Triangle Petroleum (TPLMQ) Inactive 10-Q8 Jun 152016 Q1 Quarterly reportFinancial data

Company Profile

Document_And_Entity_Informatio

Document And Entity Information	3 Months Ended
Document And Entity Information	Apr. 30, 2015	Jun. 04, 2015
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	30-Apr-15
Document Fiscal Period Focus	Q1
Document Fiscal Year Focus	2016
Entity Registrant Name	Triangle Petroleum Corp
Entity Central Index Key	1281922
Current Fiscal Year End Date	-30
Entity Filer Category	Accelerated Filer
Entity Current Reporting Status	Yes
Entity Common Stock, Shares Outstanding		75,385,334

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Apr. 30, 2015	Jan. 31, 2015
In Thousands, unless otherwise specified	Apr. 30, 2015	Jan. 31, 2015
CURRENT ASSETS
Cash and equivalents	$50,277	$67,871
Accounts receivable	124,821	171,911
Commodity derivatives	24,796	54,775
Other current assets	10,605	14,952
Total current assets	210,499	309,509
Oil and natural gas properties, at cost, full cost method of accounting:
Proved properties	1,239,328	1,159,584
Unproved properties and properties under development, not being amortized	124,518	142,896
Total oil and natural gas properties	1,363,846	1,302,480
Accumulated amortization	-397,069	-176,390
Net oil and natural gas properties	966,777	1,126,090
Oilfield services equipment - net	84,398	87,549
Other property and equipment, net	48,259	47,367
Net property, plant and equipment	1,099,434	1,261,006
Deferred loan costs	14,312	14,038
Equity investment	67,716	64,411
Other	5,812	5,906
Total other assets	87,840	84,355
Total assets	1,397,773	1,654,870
CURRENT LIABILITIES
Accounts payable and accrued capital expenditures	139,140	176,182
Other accrued liabilities	51,809	73,440
Current portion of long-term debt	508	503
Interest payable	9,132	2,250
Deferred income taxes		19,467
Derivative liability	292
Total current liabilities	200,881	271,842
LONG-TERM LIABILITIES
5% convertible note	137,576	135,877
Borrowings on credit facilities	245,288	224,159
TUSA 6.75% notes	429,500	429,500
Other notes and mortgages payable	9,982	10,102
Deferred income taxes		33,974
Derivative liability	3,171
Other	4,085	4,398
Total liabilities	1,030,483	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	547,488	545,017
Retained earnings (accumulated deficit)	-180,199
Total stockholders' equity	367,290	545,018
Total liabilities and stockholders' equity	$1,397,773	$1,654,870

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Apr. 30, 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	75,327,056	75,174,442
Common stock, shares outstanding	75,327,056	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_Ope

Consolidated Statements of Operations (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Apr. 30, 2015	Apr. 30, 2014
REVENUES
Oil and natural gas liquids sales	$47,778	$60,834
Oilfield services	70,510	38,948
Total revenues	118,288	99,782
EXPENSES:
Lease operating expenses	10,909	4,726
Gathering, transportation and processing	6,348	3,802
Production taxes	4,787	6,348
Depreciation and amortization	37,806	21,287
Impairment of oil and natural gas properties	192,000
Accretion of asset retirement obligations	57	25
Oilfield services	65,464	27,710
General and administrative, net of amounts capitalized	14,859	13,401
Total operating expenses	332,230	77,299
INCOME FROM OPERATIONS	-213,942	22,483
OTHER INCOME (EXPENSE):
Interest expense, net	-9,106	-2,672
Amortization of deferred loan costs	-616	-192
Realized commodity derivative gains (losses)	19,468	-818
Unrealized commodity derivative gains (losses)	-33,442	-4,638
Equity investment income (loss)	188	-126
Gain on equity investment derivatives		10,454
Gain on Caliber capital transactions	2,880
Other income	930	62
Total other income (expense)	-19,698	2,070
INCOME (LOSS) BEFORE INCOME TAXES	-233,640	24,553
Income tax provision	-53,441	10,011
NET INCOME (LOSS)	-180,199	14,542
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCKHOLDERS	($180,199)	$14,542
Earnings (loss) per common share outstanding:
Basic	($2.39)	$0.17
Diluted	($2.39)	$0.15
Weighted average common shares outstanding:
Basic	75,256	85,952
Diluted	75,256	103,314

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Apr. 30, 2015	Apr. 30, 2014
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	($180,199)	$14,542
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	37,806	21,287
Impairment of oil and natural gas properties	192,000
Share-based compensation	2,508	2,008
Interest expense not paid in cash	1,699	1,011
Amortization of deferred loan costs	616	192
Accretion of asset retirement obligations	57	25
Unrealized commodity derivative (gains) losses	33,442	4,638
Equity investment income (loss)	-188	126
Gain on equity investment derivatives		-10,454
Gain on Caliber capital transactions	-2,880
Deferred income taxes	-53,441	9,884
Changes in related current assets and current liabilities:
Accounts receivable	47,090	-627
Other current assets	4,347	-855
Accounts payable and accrued liabilities	-42,955	-1,846
Asset retirement expenditures	-5	-136
Other	-642	48
Cash provided by operating activities	39,255	39,843
CASH FLOWS FROM INVESTING ACTIVITIES:
Oil and natural gas expenditures	-74,834	-73,350
Acquisitions of oil and natural gas properties	-222	-4,393
Purchase of oil field services equipment	-5,299	-12,949
Purchase of other property and equipment	-2,251	-1,122
Sale of oil and natural gas properties	6,000
Other		8
Cash used in investing activities	-76,606	-91,806
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from credit facilities	51,000	99,616
Repayments of credit facilities	-29,871	-21,515
Repayments of other notes and mortgages payable	-125	-100
Debt issuance costs	-890	-1,008
Payments to settle tax on vested restricted stock units	-357	-1,498
Cash provided by financing activities	19,757	75,495
NET INCREASE (DECREASE) IN CASH AND EQUIVALENTS	-17,594	23,532
CASH AND EQUIVALENTS, BEGINNING OF PERIOD	105,282	81,750
CASH AND EQUIVALENTS, END OF PERIOD	$50,277

Consolidated_Statement_of_Stoc

Consolidated Statement of Stockholders' Equity (USD $)	Common Stock [Member]	Additional Paid-In Capital [Member]	Accumulated Deficit [Member]	Total
In Thousands, except Share data	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)		-357		-357
Vesting of restricted stock units (net of shares surrendered for taxes), shares	152,614
Share-based compensation		2,828		2,828
Net income (loss) for the year			-180,199	-180,199
Balance at Apr. 30, 2015	$1	$547,488	($180,199)	$367,290
Balance, shares at Apr. 30, 2015	75,327,056			75,327,056

Description_Of_Business

Description Of Business	3 Months Ended
Description Of Business	Apr. 30, 2015
Description Of Business [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 (“FREIF”). 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_Account

Summary Of Significant Accounting Policies	3 Months Ended
Summary Of Significant Accounting Policies	Apr. 30, 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 undeveloped 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 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. The Company follows the full-cost method of accounting for its oil and natural gas properties. Under this method of accounting, all costs incurred for both successful and unsuccessful exploration and development activities, including salaries, benefits and other internal costs directly identified with these activities, and oil and natural gas property acquisitions are capitalized. The net book value of oil and natural gas properties, less related deferred income taxes, may not exceed a calculated “ceiling.” The ceiling limitation is the estimated after-tax future net cash flows from proved oil and natural gas reserves, discounted at ten percent per annum. Estimated future net cash flows are calculated using end-of-period costs and an unweighted arithmetic average of commodity prices in effect on the first day of each of the previous twelve months, held flat for the life of the production, except where prices are defined by contractual arrangements.

