October 31, (in thousands) 2014 2015 2014 2015 Restricted stock units $ $ $ $ Stock options RockPile Series B Units Less amounts capitalized to oil and natural gas properties Compensation expense $ $ $ $
Restricted Stock Units Outstanding	The following table summarizes the activity for our restricted stock units during the nine months ended October 31, 201 5 : Weighted Average Number of Award Date Shares Fair Value Restricted stock units outstanding - January 31, 2015 $ Units granted $ Units forfeited $ Units vested $ Restricted stock units outstanding - October 31, 2015 $
Stock Options Outstanding By Exercise Price	The following table summarizes the stock options outstanding at October 31, 2015 : Remaining Exercise Price Contractual Life Number of Shares per Share (years) Outstanding Exercisable $ 7.68 $ 7.68 $ 7.68 $ 7.68 $ 7.68 $ 5.86 $ 5.86 $ 8.87 Weighted average exercise price per share $ $ Weighted average remaining contractual life
Summary Of Series B Unit Activity	Series Series Series Series Series Series B-1 units B-2 units B-3 units B-4 units B-5 units B-6 units Total Units outstanding - January 31, 2015 — — Units redeemed — — — — — — — Units granted — — — — Units forfeited — — — — Units outstanding - October 31, 2015 Vested — — Unvested — —

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Oct. 31, 2015
Fair Value Measurements [Abstract]
Schedule Of Fair Value, Assets And Liabilities Measured On Recurring Basis	As of January 31, 2015 (in thousands) Level 1 Level 2 Level 3 Total Assets: Commodity derivative assets $ — $ $ — $ Equity investment derivative assets $ — $ — $ $ Liabilities: RockPile earn-out liability $ — $ $ — $ As of October 31, 2015 (in thousands) Level 1 Level 2 Level 3 Total Assets: Commodity derivative assets $ — $ $ — $ Equity investment derivative assets $ — $ — $ $ Liabilities: Commodity derivative liabilities $ — $ $ — $ RockPile earn-out liability $ — $ $ — $
Summary Of Fair Value Of Financial Instruments	The carrying values and fair values of the Company’s debt instruments are as follows : January 31, 2015 October 31, 2015 Carrying Estimated Carrying Estimated (in thousands) Value Fair Value Value Fair Value Revolving credit facilities $ $ $ $ TUSA 6.75% notes 5% convertible note Other notes and mortgages payable

Supplemental Disclosures of C28

Supplemental Disclosures of Cash Flow Information (Tables)	9 Months Ended
	Oct. 31, 2015
Supplemental Disclosures of Cash Flow Information [Abstract]
Schedule of Supplemental Cash Flow Disclosures	For the Nine Months Ended October 31, (in thousands) 2014 2015 Cash paid during the period for: Interest expense $ $ Income taxes $ $ - Non-cash investing activities: Additions (reductions) to oil and natural gas properties through: Increase (decrease) in accounts payable and accrued liabilities $ $ Capitalized stock based compensation $ $ Change in asset retirement obligations $ $

Description of Business - (Deta

Description of Business - (Details)	9 Months Ended
	Oct. 31, 2015item
Basis Of Presentation [Abstract]
Number of major focus lines of business	3

Summary of Significant Accoun30

Summary of Significant Accounting Policies - Consolidation (Details) $ in Thousands	3 Months Ended		6 Months Ended	9 Months Ended	12 Months Ended
	Oct. 31, 2015USD ($)	Apr. 30, 2015$ / MMBTU$ / bbl	Jul. 31, 2015$ / MMBTU$ / bbl	Oct. 31, 2015USD ($)$ / MMBTU$ / bbl	Jan. 31, 2015$ / MMBTU$ / bbl
Impairment charges
Impairment of oil and natural gas properties | $	$ 261,000			$ 659,000
Minimum [Member]
Equity Method Investment, Summarized Financial Information [Abstract]
Equity method ownership percentage	20.00%			20.00%
Maximum [Member]
Equity Method Investment, Summarized Financial Information [Abstract]
Equity method ownership percentage	50.00%			50.00%
Crude Oil Reserves [Member]
Trailing 12 month simple average spot prices:
Trailing 12 Month simple average spot prices		78.58	67.65	55.37	91.22
Natural Gas Reserves [Member]
Trailing 12 month simple average spot prices:
Trailing 12 Month simple average spot prices | $ / MMBTU		3.69	3.23	2.89	4.20
Natural Gas Liquids Reserves [Member]
Trailing 12 month simple average spot prices:
Trailing 12 Month simple average spot prices		41.96	34.98	26.60	50.07

