Triangle Petroleum (TPLMQ) 10-Q 8 Sep 15 2016 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	6 Months Ended
	Jul. 31, 2015	Sep. 03, 2015
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jul. 31, 2015
Document Fiscal Period Focus	Q2
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		75,504,924

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Jul. 31, 2015	Jan. 31, 2015
CURRENT ASSETS
Cash and equivalents	$ 45,870	$ 67,871
Accounts receivable	116,159	171,911
Commodity derivatives	26,677	54,775
Other current assets	8,947	14,952
Total current assets	197,653	309,509
Oil and natural gas properties, at cost, full cost method of accounting:
Proved properties	1,302,145	1,159,584
Unproved properties and properties under development, not being amortized	112,918	142,896
Total oil and natural gas properties	1,415,063	1,302,480
Accumulated amortization	(627,296)	(176,390)
Net oil and natural gas properties	787,767	1,126,090
Oilfield services equipment - net	79,997	87,549
Other property and equipment, net	48,825	47,367
Net property, plant and equipment	916,589	1,261,006
Deferred loan costs	13,601	14,038
Equity investment	73,709	64,411
Commodity derivatives	2,689
Other	5,716	5,906
Total other assets	95,715	84,355
Total assets	1,209,957	1,654,870
CURRENT LIABILITIES
Accounts payable and accrued capital expenditures	130,698	176,182
Other accrued liabilities	57,667	73,440
Current portion of long-term debt	677	503
Interest payable	1,725	2,250
Deferred income taxes		19,467
Total current liabilities	190,767	271,842
LONG-TERM LIABILITIES
5% convertible note	139,295	135,877
Borrowings on credit facilities	259,192	224,159
TUSA 6.75% notes	425,889	429,500
Other notes and mortgages payable	12,687	10,102
Deferred income taxes		33,974
Other	4,435	4,398
Total liabilities	$ 1,032,265	$ 1,109,852
COMMITMENT AND CONTINGENCIES
STOCKHOLDERS' EQUITY
Common stock, $0.00001 par value, 140,000,000 shares authorized; 75,174,442 and 75,327,056 shares issued and outstanding at January 31, 2015 and April 30, 2015, respectively	$ 1	$ 1
Additional paid-in capital	551,236	545,017
Retained earnings (accumulated deficit)	(373,545)
Total stockholders' equity	177,692	545,018
Total liabilities and stockholders' equity	$ 1,209,957	$ 1,654,870

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Jul. 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	75,488,871	75,174,442
Common stock, shares outstanding	75,488,871	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		6 Months Ended
	Jul. 31, 2015	Jul. 31, 2014	Jul. 31, 2015	Jul. 31, 2014
REVENUES
Oil and natural gas liquids sales	$ 55,263	$ 80,506	$ 103,041	$ 141,340
Oilfield services	54,470	61,483	124,980	100,431
Total revenues	109,733	141,989	228,021	241,771
EXPENSES:
Lease operating expenses	11,369	6,698	22,278	11,424
Gathering, transportation and processing	6,641	3,733	12,989	7,535
Production taxes	5,449	8,677	10,236	15,025
Depreciation and amortization	32,244	26,707	70,050	47,994
Impairment of oil and natural gas properties	206,000		398,000
Accretion of asset retirement obligations	90	40	147	65
Oilfield services	46,719	43,554	112,183	71,264
General and administrative, net of amounts capitalized	14,589	14,091	29,448	27,492
Total operating expenses	323,101	103,500	655,331	180,799
INCOME FROM OPERATIONS	(213,368)	38,489	(427,310)	60,972
OTHER INCOME (EXPENSE):
Interest expense, net	(9,866)	(4,218)	(18,972)	(6,890)
Amortization of deferred loan costs	(731)	(1,167)	(1,347)	(1,359)
Gain on extinguishment of debt	1,156		1,156
Realized commodity derivative gains (losses)	17,016	(2,954)	36,484	(3,772)
Unrealized commodity derivative gains (losses)	8,033	2,033	(25,409)	(2,605)
Equity investment income (loss)	1,210	190	1,398	64
Gain on equity investment derivatives	4,516	(7,534)	4,516	2,920
Gain on Caliber capital transactions			2,880
Other income	(1,312)	52	(382)	114
Total other income (expense)	20,022	(13,598)	324	(11,528)
INCOME (LOSS) BEFORE INCOME TAXES	(193,346)	24,891	(426,986)	49,444
Income tax provision		10,339	(53,441)	20,350
NET INCOME (LOSS)	(193,346)	14,552	(373,545)	29,094
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCKHOLDERS	$ (193,346)	$ 14,552	$ (373,545)	$ 29,094
Earnings (loss) per common share outstanding:
Basic	$ (2.56)	$ 0.17	$ (4.96)	$ 0.34
Diluted	$ (2.56)	$ 0.15	$ (4.96)	$ 0.30
Weighted average common shares outstanding:
Basic	75,410	86,172	75,334	86,064
Diluted	75,410	103,774	75,334	103,511