	Any excess of the net book value of proved oil and natural gas properties, less related deferred income taxes, over the ceiling is charged to expense and reflected as “Impairment of oil and natural gas properties” in the accompanying condensed consolidated statements of operations. The ceiling limitation is evaluated quarterly.

	At April 30, 2015, the carrying value of our oil and natural gas properties exceeded the calculated value of the ceiling limitation resulting in an impairment of $192.0 million. Triangle will likely be required to recognize an additional impairment of oil and natural gas properties in future periods if oil and natural gas prices remain at current levels or continue to decline and such impairment will likely be material.

	Oilfield Services Equipment and Other Property and Equipment. Oilfield services equipment and other property and equipment consisted of the following as of:




	(in thousands)		31-Jan-15			30-Apr-15
	Land		$	7,888		$	7,888
	Building and leasehold improvements			33,625			34,160
	Oilfield service equipment			116,354			121,653
	Vehicles			4,811			5,521
	Software, computers and office equipment			5,327			6,050
	Capital leases			853			853
	Total depreciable assets			168,858			176,125
	Accumulated depreciation			-35,189			-44,998
	Depreciable assets, net			133,669			131,127
	Assets not placed in service			1,247			1,530
	Total oilfield service equipment and other property & equipment, net		$	134,916		$	132,657

	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 $192.0 million. 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, 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 current period 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 April 30, 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 three 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 April 30,
			2014			2015
	Dilutive			17,362,426			—
	Anti-dilutive shares			6,000,000			10,910,078

	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 April 30,
	(in thousands, except per share data)		2014			2015
	Net income (loss) attributable to common stockholders		$	14,542		$	-180,199
	Effect of 5% convertible note conversion			918			—
	Net income (loss) attributable to common stockholders after effect of debt conversion		$	15,460		$	-180,199

	Basic weighted average common shares outstanding			85,952			75,256
Effect of dilutive securities			17,362			—
Diluted weighted average common shares outstanding			103,314			75,256

Basic net income (loss) per share		$	0.17		$	-2.39
Diluted net income (loss) per share		$	0.15		$	-2.39

Reclassifications. Certain amounts in our unaudited condensed consolidated statement of operations for the three months ended April 30, 2014 have been reclassified to conform to the financial statement presentation for the period ended April 30, 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 reported.

Segment_Reporting

Segment Reporting	3 Months Ended
Segment Reporting	Apr. 30, 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 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 April 30, 2015 and 2014.


			For the Three Months Ended April 30, 2015
			Exploration						Corporate
			and			Oilfield			and						Consolidated
	(in thousands)		Production			Services			Other			Eliminations			Total
	Revenues:
	Oil, natural gas and natural gas liquids sales		$	47,778		$	—		$	—		$	—		$	47,778
	Oilfield services for third parties			—			71,090			—			-580			70,510
	Intersegment revenues			—			9,504			—			-9,504			—
	Total revenues			47,778			80,594			—			-10,084			118,288
	Expenses:
	Lease operating and production taxes			15,696			—			—			—			15,696
	Gathering, transportation and processing			6,348			—			—			—			6,348
	Depreciation and amortization			29,299			9,489			325			-1,307			37,806
	Impairment of oil and natural gas properties			192,000			—			—			—			192,000
	Accretion of asset retirement obligations			57			—			—			—			57
	Cost of oilfield services			—			70,586			1,238			-6,360			65,464
	General and administrative, net of amounts capitalized:
	Salaries and benefits			341			4,829			3,253			—			8,423
	Stock-based compensation			321			51			2,136			—			2,508
	Other general and administrative			407			1,797			1,724			—			3,928
	Total operating expenses			244,469			86,752			8,676			-7,667			332,230
	Income (loss) from operations			-196,691			-6,158			-8,676			-2,417			-213,942
	Other income (expense), net			-21,002			-875			2,686			-507			-19,698
	Income (loss) before income taxes		$	-217,693		$	-7,033		$	-5,990		$	-2,924		$	-233,640
	As of April 30, 2015:
	Net oil and natural gas properties		$	1,044,482		$	—		$	—		$	-77,705		$	966,777
	Oilfield services equipment - net		$	—		$	84,398		$	—		$	—		$	84,398
	Other property and equipment - net		$	9,116		$	22,508		$	16,635		$	—		$	48,259
	Total assets		$	1,200,737		$	169,519		$	125,697		$	-98,180		$	1,397,773
	Total liabilities		$	764,057		$	138,322		$	148,034		$	-19,930		$	1,030,483





			For the Three Months Ended April 30, 2014
			Exploration						Corporate
			and			Oilfield			and						Consolidated
	(in thousands)		Production			Services			Other			Eliminations			Total
	Revenues:
	Oil, natural gas and natural gas liquids sales		$	60,834		$	—		$	—		$	—		$	60,834
	Oilfield services for third parties			—			39,557			—			-609			38,948
	Intersegment revenues			—			21,875			—			-21,875			—
	Total revenues			60,834			61,432			—			-22,484			99,782
	Expenses:
	Lease operating and production taxes			11,074			—			—			—			11,074
	Gathering, transportation and processing			3,802			—			—			—			3,802
	Depreciation and amortization			20,153			3,590			176			-2,632			21,287
	Accretion of asset retirement obligations			25			—			—			—			25
	Cost of oilfield services			—			43,711			—			-16,001			27,710
	General and administrative, net of amounts capitalized:
	Salaries and benefits			1,241			2,738			2,282			—			6,261
	Stock-based compensation			395			90			1,523			—			2,008
	Other general and administrative			1,537			2,359			1,236			—			5,132
	Total operating expenses			38,227			52,488			5,217			-18,633			77,299
	Income (loss) from operations			22,607			8,944			-5,217			-3,851			22,483
	Other income (expense), net			-6,567			-507			9,498			-354			2,070
Income (loss) before income taxes		$	16,040		$	8,437		$	4,281		$	-4,205		$	24,553

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 April 30, 2015 and 2014, $0.5 and $1.4 million, respectively, of the depreciation and amortization elimination relates to the Exploration and Production segment and the balance relates to the Oilfield Services segment.