Summary of Significant Accoun31

Summary of Significant Accounting Policies - Oilfield Services Equipment Schedule (Details) - USD ($) $ in Thousands	Oct. 31, 2015	Jan. 31, 2015
Property, Plant and Equipment [Line Items]
Accumulated depreciation	$ (10,488)	$ (6,384)
Depreciable assets, net	47,540	46,120
Assets not placed in service	384	1,247
Total oilfield services equipment and other property and equipment, net	47,924	47,367
Oilfield services equipment - net	64,210	87,549
Land [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	7,888	7,888
Building And Leasehold Improvements [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	36,843	33,625
Oilfield Service Equipment [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	110,703	105,938
Accumulated depreciation	(46,792)	(28,805)
Depreciable assets, net	63,911	77,133
Assets not placed in service	299	10,416
Oilfield services equipment - net	64,210	87,549
Vehicles [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	5,036	4,811
Software, Computers And Office Equipment [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	7,382	5,327
Capital Leases [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	$ 879	$ 853

Summary of Significant Accoun32

Summary of Significant Accounting Policies - Income Taxes (Details) - USD ($) $ in Thousands	9 Months Ended
	Oct. 31, 2015	Jan. 31, 2015
Summary Of Significant Accounting Policies [Abstract]
Period of pre-tax losses	3 years
Domestic net losses carried forward		$ 143,100
Unrecognized tax benefits	$ 0

Summary of Significant Accoun33

Summary of Significant Accounting Policies - Earnings per Share- (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Oct. 31, 2015	Oct. 31, 2014	Oct. 31, 2015	Oct. 31, 2014
Earnings Per Share, Diluted, Other Disclosures [Abstract]
Weighted Average Number Diluted Shares Outstanding Adjustment		17,712		17,652
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	10,819	6,740	10,819	6,776
Earnings Per Share Reconciliation [Abstract]
Net income	$ (286,999)	$ 25,398	$ (660,544)	$ 54,492
Effect of 5% Convertible Note conversion		919		2,852
Net income (loss) attributable to common shareholders after effect of debt conversion	$ (286,999)	$ 26,317	$ (660,544)	$ 57,344
Weighted Average Number of Shares Outstanding Reconciliation [Abstract]
Basic weighted average common shares outstanding	75,588	85,242	75,419	85,769
Effect of dilutive securities		17,712		17,652
Diluted weighted average common shares outstanding	75,588	102,954	75,419	103,421
Basic net income (loss) per share	$ (3.80)	$ 0.30	$ (8.76)	$ 0.64
Diluted net income (loss) per share	$ (3.80)	$ 0.26	$ (8.76)	$ 0.55
Anitdilutive securities excluded from calculation of diluted net income	10,819	6,740	10,819	6,776