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jul. 31, 2015	Jul. 31, 2014	Jul. 31, 2015	Jul. 31, 2014	Jan. 31, 2015
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$ (193,346)	$ 14,552	$ (373,545)	$ 29,094
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	32,244	26,707	70,050	47,994
Impairment of oil and natural gas properties	206,000		398,000
Share-based compensation			6,134	3,815
Interest expense not paid in cash			3,418	3,252
Amortization of deferred loan costs	731	1,167	1,347	1,359
Gain on extinguishment of debt	(1,156)		(1,156)
Accretion of asset retirement obligations	90	40	147	65
Unrealized commodity derivative (gains) losses	(8,033)	(2,033)	25,409	2,605
Equity investment income (loss)	(1,210)	(190)	(1,398)	(64)
Gain on equity investment derivatives			(4,516)	(2,920)
Gain on Caliber capital transactions			(2,880)
Deferred income taxes			(53,441)	19,800
Changes in related current assets and current liabilities:
Accounts receivable			55,752	(44,363)
Other current assets			6,005	(581)
Accounts payable and accrued liabilities			(48,345)	2,994
Asset retirement expenditures			(377)	(136)
Other			(559)	(1,068)
Cash provided by operating activities			80,045	61,846
CASH FLOWS FROM INVESTING ACTIVITIES:
Oil and natural gas expenditures			(128,734)	(149,479)
Acquisitions of oil and natural gas properties			(243)	(131,368)
Purchase of oil field services equipment			(8,657)	(24,579)
Purchase of other property and equipment			(4,208)	(3,080)
Sale of oil and natural gas properties			6,000
Other			15	58
Cash used in investing activities			(135,827)	(308,448)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from credit facilities			110,810	245,116
Repayments of credit facilities			(75,777)	(410,015)
Proceeds from notes payable			3,035	450,000
Repayments of other notes and mortgages payable			(298)	(199)
Early extinguishment of repurchased debt			(2,455)
Debt issuance costs			(910)	(10,331)
Payments to settle tax on vested restricted stock units			(624)	(2,192)
Cash provided by financing activities			33,781	272,379
NET INCREASE (DECREASE) IN CASH AND EQUIVALENTS			(22,001)	25,777
CASH AND EQUIVALENTS, BEGINNING OF PERIOD			67,871	81,750	$ 81,750
CASH AND EQUIVALENTS, END OF PERIOD	$ 45,870	$ 107,527	$ 45,870	$ 107,527	$ 67,871

Consolidated Statement of Stock

Consolidated Statement of Stockholders' Equity - 6 months ended Jul. 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)		(624)		$ (624)
Vesting of restricted stock units (net of shares surrendered for taxes), shares	314,429
Share-based compensation		6,843		6,843
Net income (loss) for the year			$ (373,545)	(373,545)
Balance at Jul. 31, 2015	$ 1	$ 551,236	$ (373,545)	$ 177,692
Balance, shares at Jul. 31, 2015	75,488,871			75,488,871

Description Of Business

Description Of Business	6 Months Ended
	Jul. 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	6 Months Ended
	Jul. 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 Oil (per Bbl) $ $ $ Natural gas (per MMbtu) $ $ $ Natural gas liquids (per Bbl) $ $ $ We recognized impairments to our proved oil and natural gas properties of $206.0 million and $398.0 million for the three and six months ended July 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 six months ended July 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 July 31, 2015 Land $ $ Building and leasehold improvements Oilfield service equipment Vehicles Software, computers and office equipment Capital leases Total depreciable assets Accumulated depreciation Depreciable assets, net Assets not placed in service Total oilfield service equipment and other property & 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 $398.0 million for the six months ended July 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 $136.9 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 and July 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 alternative minimum tax expense, a release of a portion of the valuation allowance for net operating loss carryback claims or for state income taxes. As of July 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 six 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 net income 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 Six Months Ended July 31, July 31, 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 Six Months Ended July 31, July 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 statement of operations for the three and six months ended July 31, 2014 have been reclassified to conform to the financial statement presentation for the periods ended July 31, 2015. The unaudited condensed consolidated statement 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	6 Months Ended
	Jul. 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 complementary 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 July 31, 2015 and 2014. For the Three Months Ended July 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 — — — Cost of oilfield services — General and administrative, net of amounts capitalized: Salaries and benefits — Stock-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense), net Income (loss) before income taxes $ $ $ $ $ For the Three Months Ended July 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 — — — Cost of oilfield services — — General and administrative, net of amounts capitalized: Salaries and benefits — Stock-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense), net Net income (loss) before income taxes $ $ $ $ $ The following tables present selected financial information for our operating segments for the six months ended July 31, 2015 and 2014. For the Six Months Ended July 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 — — — Cost of oilfield services — — General and administrative, net of amounts capitalized: Salaries and benefits — Stock-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense), net Income (loss) before income taxes $ $ $ $ $ As of July 31, 2015: Net oil and natural gas properties $ $ — $ — $ $ Oilfield services equipment - net $ — $ $ — $ — $ Other property and equipment - net $ $ $ $ — $ Total assets $ $ $ $ $ Total liabilities $ $ $ $ $ For the Six Months Ended July 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 — — — Cost of oilfield services — — General and administrative, net of amounts capitalized: Salaries and benefits — Stock-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense), net 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 July 31, 2015 and 2014, $0.1 and $2.9 million, respectively, of the depreciation and amortization elimination relates to the Exploration and Production segment and the balance relates to th e Oilfield Services segment. F or the six months ended July 31, 2015 and 2014 , $0.6 and $4.3 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	6 Months Ended
	Jul. 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 July 31, 2015: (in thousands) January 31, 2015 July 31, 2015 5% convertible note $ $ TUSA credit facility due October 2018 RockPile credit facility due March 2019 TUSA 6.75% notes due July 2022 Other notes and mortgages payable Total debt Less current portion of debt: Other notes and mortgages payable Total long-term debt $ $ Convertible Note. On July 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 into the Company’s common stock at a conversion rate of one share per $8.00 of note principal. 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 July 31, 2015, $19.3 million of accrued interest has been added to the principal balance of the Convertible Note. 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. 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 July 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 pay s a commitment fee that ranges between 0.375% and 0.50% per annum on the unused availability under the RockPile credit facility. RockPile also pay s 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 July 31, 2015, RockPile was in compliance with all financial covenants under the RockPile credit facility. 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, beginning on January 15, 2015. 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 on 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, 2 019 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 three months ended July 31, 2015, TUSA repurchased additional TUSA 6.75% Notes with a face value of $3.6 million for $2.5 million, immediately retired the repurchased notes, and recognized a gain on extinguishment of debt of $1.1 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 July 31, 2015, TUSA was in compliance with all covenants under the TUSA 6.75% Notes.