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 statements.

LongTerm_Debt

Long-Term Debt	3 Months Ended
	Apr. 30, 2015
Long-Term Debt [Abstract]
Long-term Debt	4. LONG-TERM DEBT

	The Company’s long-term debt consisted of the following as of January 31, 2015 and April 30, 2015:



		31-Jan-15		30-Apr-15
	5% convertible note	$	135,877	$	137,576
	TUSA credit facility due October 2018		119,272		146,272
	RockPile credit facility due March 2019		104,887		99,016
	TUSA 6.75% notes due July 2022		429,500		429,500
	Other notes and mortgages payable		10,605		10,490
	Total debt		800,141		822,854
	Less current portion of debt:
	Other notes and mortgages payable		-503		-508
	Total long-term debt	$	799,638	$	822,346

	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 October 31, 2017, the Company has the option to make such interest payments in cash. As of April 30, 2015, $17.6 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 domestic 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 April 30, 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 will pay a commitment fee that ranges between 0.375% and 0.50% per annum on the unused availability under the RockPile credit facility. RockPile will also pay 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. Triangle is not a guarantor under the RockPile credit facility.

	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 April 30, 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 redemption prices set forth in the Indenture, 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. TUSA immediately retired the repurchased notes and recognized a gain on extinguishment of debt of $6.6 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 April 30, 2015, TUSA was in compliance with all covenants under the TUSA 6.75% Notes.

Hedging_And_Commodity_Derivati

Hedging And Commodity Derivative Financial Instruments	3 Months Ended
Hedging And Commodity Derivative Financial Instruments	Apr. 30, 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 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 (in thousands):

			For the Three Months Ended April 30,
			2014			2015
	Realized commodity derivative gains (losses)		$	-818		$	19,468
	Unrealized commodity derivative gains (losses)			-4,638			-33,442
	Commodity derivative gains (losses), net		$	-5,456		$	-13,974

	The Company’s commodity derivative contracts as of April 30, 2015 are summarized below:


			Contract				Quantity	Weighted Average		Weighted Average		Weighted Average
			Type		Basis (1)		(Bbl/d)	Put Strike		Call Strike		Price
	May 1, 2015 to January 31, 2016		Collar		NYMEX		3,826	$	86.52	$	98.72
	May 1, 2015 to January 31, 2016		Swap		NYMEX		1,170					$	60.22
	February 1, 2016 to January 31, 2017		Swap		NYMEX		2,746					$	60.23


		-1		“NYMEX” refers to West Texas Intermediate crude oil prices at Cushing, Oklahoma as quoted on the New York Mercantile Exchange.

	The estimated fair values of commodity derivatives included in the consolidated balance sheets at January 31, 2015 and April 30, 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).




			31-Jan-15			30-Apr-15
	Current Assets:
	Crude oil derivative contracts		$	54,775		$	24,796

	Total derivative asset		$	54,775		$	24,796


	Current Liabilities:
	Crude oil derivative contracts		$	—		$	292

	Long-Term Liabilities:
	Crude oil derivative contracts			—			3,171

	Total derivative liability		$	—		$	3,463

Oil_And_Natural_Gas_Properties

Oil And Natural Gas Properties	3 Months Ended
Oil And Natural Gas Properties	Apr. 30, 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
	(in thousands, except per share data)	30-Apr-14
	Operating revenues	$	106,647
	Net income (loss)	$	15,919

	Earnings (loss) per common share
	Basic	$	0.19
	Diluted	$	0.16

	Weighted average common shares outstanding:
	Basic		85,952
	Diluted		103,314

	The pro forma information includes the effects of adjustments for depreciation and amortization expense of $2.0 million for the first quarter of fiscal year 2015. 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_I

Equity Investment And Equity Investment Derivatives	3 Months Ended
Equity Investment And Equity Investment Derivatives	Apr. 30, 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 Caliber Holdings”), a wholly-owned subsidiary of FREIF. 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 quarter 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 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. Triangle also recognized a gain of $0.2 million in the first quarter of fiscal year 2016 related to the fair value of the warrants issued, which will be amortized over the lives of the related warrants.

	The following summarizes the Company’s equity investment holdings in Caliber as of January 31, 2015 and April 30, 2015 and the strike prices for exercising warrants as of April 30, 2015:


		Expiration		Strike Price at		As of	As of
		Date		30-Apr-15		31-Jan-15	30-Apr-15
	Class A Units		—	$	—	7,000,000	7,000,000
	Series 1 Warrants		1-Oct-24	$	12.78	5,600,000	6,615,467
	Series 2 Warrants		1-Oct-24	$	22.09	2,400,000	2,835,200
	Series 3 Warrants		12-Sep-25	$	22.09	3,000,000	3,544,000
	Series 4 Warrants		12-Sep-25	$	28.09	2,000,000	2,362,667
	Series 6 Warrants		2-Feb-18	$	12.50	—	1,269,333

	The following summarizes the activities related to the Company’s equity investment in Caliber for the three months ended April 30, 2015:

	(in thousands)	For the Three Months Ended April 30, 2015
	Balance at January 31, 2015	$	64,411

	Capital contributions		—
	Distributions		—
	Equity investment share of net income before intra-company profit eliminations		425
	Change in fair value of warrants		—
	Gain on Caliber capital transactions		2,880

	Balance at April 30, 2015	$	67,716

	Fair value of warrants at April 30, 2015	$	504

	Equity Investment Derivatives. At January 31, 2015 and April 30, 2015, the Company held Class A (Series 1 through Series 4 and Series 6) Warrants to acquire additional ownership in Caliber. These instruments are considered to be equity investment derivatives and are valued at each reporting period using valuation techniques (a Monte Carlo Simulation (“MCS”) model) for which the inputs are generally less observable than from objective sources.

Capital_Stock

Capital Stock	3 Months Ended
Capital Stock	Apr. 30, 2015
Capital Stock [Abstract]
Capital Stock	8. CAPITAL STOCK

	The Company had 106.5 million shares of common stock issued or reserved for issuance at April 30, 2015. At April 30, 2015, the Company had 75.3 million shares of common stock issued and outstanding. The Company also had 2.0 million shares of common stock reserved for issuance pursuant to outstanding awards under its 2011 Omnibus Incentive Plan and 2.9 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 3.1 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 17.2 million shares of common stock reserved for issuance pursuant to the Convertible Note at April 30, 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 months ended April 30, 2015. As of April 30, 2015, the number of shares of common stock remaining available for repurchase under the Board approved program was 5,160,820 shares.