Segment Reporting - Selected Fi

Segment Reporting - Selected Financial Information - (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Oct. 31, 2015	Oct. 31, 2014	Oct. 31, 2015	Oct. 31, 2014	Jan. 31, 2015
REVENUES
Oil, natural gas and natural gas liquids sales	$ 42,871	$ 80,139	$ 145,912	$ 221,479
Oilfield services for third parties	22,273	94,057	147,253	194,488
Total revenues	65,144	174,196	293,165	415,967
EXPENSES:
Lease operating and production taxes	14,187	15,954	46,701	42,403
Gathering, transportation and processing	6,537	4,380	19,526	11,915
Depreciation and amortization	28,396	32,471	98,446	80,465
Impairment of oil and natural gas properties	261,000		659,000
Accretion of asset retirement obligations	75	259	222	324
Oilfield services	21,700	70,805	133,883	142,069
Salaries and benefits	6,926	7,725	22,918	20,519
Share-based compensation	7,766	1,827	13,900	5,642
Other general and administrative	3,742	7,241	11,064	18,124
Total operating expenses	350,329	140,662	1,005,660	321,461
INCOME (LOSS) FROM OPERATIONS	(285,185)	33,534	(712,495)	94,506
Other income (expense)	(1,814)	11,164	(1,490)	(364)
INCOME (LOSS) BEFORE INCOME TAXES	(286,999)	44,698	(713,985)	94,142
Net oil and natural gas properties	529,349		529,349		$ 1,126,090
Oilfield services equipment, net	64,210		64,210		87,549
Other property and equipment, net	47,924		47,924		47,367
Total assets	850,458		850,458		1,654,870
Total liabilities	956,983		956,983		$ 1,109,852
Eliminations And Other [Member]
REVENUES
Oilfield services for third parties	351	(2,753)	(589)	(5,972)
Total revenues	(3,530)	(49,418)	(28,575)	(112,474)
EXPENSES:
Depreciation and amortization	(215)	(4,194)	(2,930)	(11,282)
Oilfield services	(2,964)	(31,905)	(17,720)	(73,219)
Total operating expenses	(3,179)	(36,099)	(20,650)	(84,501)
INCOME (LOSS) FROM OPERATIONS	(351)	(13,319)	(7,925)	(27,973)
Other income (expense)	(445)	(928)	(1,491)	(2,194)
INCOME (LOSS) BEFORE INCOME TAXES	(796)	(14,247)	(9,416)	(30,167)
Net oil and natural gas properties	(84,198)		(84,198)
Total assets	(84,532)		(84,532)
Total liabilities	(334)		(334)
Intersegment Revenues [Member] | Eliminations And Other [Member]
REVENUES
Total revenues	(3,881)	(46,665)	(27,986)	(106,502)
Exploration and Production [Member]
REVENUES
Oil, natural gas and natural gas liquids sales	42,871	80,139	145,912	221,479
Total revenues	42,871	80,139	145,912	221,479
EXPENSES:
Lease operating and production taxes	14,187	15,954	46,701	42,403
Gathering, transportation and processing	6,537	4,380	19,526	11,915
Depreciation and amortization	21,394	30,291	75,220	76,731
Impairment of oil and natural gas properties	261,000		659,000
Accretion of asset retirement obligations	75	259	222	324
Salaries and benefits	450	1,264	1,375	4,065
Share-based compensation	390	94	1,086	832
Other general and administrative	405	2,966	1,161	7,385
Total operating expenses	304,438	55,208	804,291	143,655
INCOME (LOSS) FROM OPERATIONS	(261,567)	24,931	(658,379)	77,824
Other income (expense)	2,991	12,126	279	1,292
INCOME (LOSS) BEFORE INCOME TAXES	(258,576)	37,057	(658,100)	79,116
Net oil and natural gas properties	613,547		613,547
Other property and equipment, net	9,072		9,072
Total assets	718,582		718,582
Total liabilities	720,821		720,821
Exploration and Production [Member] | Eliminations And Other [Member]
EXPENSES:
Depreciation and amortization	(400)	2,400	200	6,700
Oilfield Services [Member]
REVENUES
Oilfield services for third parties	21,922	96,810	147,842	200,460
Total revenues	25,803	143,475	175,828	306,962
EXPENSES:
Depreciation and amortization	6,797	6,119	25,004	14,399
Oilfield services	24,664	102,710	151,603	215,288
Salaries and benefits	4,138	3,836	12,907	9,496
Share-based compensation	117	146	252	363
Other general and administrative	1,198	3,207	4,029	7,895
Total operating expenses	36,914	116,018	193,795	247,441
INCOME (LOSS) FROM OPERATIONS	(11,111)	27,457	(17,967)	59,521
Other income (expense)	(2,062)	(628)	(3,782)	(1,802)
INCOME (LOSS) BEFORE INCOME TAXES	(13,173)	26,829	(21,749)	57,719
Oilfield services equipment, net	64,210		64,210
Other property and equipment, net	21,398		21,398
Total assets	93,333		93,333
Total liabilities	82,164		82,164
Oilfield Services [Member] | Intersegment Revenues [Member]
REVENUES
Total revenues	3,881	46,665	27,986	106,502
Corporate And Other [Member]
EXPENSES:
Depreciation and amortization	420	255	1,152	617
Salaries and benefits	2,338	2,625	8,636	6,958
Share-based compensation	7,259	1,587	12,562	4,447
Other general and administrative	2,139	1,068	5,874	2,844
Total operating expenses	12,156	5,535	28,224	14,866
INCOME (LOSS) FROM OPERATIONS	(12,156)	(5,535)	(28,224)	(14,866)
Other income (expense)	(2,298)	594	3,504	2,340
INCOME (LOSS) BEFORE INCOME TAXES	(14,454)	$ (4,941)	(24,720)	$ (12,526)
Other property and equipment, net	17,454		17,454
Total assets	123,075		123,075
Total liabilities	$ 154,332		$ 154,332

Segment Reporting - (Details)

Segment Reporting - (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Oct. 31, 2015USD ($)	Oct. 31, 2014USD ($)	Oct. 31, 2015USD ($)segment	Oct. 31, 2014USD ($)
Number of reportable segments | segment			2
Depreciation, Depletion and Amortization	$ 28,396	$ 32,471	$ 98,446	$ 80,465
Exploration and Production [Member]
Depreciation, Depletion and Amortization	21,394	30,291	75,220	76,731
Eliminations And Other [Member]
Depreciation, Depletion and Amortization	(215)	(4,194)	(2,930)	(11,282)
Eliminations And Other [Member] | Exploration and Production [Member]
Depreciation, Depletion and Amortization	$ (400)	$ 2,400	$ 200	$ 6,700

Long-Term Debt - Schedule of lo

Long-Term Debt - Schedule of long term debt- (Details) - USD ($) $ in Thousands	Oct. 31, 2015	Jan. 31, 2015	Jul. 18, 2014
Debt Instrument [Line Items]
Credit facility	$ 243,402	$ 224,159
TUSA 6.75% notes	415,889	429,500
5% Convertible Note	141,037	135,877
Other notes and mortgages payable	14,207	10,605
Total debt	814,535	800,141
Other notes and mortgages payable	(1,641)	(503)
Total long-term debt	$ 812,894	$ 799,638
TUSA 6.75% Notes [Member]
Debt instrument, interest rate
Debt instrument, interest rate	6.75%	6.75%	6.75%
Convertible Notes [Member]
Debt instrument, interest rate
Debt instrument, interest rate	5.00%	5.00%
TUSA [Member]
Debt Instrument [Line Items]
Credit facility	$ 189,272	$ 119,272
Rockpile [Member]
Debt Instrument [Line Items]
Credit facility	$ 54,130	$ 104,887