Hedging And Commodity Derivativ

Hedging And Commodity Derivative Financial Instruments	6 Months Ended
	Jul. 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 four 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. Net gains and losses on derivative activities are recorded in the commodity derivatives gains (losses) caption on the consolidated statements of operations. 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 Six Months Ended July 31, July 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 July 31, 2015 are summarized below: Contract Quantity Weighted Average Weighted Average Weighted Average Type Basis (1) (Bbl/d) Put Strike Call Strike Price August 1, 2015 to January 31, 2016 Collar NYMEX $ $ August 1, 2015 to January 31, 2016 Swap NYMEX $ February 1, 2016 to January 31, 2017 Swap NYMEX $ (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 July 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 (in thousands). 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 July 31, 2015 Current Assets: Crude oil derivative contracts $ $ Other Long-Term Assets: Crude oil derivative contracts — Total derivative asset $ $

Oil And Natural Gas Properties

Oil And Natural Gas Properties	6 Months Ended
	Jul. 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 Three Months Ended For the Six Months Ended (in thousands, except per share data) July 31, 2014 July 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 $1.3 million and $3.3 million, respectively, for the three and six month periods ended July 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	6 Months Ended
	Jul. 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 six 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 July 31, 2015 and the strike prices for exercising warrants as of July 31, 2015: Expiration Strike Price at As of As of Date July 31, 2015 January 31, 2015 July 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 six months ended July 31, 2015: For the Six Months Ended (in thousands) July 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 July 31, 2015 $ Fair value of warrants at July 31, 2015 $ Equity Investment Derivatives . At January 31, 2015 and July 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 techni ques for which the inputs are generally less observable than from objective sources .

Capital Stock

Capital Stock	6 Months Ended
	Jul. 31, 2015
Capital Stock [Abstract]
Capital Stock	8. CAPITAL STOCK The Company had 106.7 million shares of common stock issued or reserved for issuance at July 31, 2015. At July 31, 2015, the Company had 75.5 million shares of common stock issued and outstanding . The Company also had 1.8 million shares of common stock reserved for issuance pursuant to outstanding awards under its 2011 Omnibus Incentive Plan and 3.1 million shares of common stock reserved for issuance pursuant to outstanding awards under its 2014 Equity Incentive Plan (the “2014 Plan”). The Company also had 2.9 million shares of common stock reserved that remained available for issuance under the 2014 Plan, as well as 6.0 million shares of common stock reserved for issuance under the CEO Stand-Alone Stock Option Agreement. Lastly, the Company had 17.4 million shares of common stock reserved for issuance pursuant to the Convertible Note at July 31, 2015. 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 six months ended July 31, 2015. As of July 31, 2015, the number of shares of common stock remaining available for repurchase under the Board approved program was 5,374,890 shares.

Share-Based Compensation

Share-Based Compensation	6 Months Ended
	Jul. 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 July 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 six months ended July 31, 2014 and 2015, the Company recorded share-based compensation related to restricted stock units, stock options and RockPile Series B Units as follows : For the Three Months Ended For the Six Months Ended July 31, July 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 six months ended July 31, 2015, the Company granted 1,773,343 restricted stock units as compensation to employees, officers, and directors which generally vest over one to five years. As of July 31, 2015, there was approximately $23.2 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 3.3 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 six months ended July 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 - July 31, 2015 $ Stock Options. There were no grants , exercises or forfeitures of stock options during the six months ended July 31, 2015. The following table summarizes the stock options outstanding at July 31, 2015 : Remaining Exercise Price Contractual Life Number of Shares per Share (years) Outstanding Exercisable $ 7.93 $ 7.93 $ 7.93 $ 7.93 $ 7.93 $ 6.12 — $ 6.12 — $ 9.12 — Weighted average exercise price per share $ $ Weighted average remaining contractual life As of July 31, 2015, there was approximately $16.5 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 2.8 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 six months ended July 31, 2015: Series Series Series Series B-1 units B-2 units B-3 units B-4 units Total Units outstanding - January 31, 2015 Units redeemed — — — — — Units granted — — — — — Units forfeited — — Units outstanding - July 31, 2015 Vested Unvested — Series B Units currently have a 1 to 46 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 July 31, 2015, there was approximately $2.3 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	6 Months Ended
	Jul. 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 July 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 July 31, 2015 (in thousands) Level 1 Level 2 Level 3 Total Assets: Commodity derivative assets $ — $ $ — $ Equity investment derivative assets $ — $ — $ $ 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 July 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 Cl ass 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 wa rrant is adjusted accordingly. At July 31, 2015, t he fair value of the underlying Class A Units was estimated employing a n 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 Convertible Note’s estimated fair value is based on discounted cash flows analysis and option pricing. The carrying amount of the Company’s revolving credit facilities approximated fair value because the interest rate of the facilities is variable. The 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. 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 July 31, 2015 Carrying Estimated Carrying Estimated (in thousands) Value Fair Value Value Fair Value 5% convertible note $ $ $ $ Revolving credit facilities TUSA 6.75% notes Other notes and mortgages payable

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jul. 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 $336.3 million was outstanding at July 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 anticipated to be in the first half of fiscal year 2016. 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 six months ended July 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	6 Months Ended
	Jul. 31, 2015
Supplemental Disclosures of Cash Flow Information [Abstract]
Supplemental Disclosures of Cash Flow Information	12. SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION For the Six Months Ended July 31, (in thousands) 2014 2015 Cash paid during the period for: Interest expense $ $ Income taxes $ $ — Non-cash investing activities: Additions to oil and natural gas properties through: Increase (decrease) in accounts payable and accrued liabilities $ $ Capitalized stock based compensation $ $ Change in asset retirement obligations $ $ Non-cash financing activities: Notes payable issued for redemption of RockPile Series B Units $ $ —