ShareBased_Compensation

Share-Based Compensation	3 Months Ended
Share-Based Compensation	Apr. 30, 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 months ended April 30, 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 April 30,
	(in thousands)		2014			2015
	Restricted stock units		$	1,771		$	2,079
	Stock options			486			698
	RockPile Series B Units			90			51
				2,347			2,828
	Less amounts capitalized to oil and natural gas properties			-339			-320
	Compensation expense		$	2,008		$	2,508

	Restricted Stock Units. During the three months ended April 30, 2015, the Company granted 1,568,093 restricted stock units as compensation to employees, officers, and directors which generally vest over one to five years. As of April 30, 2015, there was approximately $25.1 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 3.6 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 three months ended April 30, 2015:

					Weighted
					Average
			Number of		Award Date
			Shares		Fair Value
	Restricted stock units outstanding - January 31, 2015		2,914,045		$	7.92
	Units granted		1,568,093		$	5.00
	Units forfeited		-50,588		$	8.92
	Units vested		-221,472		$	7.34
	Restricted stock units outstanding - April 30, 2015		4,210,078		$	6.86

	Stock Options. There were no grants, exercises or forfeitures of stock options during the three months ended April 30, 2015. The following table summarizes the stock options outstanding at April 30, 2015:



				Remaining
	Exercise Price			Contractual Life		Number of Shares
	per Share			(years)		Outstanding			Exercisable
	$	7.50		8.18			750,000			75,000
	$	8.50		8.18			750,000			75,000
	$	10.00		8.18			1,500,000			150,000
	$	12.00		8.18			1,500,000			150,000
	$	15.00		8.18			1,500,000			150,000
	$	12.00		6.37			233,333			—
	$	14.00		6.37			233,333			—
	$	16.00		9.37			233,334			—
							6,700,000			600,000

	Weighted average exercise price per share					$	11.54		$	11.25

	Weighted average remaining contractual life						8.10			8.18

	As of April 30, 2015, there was approximately $17.9 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 3.1 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 three months ended April 30, 2015:

			Series		Series		Series		Series
			B-1 units		B-2 units		B-3 units		B-4 units		Total
	Units outstanding - January 31, 2015		2,920,000		60,000		910,000		1,412,000		5,302,000
	Units redeemed		—		—		—		—		—
	Units granted		—		—		—		—		—
	Units outstanding - April 30, 2015		2,920,000		60,000		910,000		1,412,000		5,302,000
Vested		2,920,000		30,000		188,000		—		3,138,000
Unvested		—		30,000		722,000		1,412,000		2,164,000

Series B Units currently have a 7 to 52 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 April 30, 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’ vesting schedule during the next five fiscal years.

Fair_Value_Measurements

Fair Value Measurements	3 Months Ended
Fair Value Measurements	Apr. 30, 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 April 30, 2015, by level within the fair value hierarchy:



			As of January 31, 2015
	(in thousands)		Level 1		Level 2		Level 3		Total
	Assets:
	Equity investment derivative assets		$	—	$	—	$	504	$	504
	Commodity derivative assets		$	—	$	54,775	$	—	$	54,775

	Liabilities:
	RockPile earn-out liability		$	—	$	-1,825	$	—	$	-1,825



			As of April 30, 2015
	(in thousands)		Level 1		Level 2		Level 3		Total
	Assets:
	Equity investment derivative assets		$	—	$	—	$	504	$	504
	Commodity derivative assets		$	—	$	24,796	$	—	$	24,796

	Liabilities:
	Commodity derivative liabilities		$	—	$	-3,463	$	—	$	-3,463
	RockPile earn-out liability		$	—	$	-1,226	$	—	$	-1,226

	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 April 30, 2015, commodity derivative instruments utilized by the Company consist of costless collars and swaps. The Company’s commodity derivative instruments are valued using public indices and are traded with third-party counterparties, but are not openly traded on an exchange. As such, the Company has classified these commodity derivative instruments as Level 2.

	Caliber Class A (Series 1 through Series 4 and Series 6) Warrants. The Company determines its estimate of the fair value of Caliber Class A Warrants using a MCS model. For each MCS, the value of the Class A Units was forecasted at the end of each quarter based on a predetermined yield, and the strike price for the warrant is adjusted accordingly. The fair value of the underlying Class A Units was estimated employing primarily a discounted cash flows analysis. At April 30, 2015, the Company’s Caliber Class A Warrants are valued using valuation models that are generally less observable from objective sources. As such, 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.

	Summary of Level 3 Financial Assets and Liabilities. The fair values of the Class A (Series 1 through Series 4 and Series 6) Warrants were estimated using a MCS model. The fair value of the Company’s equity investment derivative assets was $0.5 million at January 31, 2015 and April 30, 2015.

	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				30-Apr-15
			Carrying		Estimated		Carrying		Estimated
	(in thousands)		Value		Fair Value		Value		Fair Value
	5% convertible note		$	135,877	$	137,790	$	137,576	$	154,884
	Revolving credit facilities			224,159		224,159		245,288		245,288
	TUSA 6.75% notes			429,500		303,871		429,500		365,505
	Other notes and mortgages payable			10,605		10,605		10,490		10,490

Related_Party_Transactions

Related Party Transactions	3 Months Ended
Related Party Transactions	Apr. 30, 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 on the 2014 in-service dates for the Caliber facilities. The aggregate minimum revenue commitment over the term of the agreements is $405.0 million, of which $347.0 million was outstanding at April 30, 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 three months ended April 30, 2015, TUSA sold one salt water disposal well to an affiliate of Caliber for net proceeds of $6.0 million.

Supplemental_Disclosures_Of_Ca

Supplemental Disclosures Of Cash Flow Information	3 Months Ended
Supplemental Disclosures Of Cash Flow Information	Apr. 30, 2015
Supplemental Disclosures of Cash Flow Information [Abstract]
Supplemental Disclosures of Cash Flow Information
	12. SUPPLEMENTAL DISCLOSURES OF CASH FLOWS INFORMATION



		For the Three Months Ended April 30,
	(in thousands)	2014		2015
	Cash paid during the period for:
	Interest expense	$	1,661	$	1,890
	Income taxes	$	—	$	—

	Non-cash investing activities:
	Additions to oil and natural gas properties through:
	Increase (decrease) in accounts payable and accrued liabilities	$	10,167	$	-7,932
	Capitalized stock based compensation	$	339	$	320
	Change in asset retirement obligations	$	197	$	242

Summary_Of_Significant_Account1

Summary Of Significant Accounting Policies (Policies)	3 Months Ended
Summary Of Significant Accounting Policies (Policies)	Apr. 30, 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 undeveloped 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 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.
Use of Estimates
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
Principles of Consolidation
Oil And Natural Gas Properties	Oil and Natural Gas Properties. The Company follows the full-cost method of accounting for its oil and natural gas properties. Under this method of accounting, all costs incurred for both successful and unsuccessful exploration and development activities, including salaries, benefits and other internal costs directly identified with these activities, and oil and natural gas property acquisitions are capitalized. The net book value of oil and natural gas properties, less related deferred income taxes, may not exceed a calculated “ceiling.” The ceiling limitation is the estimated after-tax future net cash flows from proved oil and natural gas reserves, discounted at ten percent per annum. Estimated future net cash flows are calculated using end-of-period costs and an unweighted arithmetic average of commodity prices in effect on the first day of each of the previous twelve months, held flat for the life of the production, except where prices are defined by contractual arrangements.