Long-term Debt - TUSA credit fa

Long-term Debt - TUSA credit facility - (Details) - USD ($) $ in Millions	9 Months Ended
	Oct. 31, 2015	Apr. 30, 2015	Nov. 25, 2014	Apr. 30, 2014
Line of Credit Facility [Line Items]
Credit agreement borrowing base	$ 350	$ 350		$ 435
TUSA [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum borrowing capacity			$ 1,000
Letter of credit sublimit			$ 15
Percentage of Oil and Gas Interests Used For Collateral	80.00%
Minimum [Member] | TUSA [Member] | Letter of Credit [Member]
Line of Credit Facility [Line Items]
Credit facility, commitment fee percentage	0.375%
Maximum [Member] | TUSA [Member] | Letter of Credit [Member]
Line of Credit Facility [Line Items]
Credit facility, commitment fee percentage	0.50%
Federal Funds Rate [Member] | TUSA [Member]
Line of Credit Facility [Line Items]
Credit facility, basis spread on interest rate	0.50%
Eurodollar Rate Plus 1% [Member] | TUSA [Member]
Line of Credit Facility [Line Items]
Credit facility, margin on dollar amount based on usage	1.00%
Eurodollar Rate Plus 1% [Member] | Minimum [Member] | TUSA [Member]
Line of Credit Facility [Line Items]
Credit facility, basis spread on interest rate	0.50%
Eurodollar Rate Plus 1% [Member] | Maximum [Member] | TUSA [Member]
Line of Credit Facility [Line Items]
Credit facility, basis spread on interest rate	1.50%
Eurodollar [Member] | Minimum [Member] | TUSA [Member]
Line of Credit Facility [Line Items]
Credit facility, basis spread on interest rate	1.50%
Eurodollar [Member] | Maximum [Member] | TUSA [Member]
Line of Credit Facility [Line Items]
Credit facility, basis spread on interest rate	2.50%

Long-term Debt - Rockpile credi

Long-term Debt - Rockpile credit facility - (Details) - Rockpile [Member] $ in Millions	9 Months Ended
	Oct. 31, 2015item	Nov. 13, 2014USD ($)	Mar. 25, 2014USD ($)
Federal Funds Rate [Member]
Debt Instrument [Line Items]
Credit facility, basis spread on interest rate	0.50%
Eurodollar Rate Plus 1% [Member]
Debt Instrument [Line Items]
Credit facility, margin on dollar amount based on usage	1.00%
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity | $		$ 150	$ 100
Debt covenant, maximum number of cure rights	5
Letter of Credit [Member]
Debt Instrument [Line Items]
Credit facility, fronting fee percentage	0.125%
Maximum [Member]
Debt Instrument [Line Items]
Commitment fee percentage	0.50%
Maximum [Member] | Eurodollar Rate Plus 1% [Member]
Debt Instrument [Line Items]
Credit facility, basis spread on interest rate	2.25%
Maximum [Member] | Eurodollar [Member]
Debt Instrument [Line Items]
Credit facility, basis spread on interest rate	3.25%
Maximum [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt covenant, number of days, cure right, obtain cash capital contribution	10 days
Debt covenant, number of days, compliance certificates due	120 days
Debt covenant, number of quarters, cure right may be exercised within range	2
Debt covenant, number of consecutive quarters to exercise cure right	4
Minimum [Member]
Debt Instrument [Line Items]
Commitment fee percentage	0.375%
Minimum [Member] | Eurodollar Rate Plus 1% [Member]
Debt Instrument [Line Items]
Credit facility, basis spread on interest rate	1.50%
Minimum [Member] | Eurodollar [Member]
Debt Instrument [Line Items]
Credit facility, basis spread on interest rate	2.50%
Minimum [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt covenant, number of days, compliance certificates due	45 days

Long-term Debt - TUSA 6.75% Not

Long-term Debt - TUSA 6.75% Note - (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Oct. 31, 2015	Oct. 31, 2015	Jan. 31, 2015	Jul. 18, 2014
Debt Instrument [Line Items]
Gain (loss) on extinguishment of debt	$ 4,175	$ 5,331
TUSA 6.75% Notes [Member]
Debt Instrument [Line Items]
Debt instrument, face amount				$ 450,000
Debt instrument, interest rate	6.75%	6.75%	6.75%	6.75%
Offering costs		$ 10,500
Face value of notes repurchased	$ 13,600	13,600	$ 20,500
Repurchased amount	$ 8,300	8,300	13,900
Gain (loss) on extinguishment of debt		$ 5,300	$ 6,600
TUSA 6.75% Notes [Member] | Redemption prior to October 15, 2017 [Member]
Debt Instrument [Line Items]
Redemption price, percentage		100.00%
Redemption price, percentage of principal amount redeemed		35.00%
TUSA 6.75% Notes [Member] | Redemption Due to Change in Control Events [Member]
Debt Instrument [Line Items]
Redemption price, percentage		101.00%
TUSA 6.75% Notes [Member] | Redemption after October 15, 2017 [Member]
Debt Instrument [Line Items]
Redemption price, percentage		105.00%
TUSA 6.75% Notes [Member] | Redemption after October 15, 2018 [Member]
Debt Instrument [Line Items]
Redemption price, percentage		103.00%
TUSA 6.75% Notes [Member] | Redemption after October 15, 2019 [Member]
Debt Instrument [Line Items]
Redemption price, percentage		102.00%
TUSA 6.75% Notes [Member] | Redemption after October 15, 2020 [Member]
Debt Instrument [Line Items]
Redemption price, percentage		100.00%