Summary Of Significant Accoun19

Summary Of Significant Accounting Policies (Policies)	6 Months Ended
	Jul. 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 Oil (per Bbl) $ $ $ Natural gas (per MMbtu) $ $ $ Natural gas liquids (per Bbl) $ $ $ We recognized impairments to our proved oil and natural gas properties of $206.0 million and $398.0 million for the three and six months ended July 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 six months ended July 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 July 31, 2015 Land $ $ Building and leasehold improvements Oilfield service equipment Vehicles Software, computers and office equipment Capital leases Total depreciable assets Accumulated depreciation Depreciable assets, net Assets not placed in service Total oilfield service equipment and other property & 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 $398.0 million for the six months ended July 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 $136.9 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 and July 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 alternative minimum tax expense, a release of a portion of the valuation allowance for net operating loss carryback claims or for state income taxes. As of July 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 six 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 net income 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 Six Months Ended July 31, July 31, 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 Six Months Ended July 31, July 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 statement of operations for the three and six months ended July 31, 2014 have been reclassified to conform to the financial statement presentation for the periods ended July 31, 2015. The unaudited condensed consolidated statement 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)	6 Months Ended
	Jul. 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 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 July 31, 2015 Land $ $ Building and leasehold improvements Oilfield service equipment Vehicles Software, computers and office equipment Capital leases Total depreciable assets Accumulated depreciation Depreciable assets, net Assets not placed in service Total oilfield service equipment and other property & 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 Six Months Ended July 31, July 31, 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 Six Months Ended July 31, July 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)	6 Months Ended
	Jul. 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 July 31, 2015 and 2014. For the Three Months Ended July 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 — — — Cost of oilfield services — General and administrative, net of amounts capitalized: Salaries and benefits — Stock-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense), net Income (loss) before income taxes $ $ $ $ $ For the Three Months Ended July 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 — — — Cost of oilfield services — — General and administrative, net of amounts capitalized: Salaries and benefits — Stock-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense), net Net income (loss) before income taxes $ $ $ $ $ The following tables present selected financial information for our operating segments for the six months ended July 31, 2015 and 2014. For the Six Months Ended July 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 — — — Cost of oilfield services — — General and administrative, net of amounts capitalized: Salaries and benefits — Stock-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense), net Income (loss) before income taxes $ $ $ $ $ As of July 31, 2015: Net oil and natural gas properties $ $ — $ — $ $ Oilfield services equipment - net $ — $ $ — $ — $ Other property and equipment - net $ $ $ $ — $ Total assets $ $ $ $ $ Total liabilities $ $ $ $ $ For the Six Months Ended July 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 — — — Cost of oilfield services — — General and administrative, net of amounts capitalized: Salaries and benefits — Stock-based compensation — Other general and administrative — Total operating expenses Income (loss) from operations Other income (expense), net Income (loss) before income taxes $ $ $ $ $

Long-Term Debt (Tables)

Long-Term Debt (Tables)	6 Months Ended
	Jul. 31, 2015
Long-Term Debt [Abstract]
Schedule Of Debt	(in thousands) January 31, 2015 July 31, 2015 5% convertible note $ $ TUSA credit facility due October 2018 RockPile credit facility due March 2019 TUSA 6.75% notes due July 2022 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)	6 Months Ended
	Jul. 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 Six Months Ended July 31, July 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 July 31, 2015 are summarized below: Contract Quantity Weighted Average Weighted Average Weighted Average Type Basis (1) (Bbl/d) Put Strike Call Strike Price August 1, 2015 to January 31, 2016 Collar NYMEX $ $ August 1, 2015 to January 31, 2016 Swap NYMEX $ February 1, 2016 to January 31, 2017 Swap NYMEX $ (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.
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 July 31, 2015 Current Assets: Crude oil derivative contracts $ $ Other Long-Term Assets: Crude oil derivative contracts — Total derivative asset $ $

Oil And Natural Gas Properties

Oil And Natural Gas Properties (Tables)	6 Months Ended
	Jul. 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 Three Months Ended For the Six Months Ended (in thousands, except per share data) July 31, 2014 July 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)	6 Months Ended
	Jul. 31, 2015
Equity Investment [Abstract]
Schedule Of Equity Investment In Caliber	Expiration Strike Price at As of As of Date July 31, 2015 January 31, 2015 July 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 Six Months Ended (in thousands) July 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 July 31, 2015 $ Fair value of warrants at July 31, 2015 $

Share-Based Compensation (Table

Share-Based Compensation (Tables)	6 Months Ended
	Jul. 31, 2015
Share-Based Compensation [Abstract]
Non-Cash Stock-Based Compensation Cost	For the Three Months Ended For the Six Months Ended July 31, July 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 six months ended July 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 - July 31, 2015 $
Stock Options Outstanding By Exercise Price	The following table summarizes the stock options outstanding at July 31, 2015 : Remaining Exercise Price Contractual Life Number of Shares per Share (years) Outstanding Exercisable $ 7.93 $ 7.93 $ 7.93 $ 7.93 $ 7.93 $ 6.12 — $ 6.12 — $ 9.12 — Weighted average exercise price per share $ $ Weighted average remaining contractual life
Summary Of Series B Unit Activity	Series Series Series Series B-1 units B-2 units B-3 units B-4 units Total Units outstanding - January 31, 2015 Units redeemed — — — — — Units granted — — — — — Units forfeited — — Units outstanding - July 31, 2015 Vested Unvested —

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jul. 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 July 31, 2015 (in thousands) Level 1 Level 2 Level 3 Total Assets: Commodity derivative assets $ — $ $ — $ Equity investment derivative assets $ — $ — $ $ 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 July 31, 2015 Carrying Estimated Carrying Estimated (in thousands) Value Fair Value Value Fair Value 5% convertible note $ $ $ $ Revolving credit facilities TUSA 6.75% notes Other notes and mortgages payable