	Any excess of the net book value of proved oil and natural gas properties, less related deferred income taxes, over the ceiling is charged to expense and reflected as “Impairment of oil and natural gas properties” in the accompanying condensed consolidated statements of operations. The ceiling limitation is evaluated quarterly.

	At April 30, 2015, the carrying value of our oil and natural gas properties exceeded the calculated value of the ceiling limitation resulting in an impairment of $192.0 million. Triangle will likely be required to recognize an additional impairment of oil and natural gas properties in future periods if oil and natural gas prices remain at current levels or continue to decline and such impairment will likely be material.

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)		31-Jan-15			30-Apr-15
	Land		$	7,888		$	7,888
	Building and leasehold improvements			33,625			34,160
	Oilfield service equipment			116,354			121,653
	Vehicles			4,811			5,521
	Software, computers and office equipment			5,327			6,050
	Capital leases			853			853
	Total depreciable assets			168,858			176,125
	Accumulated depreciation			-35,189			-44,998
	Depreciable assets, net			133,669			131,127
	Assets not placed in service			1,247			1,530
	Total oilfield service equipment and other property & equipment, net		$	134,916		$	132,657


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 $192.0 million. 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, 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 current period 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 April 30, 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 three 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 April 30,
			2014			2015
	Dilutive			17,362,426			—
	Anti-dilutive shares			6,000,000			10,910,078

	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 April 30,
	(in thousands, except per share data)		2014			2015
	Net income (loss) attributable to common stockholders		$	14,542		$	-180,199
	Effect of 5% convertible note conversion			918			—
	Net income (loss) attributable to common stockholders after effect of debt conversion		$	15,460		$	-180,199

	Basic weighted average common shares outstanding			85,952			75,256
	Effect of dilutive securities			17,362			—
	Diluted weighted average common shares outstanding			103,314			75,256

	Basic net income (loss) per share		$	0.17		$	-2.39
	Diluted net income (loss) per share		$	0.15		$	-2.39


Reclassifications	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 undeveloped 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 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. The Company follows the full-cost method of accounting for its oil and natural gas properties. Under this method of accounting, all costs incurred for both successful and unsuccessful exploration and development activities, including salaries, benefits and other internal costs directly identified with these activities, and oil and natural gas property acquisitions are capitalized. The net book value of oil and natural gas properties, less related deferred income taxes, may not exceed a calculated “ceiling.” The ceiling limitation is the estimated after-tax future net cash flows from proved oil and natural gas reserves, discounted at ten percent per annum. Estimated future net cash flows are calculated using end-of-period costs and an unweighted arithmetic average of commodity prices in effect on the first day of each of the previous twelve months, held flat for the life of the production, except where prices are defined by contractual arrangements.

	Any excess of the net book value of proved oil and natural gas properties, less related deferred income taxes, over the ceiling is charged to expense and reflected as “Impairment of oil and natural gas properties” in the accompanying condensed consolidated statements of operations. The ceiling limitation is evaluated quarterly.

	At April 30, 2015, the carrying value of our oil and natural gas properties exceeded the calculated value of the ceiling limitation resulting in an impairment of $192.0 million. Triangle will likely be required to recognize an additional impairment of oil and natural gas properties in future periods if oil and natural gas prices remain at current levels or continue to decline and such impairment will likely be material.

	Oilfield Services Equipment and Other Property and Equipment. Oilfield services equipment and other property and equipment consisted of the following as of:




	(in thousands)		31-Jan-15			30-Apr-15
	Land		$	7,888		$	7,888
	Building and leasehold improvements			33,625			34,160
	Oilfield service equipment			116,354			121,653
	Vehicles			4,811			5,521
	Software, computers and office equipment			5,327			6,050
	Capital leases			853			853
	Total depreciable assets			168,858			176,125
	Accumulated depreciation			-35,189			-44,998
	Depreciable assets, net			133,669			131,127
	Assets not placed in service			1,247			1,530
	Total oilfield service equipment and other property & equipment, net		$	134,916		$	132,657

	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 $192.0 million. 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, 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 current period 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 April 30, 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 three 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 April 30,
			2014			2015
	Dilutive			17,362,426			—
	Anti-dilutive shares			6,000,000			10,910,078

	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 April 30,
	(in thousands, except per share data)		2014			2015
	Net income (loss) attributable to common stockholders		$	14,542		$	-180,199
	Effect of 5% convertible note conversion			918			—
	Net income (loss) attributable to common stockholders after effect of debt conversion		$	15,460		$	-180,199

	Basic weighted average common shares outstanding			85,952			75,256
Effect of dilutive securities			17,362			—
Diluted weighted average common shares outstanding			103,314			75,256

Basic net income (loss) per share		$	0.17		$	-2.39
Diluted net income (loss) per share		$	0.15		$	-2.39

Reclassifications. Certain amounts in our unaudited condensed consolidated statement of operations for the three months ended April 30, 2014 have been reclassified to conform to the financial statement presentation for the period ended April 30, 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 reported.

Summary_Of_Significant_Account2

Summary Of Significant Accounting Policies (Tables)	3 Months Ended
Summary Of Significant Accounting Policies (Tables)	Apr. 30, 2015
Summary Of Significant Accounting Policies [Abstract]
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)	31-Jan-15		30-Apr-15
	Land	$	7,888	$	7,888
	Building and leasehold improvements		33,625		34,160
	Oilfield service equipment		116,354		121,653
	Vehicles		4,811		5,521
	Software, computers and office equipment		5,327		6,050
	Capital leases		853		853
	Total depreciable assets		168,858		176,125
	Accumulated depreciation		-35,189		-44,998
	Depreciable assets, net		133,669		131,127
	Assets not placed in service		1,247		1,530
	Total oilfield service equipment and other property & equipment, net	$	134,916	$	132,657


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 April 30,
		2014		2015
	Dilutive		17,362,426		—
	Anti-dilutive shares		6,000,000		10,910,078


Schedule of computations of net income(loss) per common share (basic and diluted)

		For the Three Months Ended April 30,
	(in thousands, except per share data)	2014		2015
	Net income (loss) attributable to common stockholders	$	14,542	$	-180,199
	Effect of 5% convertible note conversion		918		—
	Net income (loss) attributable to common stockholders after effect of debt conversion	$	15,460	$	-180,199

	Basic weighted average common shares outstanding		85,952		75,256
	Effect of dilutive securities		17,362		—
	Diluted weighted average common shares outstanding		103,314		75,256