Long-Term Debt - Convertible no

Long-Term Debt - Convertible note- (Details) - USD ($)	9 Months Ended
	Oct. 31, 2015	Jan. 31, 2015
Debt Instrument [Line Items]
Accrued interest	$ 8,717,000	$ 2,250,000
Convertible Notes [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate	5.00%	5.00%
Debt instrument, face amount	$ 120,000,000
Convertible note, conversion price	$ 8
Accrued interest	$ 21,000,000
Redemption criteria, share price for 20 consecutive days	$ 11
Redemption criteria, number of consecutive trading days	20 days

Hedging And Commodity Derivat41

Hedging And Commodity Derivative Financial Instruments - (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		9 Months Ended
	Aug. 31, 2015	Oct. 31, 2015	Oct. 31, 2014	Oct. 31, 2015	Oct. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Realized commodity derivative gains (losses)	$ 9,300	$ 27,857	$ 688	$ 64,341	$ (3,084)
Unrealized commodity derivative gains (losses)		(21,044)	19,134	(46,453)	16,529
Commodity derivatives gains (losses)				$ 17,888	$ 13,445
Crude Oil Derivative Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized commodity derivative gains (losses)		27,857	688
Unrealized commodity derivative gains (losses)		(21,044)	19,134
Commodity derivatives gains (losses)		$ 6,813	$ 19,822

Hedging And Commodity Derivat42

Hedging And Commodity Derivative Financial Instruments - Notional - (Details) $ in Thousands	1 Months Ended	3 Months Ended		9 Months Ended
	Aug. 31, 2015USD ($)bbl / item$ / bbl	Oct. 31, 2015USD ($)bbl / item$ / bbl	Oct. 31, 2014USD ($)	Oct. 31, 2015USD ($)bbl / item$ / bbl	Oct. 31, 2014USD ($)
Derivative [Line Items]
Quantity, (bbls)	2,000
Notional Disclosures [Abstract]
Realized commodity derivative gains (losses) | $	$ 9,300	$ 27,857	$ 688	$ 64,341	$ (3,084)
Notional amount per day (in Bbl)	2,000
Average fixed price | $ / bbl	60.34
Fiscal 2016 Collar [Member]
Derivative [Line Items]
End date				November 1, 2015 to January 31, 2016
Contract type				Collar
Basis				NYMEX
Quantity, (bbls)		995		995
Put strike price | $ / bbl		80		80
Call strike price | $ / bbl		95.78		95.78
Notional Disclosures [Abstract]
Notional amount per day (in Bbl)		995		995
Fiscal 2016 Swap [Member]
Derivative [Line Items]
End date				November 1, 2015 to January 31, 2016
Contract type				Swap
Basis				NYMEX
Quantity, (bbls)		1,995		1,995
Weighted average price | $ / bbl		60.19		60.19
Notional Disclosures [Abstract]
Notional amount per day (in Bbl)		1,995		1,995
Fiscal 2017 Swap [Member]
Derivative [Line Items]
End date				February 1, 2016 to January 31, 2017
Contract type				Swap
Basis				NYMEX
Quantity, (bbls)		2,175		2,175
Weighted average price | $ / bbl		56.13		56.13
Notional Disclosures [Abstract]
Notional amount per day (in Bbl)		2,175		2,175
Fiscal 2018 Swap [Member]
Derivative [Line Items]
End date				February 1, 2017 to January 31, 2018
Contract type				Swap
Basis				NYMEX
Quantity, (bbls)		2,745		2,745
Weighted average price | $ / bbl		53.36		53.36
Notional Disclosures [Abstract]
Notional amount per day (in Bbl)		2,745		2,745

Hedging And Commodity Derivat43

Hedging And Commodity Derivative Financial Instruments - Fair values of commodity derivatives - (Details) - USD ($) $ in Thousands	Oct. 31, 2015	Jan. 31, 2015
Derivatives, Fair Value [Line Items]
Derivative Assets	$ 8,792	$ 54,775
Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liabilities	470
Crude Oil Derivative Contract [Member] | Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets	8,329	$ 54,775
Crude Oil Derivative Contract [Member] | Long-Term Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets	463
Crude Oil Derivative Contract [Member] | Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liabilities	$ 470