Supplemental Disclosures of C28

Supplemental Disclosures of Cash Flow Information (Tables)	6 Months Ended
	Jul. 31, 2015
Supplemental Disclosures of Cash Flow Information [Abstract]
Schedule of Supplemetal Cash Flow Disclosures	For the Six Months Ended July 31, (in thousands) 2014 2015 Cash paid during the period for: Interest expense $ $ Income taxes $ $ — Non-cash investing activities: Additions to oil and natural gas properties through: Increase (decrease) in accounts payable and accrued liabilities $ $ Capitalized stock based compensation $ $ Change in asset retirement obligations $ $ Non-cash financing activities: Notes payable issued for redemption of RockPile Series B Units $ $ —

Description of Business - (Deta

Description of Business - (Details)	6 Months Ended
	Jul. 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	12 Months Ended
	Jul. 31, 2015USD ($)	Apr. 30, 2015$ / MMBTU$ / bbl	Jul. 31, 2015USD ($)$ / MMBTU$ / bbl	Jan. 31, 2015$ / MMBTU$ / bbl
Impairment charges
Impairment of oil and natural gas properties | $	$ 206,000		$ 398,000
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	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	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	50.07

Summary of Significant Accoun31

Summary of Significant Accounting Policies - Oilfield Services Equipment Schedule (Details) - USD ($) $ in Thousands	Jul. 31, 2015	Jan. 31, 2015
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	$ 179,435	$ 168,858
Accumulated depreciation	(54,121)	(35,189)
Depreciable assets, net	125,314	133,669
Assets not placed in service	3,508	1,247
Total oilfield service equipment and other property and equipment, net	128,822	134,916
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	35,506	33,625
Oilfield Service Equipment [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	122,946	116,354
Vehicles [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	5,761	4,811
Software, Computers And Office Equipment [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	6,481	5,327
Capital Leases [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	$ 853	$ 853

Summary of Significant Accoun32

Summary of Significant Accounting Policies - Income Taxes (Details) - USD ($) $ in Thousands	6 Months Ended
	Jul. 31, 2015	Jan. 31, 2015
Summary Of Significant Accounting Policies [Abstract]
Period of pre-tax losses	3 years
Domestic net losses carried forward		$ 136,900
Unrecognized tax benefits	$ 0

Summary of Significant Accoun33

Summary of Significant Accounting Policies - Earnings per Share- (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jul. 31, 2015	Jul. 31, 2014	Jul. 31, 2015	Jul. 31, 2014
Earnings Per Share, Diluted, Other Disclosures [Abstract]
Weighted Average Number Diluted Shares Outstanding Adjustment		17,602,373		17,447,130
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	10,888,828	4,500,000	10,888,828	4,500,000
Earnings Per Share Reconciliation [Abstract]
Net income	$ (193,346)	$ 14,552	$ (373,545)	$ 29,094
Effect of 5% Convertible Note conversion		996		1,983
Net income (loss) attributable to common shareholders after effect of debt conversion	$ (193,346)	$ 15,548	$ (373,545)	$ 31,077
Weighted Average Number of Shares Outstanding Reconciliation [Abstract]
Basic weighted average common shares outstanding	75,410,000	86,172,000	75,334,000	86,064,000
Effect of dilutive securities		17,602,373		17,447,130
Diluted weighted average common shares outstanding	75,410,000	103,774,000	75,334,000	103,511,000
Basic net income (loss) per share	$ (2.56)	$ 0.17	$ (4.96)	$ 0.34
Diluted net income (loss) per share	$ (2.56)	$ 0.15	$ (4.96)	$ 0.30
Anitdilutive securities excluded from calculation of diluted net income	10,888,828	4,500,000	10,888,828	4,500,000