	Basic net income (loss) per share	$	0.17	$	-2.39
	Diluted net income (loss) per share	$	0.15	$	-2.39

Segment_Reporting_Tables

Segment Reporting (Tables)	3 Months Ended
Segment Reporting (Tables)	Apr. 30, 2015
Segment Reporting [Abstract]
Schedule Of Segment Reporting


		For the Three Months Ended April 30, 2015
		Exploration				Corporate
		and		Oilfield		and				Consolidated
	(in thousands)	Production		Services		Other		Eliminations		Total
	Revenues:
	Oil, natural gas and natural gas liquids sales	$	47,778	$	—	$	—	$	—	$	47,778
	Oilfield services for third parties		—		71,090		—		-580		70,510
	Intersegment revenues		—		9,504		—		-9,504		—
	Total revenues		47,778		80,594		—		-10,084		118,288
	Expenses:
	Lease operating and production taxes		15,696		—		—		—		15,696
	Gathering, transportation and processing		6,348		—		—		—		6,348
	Depreciation and amortization		29,299		9,489		325		-1,307		37,806
	Impairment of oil and natural gas properties		192,000		—		—		—		192,000
	Accretion of asset retirement obligations		57		—		—		—		57
	Cost of oilfield services		—		70,586		1,238		-6,360		65,464
	General and administrative, net of amounts capitalized:
	Salaries and benefits		341		4,829		3,253		—		8,423
	Stock-based compensation		321		51		2,136		—		2,508
	Other general and administrative		407		1,797		1,724		—		3,928
	Total operating expenses		244,469		86,752		8,676		-7,667		332,230
	Income (loss) from operations		-196,691		-6,158		-8,676		-2,417		-213,942
	Other income (expense), net		-21,002		-875		2,686		-507		-19,698
	Income (loss) before income taxes	$	-217,693	$	-7,033	$	-5,990	$	-2,924	$	-233,640
	As of April 30, 2015:
	Net oil and natural gas properties	$	1,044,482	$	—	$	—	$	-77,705	$	966,777
	Oilfield services equipment - net	$	—	$	84,398	$	—	$	—	$	84,398
	Other property and equipment - net	$	9,116	$	22,508	$	16,635	$	—	$	48,259
	Total assets	$	1,200,737	$	169,519	$	125,697	$	-98,180	$	1,397,773
	Total liabilities	$	764,057	$	138,322	$	148,034	$	-19,930	$	1,030,483





		For the Three Months Ended April 30, 2014
		Exploration				Corporate
		and		Oilfield		and				Consolidated
	(in thousands)	Production		Services		Other		Eliminations		Total
	Revenues:
	Oil, natural gas and natural gas liquids sales	$	60,834	$	—	$	—	$	—	$	60,834
	Oilfield services for third parties		—		39,557		—		-609		38,948
	Intersegment revenues		—		21,875		—		-21,875		—
	Total revenues		60,834		61,432		—		-22,484		99,782
	Expenses:
	Lease operating and production taxes		11,074		—		—		—		11,074
	Gathering, transportation and processing		3,802		—		—		—		3,802
	Depreciation and amortization		20,153		3,590		176		-2,632		21,287
	Accretion of asset retirement obligations		25		—		—		—		25
	Cost of oilfield services		—		43,711		—		-16,001		27,710
	General and administrative, net of amounts capitalized:
	Salaries and benefits		1,241		2,738		2,282		—		6,261
	Stock-based compensation		395		90		1,523		—		2,008
	Other general and administrative		1,537		2,359		1,236		—		5,132
	Total operating expenses		38,227		52,488		5,217		-18,633		77,299
	Income (loss) from operations		22,607		8,944		-5,217		-3,851		22,483
	Other income (expense), net		-6,567		-507		9,498		-354		2,070
	Income (loss) before income taxes	$	16,040	$	8,437	$	4,281	$	-4,205	$	24,553

LongTerm_Debt_Tables

Long-Term Debt (Tables)	3 Months Ended
Long-Term Debt (Tables)	Apr. 30, 2015
Long-Term Debt [Abstract]
Schedule Of Debt

		31-Jan-15		30-Apr-15
	5% convertible note	$	135,877	$	137,576
	TUSA credit facility due October 2018		119,272		146,272
	RockPile credit facility due March 2019		104,887		99,016
	TUSA 6.75% notes due July 2022		429,500		429,500
	Other notes and mortgages payable		10,605		10,490
	Total debt		800,141		822,854
	Less current portion of debt:
	Other notes and mortgages payable		-503		-508
	Total long-term debt	$	799,638	$	822,346

Hedging_And_Commodity_Derivati1

Hedging And Commodity Derivative Financial Instruments (Tables)	3 Months Ended
	Apr. 30, 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 (in thousands):

			For the Three Months Ended April 30,
			2014			2015
	Realized commodity derivative gains (losses)		$	-818		$	19,468
	Unrealized commodity derivative gains (losses)			-4,638			-33,442
	Commodity derivative gains (losses), net		$	-5,456		$	-13,974


Summary Of Derivative Instruments	The Company’s commodity derivative contracts as of April 30, 2015 are summarized below:


			Contract				Quantity	Weighted Average		Weighted Average		Weighted Average
			Type		Basis (1)		(Bbl/d)	Put Strike		Call Strike		Price
	May 1, 2015 to January 31, 2016		Collar		NYMEX		3,826	$	86.52	$	98.72
	May 1, 2015 to January 31, 2016		Swap		NYMEX		1,170					$	60.22
	February 1, 2016 to January 31, 2017		Swap		NYMEX		2,746					$	60.23


		-1		“NYMEX” refers to West Texas Intermediate crude oil prices at Cushing, Oklahoma as quoted on the New York Mercantile Exchange.

Schedule Of Derivative Instruments In Statement Of Financial Position, Fair Value	The main headings represent the balance sheet captions for the contracts presented (in thousands).