Oil And Natural Gas Propertie44

Oil And Natural Gas Properties - (Details) - Marathon Oil Company [Member] $ in Millions	1 Months Ended
	Jun. 30, 2014USD ($)a
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Number of acres purchased | a	41,100
Total consideration for acquisition	$ 90.4
Net downward adjustment included in the purchase price consideration	$ 9.6

Oil And Natural Gas Propertie45

Oil And Natural Gas Properties - Proforma Financial Information - (Details) $ / shares in Units, shares in Thousands, $ in Thousands	9 Months Ended
	Oct. 31, 2014USD ($)$ / sharesshares
Acquisitions [Abstract]
Operating revenue	$ 427,708
Net income (loss)	$ 57,110
Earnings (loss) per common share, basic | $ / shares	$ 0.67
Earnings (loss) per common share, diluted | $ / shares	$ 0.58
Weighted average common shares outstanding, basic | shares	85,769
Weighted average common shares outstanding, diluted | shares	103,421
Pro forma depreciation, amortization and accretion expense	$ 3,400

Equity Investment And Equity 46

Equity Investment And Equity Investment Derivatives - Equity Investment - (Details) - USD ($)	Feb. 02, 2015	Oct. 31, 2015	Jan. 31, 2015
Schedule of Equity Method Investments [Line Items]
Gain on Caliber capital transactions		$ 2,880,000
Caliber Midstream Partners, L.P. [Member]
Schedule of Equity Method Investments [Line Items]
Gain on Caliber capital transactions		2,880,000
Class A Units [Member] | Caliber Midstream Partners, L.P. [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investments, units held		7,000,000	$ 7,000,000
Class A Units [Member] | Caliber Midstream Partners, L.P. [Member] | FREIF Caliber Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Capital contributions	$ 34,000,000
Equity method investments, Class A Units received	2,720,000
Equity method investments, units held		$ 17,720,000
Equity method ownership percentage		71.70%
Equity method investments, warrants received		906,667
Class A Units [Member] | Caliber Midstream Partners, L.P. [Member] | Triangle Caliber Holdings LLC [Member]
Schedule of Equity Method Investments [Line Items]
Capital contributions	$ 0
Equity method investments, units held		$ 7,000,000
Equity method ownership percentage		28.30%
Equity method investments, warrants received		3,626,667
Series 1 To 4 Warrants [Member] | Caliber Midstream Partners, L.P. [Member] | Triangle Caliber Holdings LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investments, warrants received		2,357,334
Series 6 Warrants [Member] | Caliber Midstream Partners, L.P. [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investments, units held		$ 1,269,333
Strike price		$ 12.50
Series 6 Warrants [Member] | Caliber Midstream Partners, L.P. [Member] | Triangle Caliber Holdings LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investments, warrants received		1,269,333
Strike price		$ 12.50

Equity Investment And Equity 47

Equity Investment And Equity Investment Derivatives - Equity investment holdings summary - (Details) - Caliber Midstream Partners, L.P. [Member] - USD ($)	Oct. 31, 2015	Jan. 31, 2015
Class A Units [Member]
Schedule of Equity Method Investments [Line Items]
Warrants held	$ 7,000,000	$ 7,000,000
Series 1 Warrants [Member]
Schedule of Equity Method Investments [Line Items]
Strike price	$ 12.78
Warrants held	$ 6,615,467	5,600,000
Series 2 Warrants [Member]
Schedule of Equity Method Investments [Line Items]
Strike price	$ 22.09
Warrants held	$ 2,835,200	2,400,000
Series 3 Warrants [Member]
Schedule of Equity Method Investments [Line Items]
Strike price	$ 22.09
Warrants held	$ 3,544,000	3,000,000
Series 4 Warrants [Member]
Schedule of Equity Method Investments [Line Items]
Strike price	$ 28.09
Warrants held	$ 2,362,667	$ 2,000,000
Series 6 Warrants [Member]
Schedule of Equity Method Investments [Line Items]
Strike price	$ 12.50
Warrants held	$ 1,269,333

Equity Investment And Equity 48

Equity Investment And Equity Investment Derivatives - Equity investment activity summary (Details) $ in Thousands	9 Months Ended
	Oct. 31, 2015USD ($)
Schedule of Equity Method Investments [Line Items]
Equity investment, Beginning balance	$ 64,411
Gain on Caliber capital transactions	2,880
Equity investment, Ending balance	73,389
Caliber Midstream Partners, L.P. [Member]
Schedule of Equity Method Investments [Line Items]
Equity investment, Beginning balance	64,411
Equity investment share of net income before intra-company profit eliminationsr	2,700
Change in fair value of warrants	3,398
Gain on Caliber capital transactions	2,880
Equity investment, Ending balance	73,389
Fair value of warrants	$ 3,900

Capital Stock (Details)