Segment Reporting - Selected Fi

Segment Reporting - Selected Financial Information - (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jul. 31, 2015	Jul. 31, 2014	Jul. 31, 2015	Jul. 31, 2014	Jan. 31, 2015
REVENUES
Oil and natural gas liquids sales	$ 55,263	$ 80,506	$ 103,041	$ 141,340
Oilfield services for third parties	54,470	61,483	124,980	100,431
Total revenues	109,733	141,989	228,021	241,771
EXPENSES:
Lease operating and production taxes	16,818	15,375	32,514	26,449
Gathering, transportation and processing	6,641	3,733	12,989	7,535
Depreciation and amortization	32,244	26,707	70,050	47,994
Impairment of oil and natural gas properties	206,000		398,000
Accretion of asset retirement obligations	90	40	147	65
Cost of oilfield services	46,719	43,554	112,183	71,264
Salaries and benefits	7,569	6,533	15,992	12,794
Stock-based compensation	3,626	1,807	6,134	3,815
Other general and administrative	3,394	5,751	7,322	10,883
Total operating expenses	323,101	103,500	655,331	180,799
INCOME FROM OPERATIONS	(213,368)	38,489	(427,310)	60,972
Other income (expense), net	20,022	(13,598)	324	(11,528)
INCOME (LOSS) BEFORE INCOME TAXES	(193,346)	24,891	(426,986)	49,444
Net oil and natural gas properties	787,767		787,767		$ 1,126,090
Oilfield services equipment, net	79,997		79,997		87,549
Other property and equipment, net	48,825		48,825		47,367
Total assets	1,209,957		1,209,957		1,654,870
Total liabilities	1,032,265		1,032,265		$ 1,109,852
Eliminations And Other [Member]
REVENUES
Oilfield services for third parties	(360)	(2,610)	(940)	(3,219)
Total revenues	(14,961)	(40,572)	(25,045)	(63,056)
EXPENSES:
Depreciation and amortization	(1,408)	(4,456)	(2,715)	(7,088)
Cost of oilfield services	(8,396)	(25,313)	(14,756)	(41,314)
Total operating expenses	(9,804)	(29,769)	(17,471)	(48,402)
INCOME FROM OPERATIONS	(5,157)	(10,803)	(7,574)	(14,654)
Other income (expense), net	(539)	(912)	(1,046)	(1,266)
INCOME (LOSS) BEFORE INCOME TAXES	(5,696)	(11,715)	(8,620)	(15,920)
Net oil and natural gas properties	(83,402)		(83,402)
Total assets	(103,634)		(103,634)
Total liabilities	(20,232)		(20,232)
Intersegment Revenues [Member] | Eliminations And Other [Member]
REVENUES
Total revenues	(14,601)	(37,962)	(24,105)	(59,837)
Exploration and Production [Member]
REVENUES
Oil and natural gas liquids sales	55,263	80,506	103,041	141,340
Total revenues	55,263	80,506	103,041	141,340
EXPENSES:
Lease operating and production taxes	16,818	15,375	32,514	26,449
Gathering, transportation and processing	6,641	3,733	12,989	7,535
Depreciation and amortization	24,527	26,287	53,826	46,440
Impairment of oil and natural gas properties	206,000		398,000
Accretion of asset retirement obligations	90	40	147	65
Salaries and benefits	584	1,560	925	2,801
Stock-based compensation	375	343	696	738
Other general and administrative	349	2,882	756	4,419
Total operating expenses	255,384	50,220	499,853	88,447
INCOME FROM OPERATIONS	(200,121)	30,286	(396,812)	52,893
Other income (expense), net	18,290	(4,267)	(2,712)	(10,834)
INCOME (LOSS) BEFORE INCOME TAXES	(181,831)	26,019	(399,524)	42,059
Net oil and natural gas properties	871,169		871,169
Other property and equipment, net	9,194		9,194
Total assets	1,023,660		1,023,660
Total liabilities	770,143		770,143
Oilfield Services [Member]
REVENUES
Oilfield services for third parties	54,830	64,093	125,920	103,650
Total revenues	69,431	102,055	150,025	163,487
EXPENSES:
Depreciation and amortization	8,718	4,690	18,207	8,280
Cost of oilfield services	56,353	68,867	126,939	112,578
Salaries and benefits	3,940	2,922	8,769	5,660
Stock-based compensation	84	127	135	217
Other general and administrative	1,034	2,329	2,831	4,688
Total operating expenses	70,129	78,935	156,881	131,423
INCOME FROM OPERATIONS	(698)	23,120	(6,856)	32,064
Other income (expense), net	(845)	(667)	(1,720)	(1,174)
INCOME (LOSS) BEFORE INCOME TAXES	(1,543)	22,453	(8,576)	30,890
Oilfield services equipment, net	79,997		79,997
Other property and equipment, net	21,759		21,759
Total assets	159,486		159,486
Total liabilities	130,685		130,685
Oilfield Services [Member] | Intersegment Revenues [Member]
REVENUES
Total revenues	14,601	37,962	24,105	59,837
Corporate And Other [Member]
EXPENSES:
Depreciation and amortization	407	186	732	362
Cost of oilfield services	(1,238)
Salaries and benefits	3,045	2,051	6,298	4,333
Stock-based compensation	3,167	1,337	5,303	2,860
Other general and administrative	2,011	540	3,735	1,776
Total operating expenses	7,392	4,114	16,068	9,331
INCOME FROM OPERATIONS	(7,392)	(4,114)	(16,068)	(9,331)
Other income (expense), net	3,116	(7,752)	5,802	1,746
INCOME (LOSS) BEFORE INCOME TAXES	(4,276)	$ (11,866)	(10,266)	$ (7,585)
Other property and equipment, net	17,872		17,872
Total assets	130,445		130,445
Total liabilities	$ 151,669		$ 151,669

Segment Reporting - (Details)

Segment Reporting - (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jul. 31, 2015USD ($)	Jul. 31, 2014USD ($)	Jul. 31, 2015USD ($)segment	Jul. 31, 2014USD ($)
Number of reportable segments | segment			2
Depreciation, Depletion and Amortization	$ 32,244	$ 26,707	$ 70,050	$ 47,994
TUSA [Member]
Depreciation, Depletion and Amortization	$ 100	$ 2,900	$ 600	$ 4,300

Long-Term Debt - Schedule of lo

Long-Term Debt - Schedule of long term debt- (Details) - USD ($) $ in Thousands	Jul. 31, 2015	Jan. 31, 2015	Jul. 18, 2014
Debt Instrument [Line Items]
5% Convertible Note	$ 139,295	$ 135,877
Credit facility	259,192	224,159
Other notes and mortgages payable	13,364	10,605
TUSA 6.75% notes	425,889	429,500
Total debt	837,740	800,141
Other notes and mortgages payable	(677)	(503)
Total long-term debt	$ 837,063	$ 799,638
TUSA 6.75% Notes [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate	6.75%	6.75%	6.75%
Convertible Notes [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate	5.00%	5.00%
TUSA [Member]
Debt Instrument [Line Items]
Credit facility	$ 172,272	$ 119,272
Rockpile [Member]
Debt Instrument [Line Items]
Credit facility	$ 86,920	$ 104,887

Long-Term Debt - Convertible no

Long-Term Debt - Convertible note- (Details) - USD ($) $ / shares in Units, $ in Thousands	Jul. 31, 2015	Jan. 31, 2015
Debt Instrument [Line Items]
Accrued interest	$ 1,725	$ 2,250
Convertible Notes [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate	5.00%	5.00%
Debt instrument, face amount	$ 120,000
Convertible note, conversion price	$ 8
Accrued interest	$ 19,300

Long-term Debt - TUSA credit fa

Long-term Debt - TUSA credit facility - (Details) - USD ($) $ in Millions	6 Months Ended
	Jul. 31, 2015	Apr. 30, 2015	Nov. 25, 2014	Apr. 30, 2014
Line of Credit Facility [Line Items]
Credit agreement borrowing base		$ 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] - USD ($) $ in Millions	6 Months Ended
	Jul. 31, 2015	Nov. 13, 2014	Mar. 25, 2014
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity			$ 100
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%
Letter of Credit [Member]
Debt Instrument [Line Items]
Credit facility, fronting fee percentage	0.125%
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity		$ 150
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%
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%