			31-Jan-15			30-Apr-15
	Current Assets:
	Crude oil derivative contracts		$	54,775		$	24,796

	Total derivative asset		$	54,775		$	24,796


	Current Liabilities:
	Crude oil derivative contracts		$	—		$	292

	Long-Term Liabilities:
	Crude oil derivative contracts			—			3,171

	Total derivative liability		$	—		$	3,463

Oil_And_Natural_Gas_Properties1

Oil And Natural Gas Properties (Tables)	3 Months Ended
Oil And Natural Gas Properties (Tables)	Apr. 30, 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
	(in thousands, except per share data)	30-Apr-14
	Operating revenues	$	106,647
	Net income (loss)	$	15,919

	Earnings (loss) per common share
	Basic	$	0.19
	Diluted	$	0.16

	Weighted average common shares outstanding:
	Basic		85,952
	Diluted		103,314

Equity_Investment_And_Equity_I1

Equity Investment And Equity Investment Derivatives (Tables)	3 Months Ended
	Apr. 30, 2015
Equity Investment [Abstract]
Schedule Of Equity Investment In Caliber


		Expiration		Strike Price at		As of	As of
		Date		30-Apr-15		31-Jan-15	30-Apr-15
	Class A Units		—	$	—	7,000,000	7,000,000
	Series 1 Warrants		1-Oct-24	$	12.78	5,600,000	6,615,467
	Series 2 Warrants		1-Oct-24	$	22.09	2,400,000	2,835,200
	Series 3 Warrants		12-Sep-25	$	22.09	3,000,000	3,544,000
	Series 4 Warrants		12-Sep-25	$	28.09	2,000,000	2,362,667
	Series 6 Warrants		2-Feb-18	$	12.50	—	1,269,333


Summary of activities related to company's equity investment

	(in thousands)	For the Three Months Ended April 30, 2015
	Balance at January 31, 2015	$	64,411

	Capital contributions		—
	Distributions		—
	Equity investment share of net income before intra-company profit eliminations		425
	Change in fair value of warrants		—
	Gain on Caliber capital transactions		2,880

	Balance at April 30, 2015	$	67,716

	Fair value of warrants at April 30, 2015	$	504

ShareBased_Compensation_Tables

Share-Based Compensation (Tables)	3 Months Ended
Share-Based Compensation (Tables)	Apr. 30, 2015
Share-Based Compensation [Abstract]
Non-Cash Stock-Based Compensation Cost
		For the Three Months Ended April 30,
	(in thousands)	2014			2015
	Restricted stock units	$	1,771		$	2,079
	Stock options		486			698
	RockPile Series B Units		90			51
			2,347			2,828
	Less amounts capitalized to oil and natural gas properties		-339			-320
	Compensation expense	$	2,008		$	2,508


Restricted Stock Units Outstanding
				Weighted
				Average
		Number of		Award Date
		Shares		Fair Value
	Restricted stock units outstanding - January 31, 2015	2,914,045		$	7.92
	Units granted	1,568,093		$	5.00
	Units forfeited	-50,588		$	8.92
	Units vested	-221,472		$	7.34
	Restricted stock units outstanding - April 30, 2015	4,210,078		$	6.86


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	2,920,000		60,000		910,000	1,412,000	5,302,000
	Units redeemed	—		—		—	—	—
	Units granted	—		—		—	—	—
	Units outstanding - April 30, 2015	2,920,000		60,000		910,000	1,412,000	5,302,000
	Vested	2,920,000		30,000		188,000	—	3,138,000
	Unvested	—		30,000		722,000	1,412,000	2,164,000

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	3 Months Ended
Fair Value Measurements (Tables)	Apr. 30, 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:
	Equity investment derivative assets	$	—	$	—	$	504	$	504
	Commodity derivative assets	$	—	$	54,775	$	—	$	54,775

	Liabilities:
	RockPile earn-out liability	$	—	$	-1,825	$	—	$	-1,825



		As of April 30, 2015
	(in thousands)	Level 1		Level 2		Level 3		Total
	Assets:
	Equity investment derivative assets	$	—	$	—	$	504	$	504
	Commodity derivative assets	$	—	$	24,796	$	—	$	24,796

	Liabilities:
	Commodity derivative liabilities	$	—	$	-3,463	$	—	$	-3,463
	RockPile earn-out liability	$	—	$	-1,226	$	—	$	-1,226


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				30-Apr-15
		Carrying		Estimated		Carrying		Estimated
	(in thousands)	Value		Fair Value		Value		Fair Value
	5% convertible note	$	135,877	$	137,790	$	137,576	$	154,884
	Revolving credit facilities		224,159		224,159		245,288		245,288
	TUSA 6.75% notes		429,500		303,871		429,500		365,505
	Other notes and mortgages payable		10,605		10,605		10,490		10,490

Recovered_Sheet1

Supplemental Disclosures of Cash Flow Information (Tables)	3 Months Ended
Supplemental Disclosures of Cash Flow Information (Tables)	Apr. 30, 2015
Supplemental Disclosures of Cash Flow Information [Abstract]
Schedule of Supplemetal Cash Flow Disclosures
		For the Three Months Ended April 30,
	(in thousands)	2014		2015
	Cash paid during the period for:
	Interest expense	$	1,661	$	1,890
	Income taxes	$	—	$	—

	Non-cash investing activities:
	Additions to oil and natural gas properties through:
	Increase (decrease) in accounts payable and accrued liabilities	$	10,167	$	-7,932
	Capitalized stock based compensation	$	339	$	320
	Change in asset retirement obligations	$	197	$	242

Description_Of_Business_Detail

Description Of Business - (Details)	3 Months Ended
	Apr. 30, 2015
	item
Description Of Business [Abstract]
Number of major focus lines of business	3

Summary_Of_Significant_Account3

Summary Of Significant Accounting Policies - Consolidation- (Details)	Apr. 30, 2015
Minimum [Member]
Accounting Policies [Line Items]
Equity method ownership percentage	20.00%
Maximum [Member]
Accounting Policies [Line Items]
Equity method ownership percentage	50.00%

Summary_Of_Significant_Account4

Summary Of Significant Accounting Policies - Oilfield Services Equipment Schedule - (Details) (USD $)	3 Months Ended
	Apr. 30, 2015	Jan. 31, 2015
Property, Plant and Equipment [Line Items]
Impairment of oil and natural gas properties	$192,000,000
Total Depreciable Assets	176,125,000	168,858,000
Accumulated depreciation	-44,998,000	-35,189,000
Depreciable assets, net	131,127,000	133,669,000
Assets not placed in service	1,530,000	1,247,000
Total oilfield service equipment and other property and equipment, net	132,657,000	134,916,000
Period of pre-tax losses	3 years
Domestic net losses carried forward		136,900,000
Unrecognized tax benefits	0
Land [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	7,888,000	7,888,000
Building And Leasehold Improvements [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	34,160,000	33,625,000
Oilfield Service Equipment [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	121,653,000	116,354,000
Vehicles [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	5,521,000	4,811,000
Software, Computers And Office Equipment [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	6,050,000	5,327,000
Capital Leases [Member]
Property, Plant and Equipment [Line Items]
Total Depreciable Assets	$853,000	$853,000

Summary_Of_Significant_Account5

Summary Of Significant Accounting Policies - Earnings per Share- (Details) (USD $)	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Apr. 30, 2015	Apr. 30, 2014
Earnings Per Share [Abstract]
Net income	($180,199)	$14,542
Effect of 5% Convertible Note conversion		918
Net income (loss) attributable to common shareholders after effect of debt conversion	($180,199)	$15,460
Basic weighted average common shares outstanding	75,256,000	85,952,000
Effect of dilutive securities		17,362,426
Diluted weighted average common shares outstanding	75,256,000	103,314,000
Basic net income (loss) per share	($2.39)	$0.17
Diluted net income (loss) per share	($2.39)	$0.15
Anitdilutive securities excluded from calculation of diluted net income	10,910,078	6,000,000