Capital Stock (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Oct. 31, 2015	Oct. 31, 2015	Jan. 31, 2015
Common stock issued or reserved		106,800,000
Common stock, shares issued	75,679,808	75,679,808	75,174,442
Common stock, shares outstanding	75,679,808	75,679,808	75,174,442
Stock Repurchase authorized (Tranche 1)	$ 25	$ 25
Common stock repurchased (in shares)	0	0
Authorized shares remaining repurchase	5,591,645	5,591,645
2011 Omnibus Incentive Plan
Shares reserved for issuance	1,700,000	1,700,000
2014 Plan
Shares reserved for issuance	3,100,000	3,100,000
Shares reserved for future grants	2,700,000	2,700,000
CEO Stand-Alone Stock Option Agreement
Shares reserved for issuance	6,000,000	6,000,000
Convertible Notes Payable [Member]
Shares reserved for issuance	17,600,000	17,600,000

Share-Based Compensation (Detai

Share-Based Compensation (Details) - USD ($) $ in Thousands, shares in Millions	3 Months Ended		9 Months Ended
	Oct. 31, 2015	Oct. 31, 2014	Oct. 31, 2015	Oct. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense before capitalized amount	$ 8,339	$ 2,071	$ 15,182	$ 6,535
Less amounts capitalized to oil and natural gas properties	(573)	(244)	(1,282)	(893)
Stock-based compensation, net	$ 7,766	1,827	$ 13,900	5,642
Series B Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum shares reserved under Plan	6		6
2014 Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum shares reserved under Plan	6		6
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense before capitalized amount	$ 4,078	1,298	$ 8,741	4,572
Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense before capitalized amount	4,144	627	6,189	1,600
RockPile Stock Based Compensation Related to Series [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense before capitalized amount	$ 117	$ 146	$ 252	$ 363

Share-Based Compensation - Rest

Share-Based Compensation - Restricted stock units - (Details) - Restricted Stock Units (RSUs) [Member] $ / shares in Units, $ in Millions	9 Months Ended
	Oct. 31, 2015USD ($)$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation | $	$ 19.7
Unrecognized compensation, recognition period	3 years 2 months 12 days
Number of shares per vesting unit	1
Outstanding, Unvested Beginning Balance	2,914,045
Outstanding, Weighted-Average Award Date Fair Value, Beginning Balance | $ / shares	$ 7.92
Units granted, number of units	1,983,843
Units granted, Weighted Average Award Date Fair Value | $ / shares	$ 4.74
Units forfeited, Number of Shares	(78,788)
Units forfeited, Weighted Average Award Date Fair Value | $ / shares	$ 8.07
Units that vested, Number of Shares	(700,506)
Units that vested, Weighted Average Award Date Fair Value | $ / shares	$ 8.27
Outstanding, Unvested Ending Balance	4,118,594
Outstanding, Weighted-Average Grant Date Fair Value, Ending Balance | $ / shares	$ 6.33
Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based awards vesting period	1 year
Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based awards vesting period	5 years

Share-Based Compensation - Stoc

Share-Based Compensation - Stock options - (Details) $ / shares in Units, $ in Millions	9 Months Ended
	Oct. 31, 2015USD ($)$ / sharesshares
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Options forfeited	0
Employee Stock Option [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Options granted	0
Options exercised	0
Outstanding options	6,700,000
Number of shares exercisable	1,433,310
Weighted average exercise price per share | $ / shares	$ 11.54
Weighted average remaining contractual life (years)	7 years 7 months 2 days
Weighted average exercise price per share (exercisable) | $ / shares	$ 11.70
Weighted average remaining contractual life (years) (exercisable)	7 years 6 months 18 days
Unrecognized compensation cost related to awards | $	$ 12.4
Unrecognized compensation, recognition period	2 years 7 months 6 days
Employee Stock Option [Member] | $7.50 [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price per share | $ / shares	$ 7.50
Remaining contractual life	7 years 8 months 5 days
Outstanding options	750,000
Number of shares exercisable	150,000
Employee Stock Option [Member] | $8.50 [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price per share | $ / shares	$ 8.50
Remaining contractual life	7 years 8 months 5 days
Outstanding options	750,000
Number of shares exercisable	150,000
Employee Stock Option [Member] | $10.00 [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price per share | $ / shares	$ 10
Remaining contractual life	7 years 8 months 5 days
Outstanding options	1,500,000
Number of shares exercisable	300,000
Employee Stock Option [Member] | $12.00 [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price per share | $ / shares	$ 12
Remaining contractual life	7 years 8 months 5 days
Outstanding options	1,500,000
Number of shares exercisable	300,000
Employee Stock Option [Member] | $15.00 [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price per share | $ / shares	$ 15
Remaining contractual life	7 years 8 months 5 days
Outstanding options	1,500,000
Number of shares exercisable	300,000
Employee Stock Option [Member] | $12.00 [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price per share | $ / shares	$ 12
Remaining contractual life	5 years 10 months 10 days
Outstanding options	233,333
Number of shares exercisable	77,770
Employee Stock Option [Member] | $14.00 [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price per share | $ / shares	$ 14
Remaining contractual life	5 years 10 months 10 days
Outstanding options	233,333
Number of shares exercisable	77,770
Employee Stock Option [Member] | $16.00 [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Exercise price per share | $ / shares	$ 16
Remaining contractual life	8 years 10 months 13 days
Outstanding options	233,334
Number of shares exercisable	77,770