Long-term Debt - TUSA 6.75% Not

Long-term Debt - TUSA 6.75% Note - (Details) - USD ($) $ in Thousands	3 Months Ended	6 Months Ended	12 Months Ended
	Jul. 31, 2015	Jul. 31, 2015	Jan. 31, 2015	Jul. 18, 2014
Debt Instrument [Line Items]
Gain (loss) on extinguishment of debt	$ 1,156	$ 1,156
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			$ 20,500
Repurchased amount	$ 2,500	$ 2,500	13,900
Gain (loss) on extinguishment of debt			$ 6,600
TUSA 6.75% Notes [Member] | Redemption prior to July 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%

Hedging And Commodity Derivat41

Hedging And Commodity Derivative Financial Instruments - (Details) $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
	Aug. 31, 2015USD ($)	Jul. 31, 2015USD ($)	Jul. 31, 2014USD ($)	Jul. 31, 2015USD ($)item	Jul. 31, 2014USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Number of counterparties | item				4
Realized commodity derivative gains (losses)	$ 9,300	$ 17,016	$ (2,954)	$ 36,484	$ (3,772)
Unrealized commodity derivative gains (losses)		8,033	2,033	(25,409)	(2,605)
Commodity derivatives gains (losses)				$ 11,075	$ (6,377)
Crude Oil Derivative Contract [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized commodity derivative gains (losses)		17,016	(2,954)
Unrealized commodity derivative gains (losses)		8,033	2,033
Commodity derivatives gains (losses)		$ 25,049	$ (921)

Hedging And Commodity Derivat42

Hedging And Commodity Derivative Financial Instruments - Notional - (Details) $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
	Aug. 31, 2015USD ($)bbl / item$ / bbl	Jul. 31, 2015USD ($)bbl / item$ / bbl	Jul. 31, 2014USD ($)	Jul. 31, 2015USD ($)bbl / item$ / bbl	Jul. 31, 2014USD ($)
Derivative [Line Items]
Quantity, (bbls)	2,000
Notional Disclosures [Abstract]
Realized commodity derivative gains (losses) | $	$ 9,300	$ 17,016	$ (2,954)	$ 36,484	$ (3,772)
Notional amount per day (in Bbl)	2,000
Average fixed price | $ / bbl	60.34
Fiscal 2016 Collar [Member]
Derivative [Line Items]
End date				August 1, 2015 to January 31, 2016
Contract type				Collar
Basis				NYMEX
Quantity, (bbls)		2,739		2,739
Put strike price | $ / bbl		85.45		85.45
Call strike price | $ / bbl		98.20		98.20
Notional Disclosures [Abstract]
Notional amount per day (in Bbl)		2,739		2,739
Fiscal 2016 Swap [Member]
Derivative [Line Items]
End date				August 1, 2015 to January 31, 2016
Contract type				Swap
Basis				NYMEX
Quantity, (bbls)		1,755		1,755
Weighted average price | $ / bbl		60.22		60.22
Notional Disclosures [Abstract]
Notional amount per day (in Bbl)		1,755		1,755
Fiscal 2017 Swap [Member]
Derivative [Line Items]
End date				February 1, 2016 to January 31, 2017
Contract type				Swap
Basis				NYMEX
Quantity, (bbls)		2,746		2,746
Weighted average price | $ / bbl		60.23		60.23
Notional Disclosures [Abstract]
Notional amount per day (in Bbl)		2,746		2,746

Hedging And Commodity Derivat43

Hedging And Commodity Derivative Financial Instruments - Fair values of commodity derivatives - (Details) - USD ($) $ in Thousands	Jul. 31, 2015	Jan. 31, 2015
Derivatives, Fair Value [Line Items]
Derivative Assets	$ 29,366	$ 54,775
Crude Oil Derivative Contract [Member] | Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets	26,677	$ 54,775
Crude Oil Derivative Contract [Member] | Long-Term Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets	$ 2,689

Oil And Natural Gas Propertie44

Oil And Natural Gas Properties - (Details) - Jun. 30, 2014 - Marathon Oil Company [Member] $ in Millions	USD ($)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) - Jul. 31, 2014 - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	Total	Total
Acquisitions [Abstract]
Operating revenue	$ 146,559	$ 253,206
Net income (loss)	$ 15,427	$ 31,341
Earnings (loss) per common share, basic	$ 0.18	$ 0.36
Earnings (loss) per common share, diluted	$ 0.16	$ 0.32
Weighted average common shares outstanding, basic	86,172	86,064
Weighted average common shares outstanding, diluted	103,774	103,511
Pro forma depreciation, amortization and accretion expense	$ 1,300	$ 3,300

Equity Investment And Equity 46

Equity Investment And Equity Investment Derivatives - Equity Investment - (Details) - USD ($)	Feb. 02, 2015	Jul. 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 ($)	Jul. 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) - Jul. 31, 2015 - USD ($) $ in Thousands	Total
Schedule of Equity Method Investments [Line Items]
Equity investment, Beginning balance	$ 64,411
Gain on Caliber capital transactions	2,880
Equity investment, Ending balance	73,709
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	1,902
Change in fair value of warrants	4,516
Gain on Caliber capital transactions	2,880
Equity investment, Ending balance	73,709
Fair value of warrants	$ 5,020

Capital Stock (Details)

Capital Stock (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jul. 31, 2015	Jul. 31, 2015	Jan. 31, 2015
Common stock issued or reserved		106,700,000
Common stock, shares issued	75,488,871	75,488,871	75,174,442
Common stock, shares outstanding	75,488,871	75,488,871	75,174,442
Stock Repurchase authorized (Tranche 1)	$ 25	$ 25
Common stock repurchased (in shares)	0	0
Authorized shares remaining repurchase	5,374,890	5,374,890
2011 Omnibus Incentive Plan
Shares reserved for issuance	1,800,000	1,800,000
2014 Plan
Shares reserved for issuance	3,100,000	3,100,000
Shares reserved for future grants	2,900,000	2,900,000
CEO Stand-Alone Stock Option Agreement
Shares reserved for issuance	6,000,000	6,000,000
Convertible Notes Payable [Member]
Shares reserved for issuance	17,400,000	17,400,000

Share-Based Compensation (Detai

Share-Based Compensation (Details) - USD ($) $ in Thousands, shares in Millions	3 Months Ended		6 Months Ended
	Jul. 31, 2015	Jul. 31, 2014	Jul. 31, 2015	Jul. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense before capitalized amount	$ 4,015	$ 2,117	$ 6,843	$ 4,464
Less amounts capitalized to oil and natural gas properties	(389)	(310)	(709)	(649)
Stock-based compensation, net	$ 3,626	1,807	$ 6,134	3,815
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	$ 2,584	1,503	$ 4,663	3,274
Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense before capitalized amount	1,347	487	2,045	973
RockPile Stock Based Compensation Related to Series [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense before capitalized amount	$ 84	$ 127	$ 135	$ 217

Share-Based Compensation - Rest

Share-Based Compensation - Restricted stock units - (Details) - Jul. 31, 2015 - Restricted Stock Units (RSUs) [Member] - USD ($) $ / shares in Units, $ in Millions	Total
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation	$ 23.2
Unrecognized compensation, recognition period	3 years 3 months 18 days
Number of shares per vesting unit	1
Outstanding, Unvested Beginning Balance	2,914,045
Outstanding, Weighted-Average Award Date Fair Value, Beginning Balance	$ 7.92
Units granted, number of units	1,773,343
Units granted, Weighted Average Award Date Fair Value	$ 4.93
Units forfeited, Number of Shares	(63,588)
Units forfeited, Weighted Average Award Date Fair Value	$ 8.62
Units that vested, Number of Shares	(434,971)
Units that vested, Weighted Average Award Date Fair Value	$ 7.79
Outstanding, Unvested Ending Balance	4,188,829
Outstanding, Weighted-Average Grant Date Fair Value, Ending Balance	$ 6.66
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) - Jul. 31, 2015 - USD ($) $ / shares in Units, $ in Millions	Total
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	1,200,000
Weighted average exercise price per share	$ 11.54
Weighted average remaining contractual life (years)	7 years 10 months 6 days
Weighted average exercise price per share (exercisable)	$ 11.25
Weighted average remaining contractual life (years) (exercisable)	7 years 11 months 5 days
Unrecognized compensation cost related to awards	$ 16.5
Unrecognized compensation, recognition period	2 years 9 months 18 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	$ 7.50
Remaining contractual life	7 years 11 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	$ 8.50
Remaining contractual life	7 years 11 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	$ 10
Remaining contractual life	7 years 11 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	$ 12
Remaining contractual life	7 years 11 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	$ 15
Remaining contractual life	7 years 11 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	$ 12
Remaining contractual life	6 years 1 month 13 days
Outstanding options	233,333
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	$ 14
Remaining contractual life	6 years 1 month 13 days
Outstanding options	233,333
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	$ 16
Remaining contractual life	9 years 1 month 13 days
Outstanding options	233,334

Share-Based Compensation - Rock

Share-Based Compensation - Rockpile share based compensation - (Details) - Jul. 31, 2015 - USD ($) $ in Millions	Total
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding, Number of Units, Beginning Balance	5,302,000
Units forfeited	(170,000)
Outstanding, Number of Units, Ending Balance	5,132,000
Grants, Number of Vested Units	3,419,600
Grants, Number of Unvested Units	1,712,400
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	$ 2.3
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	30,000
Grants, Number of Unvested Units	30,000
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
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	46 months

Fair Value Measurements - Asset

Fair Value Measurements - Assets and liabilities table - (Details) - Fair Value, Measurements, Recurring [Member] - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jul. 31, 2015	Jan. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rockpile earn-out liability	$ (1,242)	$ (1,825)
Equity Investment Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	5,020
Crude Oil Derivative Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	29,366
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rockpile earn-out liability	(1,242)	$ (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	29,366
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	$ 5,020

Fair Value Measurements - Debt

Fair Value Measurements - Debt instruments carrying value - (Details) - USD ($) $ in Thousands	Jul. 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	$ 139,295	$ 135,877
Convertible note	136,361	137,790
Long-term portion of credit facilities	259,192	224,159
Revolving credit facilities, carrying value	259,192	224,159
Revolving credit facilities, fair value	259,192	224,159
TUSA 6.75% notes, carrying value	425,889	429,500
TUSA 6.75% notes, fair value	317,293	303,871
Other notes and mortgages payable, carrying value	13,364	10,605
Other notes and mortgages payable, fair value	$ 13,364	$ 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) - Jul. 31, 2015 $ in Thousands	USD ($)item
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
Caliber North Dakota LLC [Member]
Related Party Transaction [Line Items]
Term of midstream agreements with Caliber	15 years
Minmum commitment over term of agreements	$ 405,000
Remaining commitment	$ 336,300

Supplemental Disclosures Of C57

Supplemental Disclosures Of Cash Flow Information (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jul. 31, 2015	Jul. 31, 2014	Jul. 31, 2015	Jul. 31, 2014
Supplemental Disclosures of Cash Flow Information [Abstract]
Interest expense			$ 16,078	$ 4,717
Income taxes				550
Increase (decrease) in accounts payable and accrued liabilities			(15,770)	37,151
Capitalized stock-based compensation	$ 389	$ 310	709	649
Change in asset retirement obligations			$ 425	1,106
Notes payable issued for redemption of RockPile B units				$ 1,041