Share-Based Compensation - Rock

Share-Based Compensation - Rockpile share based compensation - (Details) $ in Millions	9 Months Ended
	Oct. 31, 2015USD ($)shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding, Number of Units, Beginning Balance	5,302,000
Units granted	655,000
Units forfeited	(170,000)
Outstanding, Number of Units, Ending Balance	5,787,000
Grants, Number of Vested Units	3,449,600
Grants, Number of Unvested Units	2,337,400
Series B Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum shares reserved under Plan	6,000,000
Unrecognized compensation | $	$ 2.5
Series B-1 Unit [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding, Number of Units, Beginning Balance	2,920,000
Outstanding, Number of Units, Ending Balance	2,920,000
Grants, Number of Vested Units	2,920,000
Series B-2 Unit [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding, Number of Units, Beginning Balance	60,000
Outstanding, Number of Units, Ending Balance	60,000
Grants, Number of Vested Units	60,000
Series B-3 Unit [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding, Number of Units, Beginning Balance	910,000
Units forfeited	(96,000)
Outstanding, Number of Units, Ending Balance	814,000
Grants, Number of Vested Units	352,000
Grants, Number of Unvested Units	462,000
Series B-4 Unit [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding, Number of Units, Beginning Balance	1,412,000
Units forfeited	(74,000)
Outstanding, Number of Units, Ending Balance	1,338,000
Grants, Number of Vested Units	117,600
Grants, Number of Unvested Units	1,220,400
Series B-5 Unit [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units granted	397,500
Outstanding, Number of Units, Ending Balance	397,500
Grants, Number of Unvested Units	397,500
Series B-6 Unit [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Units granted	257,500
Outstanding, Number of Units, Ending Balance	257,500
Grants, Number of Unvested Units	257,500
Rockpile Series A Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Preferred return on investment	8.00%
Minimum [Member] | Series B Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based awards vesting period	1 month
Maximum [Member] | Series B Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based awards vesting period	44 months

Fair Value Measurements - Asset

Fair Value Measurements - Assets and liabilities table - (Details) - Fair Value, Measurements, Recurring [Member] - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Oct. 31, 2015	Jan. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative Liabilities	$ (470)
Rockpile earn-out liability	(1,257)	$ (1,825)
Equity Investment Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	3,900	504
Crude Oil Derivative Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	8,792	54,775
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative Liabilities	(470)
Rockpile earn-out liability	(1,257)	(1,825)
Fair Value, Inputs, Level 2 [Member] | Crude Oil Derivative Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	8,792	54,775
Fair Value, Inputs, Level 3 [Member] | Equity Investment Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$ 3,900	$ 504

Fair Value Measurements - Debt

Fair Value Measurements - Debt instruments carrying value - (Details) - USD ($) $ in Thousands	Oct. 31, 2015	Jan. 31, 2015	Jul. 18, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
5% convertible note, carrying value	$ 141,037	$ 135,877
Convertible note	123,940	137,790
Long-term portion of credit facilities	243,402	224,159
Revolving credit facilities, carrying value	243,402	224,159
Revolving credit facilities, fair value	243,402	224,159
TUSA 6.75% notes, carrying value	415,889	429,500
TUSA 6.75% notes, fair value	185,537	303,871
Other notes and mortgages payable, carrying value	14,207	10,605
Other notes and mortgages payable, fair value	$ 14,207	$ 10,605
Convertible Notes [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt instrument, interest rate	5.00%	5.00%
TUSA 6.75% Notes [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt instrument, interest rate	6.75%	6.75%	6.75%

Related Party Transactions (Det

Related Party Transactions (Details) $ in Thousands	9 Months Ended
	Oct. 31, 2015USD ($)item	Oct. 31, 2014USD ($)
Related Party Transaction [Line Items]
Term of gathering services agreements	5 years
Number of salt water disposal wells sold | item	1
Proceeds from sale of salt water disposal wells	$ 6,000	$ 1,500
Caliber North Dakota LLC [Member]
Related Party Transaction [Line Items]
Term of midstream agreements with Caliber	15 years
Minimum commitment over term of agreements	$ 405,000
Remaining commitment	$ 315,400

Supplemental Disclosures Of C57

Supplemental Disclosures Of Cash Flow Information (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Oct. 31, 2015	Oct. 31, 2014	Oct. 31, 2015	Oct. 31, 2014
Supplemental Disclosures of Cash Flow Information [Abstract]
Interest expense			$ 17,222	$ 5,672
Income taxes				550
Increase (decrease) in accounts payable and accrued liabilities			(47,554)	103,415
Capitalized stock-based compensation	$ 573	$ 244	1,282	893
Change in asset retirement obligations			$ 425	$ 1,519