Segment_Reporting_Selected_Fin

Segment Reporting - Selected Financial Information - (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Apr. 30, 2015	Apr. 30, 2014	Jan. 31, 2015
REVENUES
Oil and natural gas liquids sales	$47,778	$60,834
Oilfield services for third parties	70,510	38,948
Total revenues	118,288	99,782
EXPENSES:
Lease operating and production taxes	15,696	11,074
Gathering, transportation and processing	6,348	3,802
Depreciation and amortization	37,806	21,287
Impairment of oil and natural gas properties	192,000
Accretion of asset retirement obligations	57	25
Cost of oilfield services	65,464	27,710
Salaries and benefits	8,423	6,261
Stock-based compensation	2,508	2,008
Other general and administrative	3,928	5,132
Total operating expenses	332,230	77,299
INCOME FROM OPERATIONS	-213,942	22,483
Other income (expense), net	-19,698	2,070
NET INCOME (LOSS) BEFORE INCOME TAXES	-233,640	24,553
Net oil and natural gas properties	966,777		1,126,090
Oilfield services equipment, net	84,398		87,549
Other property and equipment, net	48,259		47,367
Total assets	1,397,773		1,654,870
Total liabilities	1,030,483		1,109,852
Eliminations And Other [Member]
REVENUES
Oilfield services for third parties	-580	-609
Total revenues	-10,084	-22,484
EXPENSES:
Depreciation and amortization	-1,307	-2,632
Cost of oilfield services	-6,360	-16,001
Total operating expenses	-7,667	-18,633
INCOME FROM OPERATIONS	-2,417	-3,851
Other income (expense), net	-507	-354
NET INCOME (LOSS) BEFORE INCOME TAXES	-2,924	-4,205
Net oil and natural gas properties	-77,705
Total assets	-98,180
Total liabilities	-19,930
Intersegment Revenues [Member] \| Eliminations And Other [Member]
REVENUES
Other	-9,504	-21,875
Exploration and Production [Member]
REVENUES
Oil and natural gas liquids sales	47,778	60,834
Total revenues	47,778	60,834
EXPENSES:
Lease operating and production taxes	15,696	11,074
Gathering, transportation and processing	6,348	3,802
Depreciation and amortization	29,299	20,153
Impairment of oil and natural gas properties	192,000
Accretion of asset retirement obligations	57	25
Salaries and benefits	341	1,241
Stock-based compensation	321	395
Other general and administrative	407	1,537
Total operating expenses	244,469	38,227
INCOME FROM OPERATIONS	-196,691	22,607
Other income (expense), net	-21,002	-6,567
NET INCOME (LOSS) BEFORE INCOME TAXES	-217,693	16,040
Net oil and natural gas properties	1,044,482
Other property and equipment, net	9,116
Total assets	1,200,737
Total liabilities	764,057
Oilfield Services [Member]
REVENUES
Oilfield services for third parties	71,090	39,557
Total revenues	80,594	61,432
EXPENSES:
Depreciation and amortization	9,489	3,590
Cost of oilfield services	70,586	43,711
Salaries and benefits	4,829	2,738
Stock-based compensation	51	90
Other general and administrative	1,797	2,359
Total operating expenses	86,752	52,488
INCOME FROM OPERATIONS	-6,158	8,944
Other income (expense), net	-875	-507
NET INCOME (LOSS) BEFORE INCOME TAXES	-7,033	8,437
Oilfield services equipment, net	84,398
Other property and equipment, net	22,508
Total assets	169,519
Total liabilities	138,322
Oilfield Services [Member] \| Intersegment Revenues [Member]
REVENUES
Other	9,504	21,875
Corporate And Other [Member]
EXPENSES:
Depreciation and amortization	325	176
Cost of oilfield services	1,238
Salaries and benefits	3,253	2,282
Stock-based compensation	2,136	1,523
Other general and administrative	1,724	1,236
Total operating expenses	8,676	5,217
INCOME FROM OPERATIONS	-8,676	-5,217
Other income (expense), net	2,686	9,498
NET INCOME (LOSS) BEFORE INCOME TAXES	-5,990	4,281
Other property and equipment, net	16,635
Total assets	125,697
Total liabilities	$148,034

Segment_Reporting_Details

Segment Reporting - (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Apr. 30, 2015	Apr. 30, 2014
	segment	Apr. 30, 2014
Number of reportable segments	2
Depreciation, Depletion and Amortization	$37,806	$21,287
TUSA [Member]
Depreciation, Depletion and Amortization	$500	$1,400

LongTerm_Debt_Schedule_of_long

Long-Term Debt - Schedule of long term debt- (Details) (USD $)	Apr. 30, 2015	Jan. 31, 2015	Jul. 18, 2014
In Thousands, unless otherwise specified	Apr. 30, 2015	Jan. 31, 2015	Jul. 18, 2014
Debt Instrument [Line Items]
5% Convertible Note	137,576	135,877
Credit facility	245,288	224,159
Other notes and mortgages payable	10,490	10,605
TUSA 6.75% notes	429,500	429,500
Total debt	822,854	800,141
Other notes and mortgages payable	-508	-503
Total long-term debt	822,346	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	146,272	119,272
Rockpile [Member]
Debt Instrument [Line Items]
Credit facility	99,016	104,887

LongTerm_Debt_Convertible_note

Long-Term Debt - Convertible note- (Details) (USD $)	Apr. 30, 2015	Jan. 31, 2015
Debt Instrument [Line Items]
Accrued interest	$9,132,000	$2,250,000
Convertible Notes [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate	5.00%	5.00%
Debt instrument, face amount	120,000,000
Convertible note, conversion price	$8
Accrued interest	$17,600,000

Longterm_Debt_TUSA_credit_faci

Long-term Debt - TUSA credit facility - (Details) (USD $)	0 Months Ended	3 Months Ended
In Millions, unless otherwise specified	Nov. 25, 2014	Apr. 30, 2015	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	0.38%
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%

Longterm_Debt_Rockpile_credit_

Long-term Debt - Rockpile credit facility - (Details) (Rockpile [Member], USD $)	3 Months Ended
In Millions, unless otherwise specified	Apr. 30, 2015	Mar. 25, 2014	Nov. 13, 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	0.13%
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	0.38%
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%

Longterm_Debt_TUSA_675_Note_De

Long-term Debt - TUSA 6.75% Note - (Details) (TUSA 6.75% Notes [Member], USD $)	3 Months Ended
In Millions, unless otherwise specified	Apr. 30, 2015	Jan. 31, 2015	Jul. 18, 2014
Debt Instrument [Line Items]
Debt instrument, face amount			$450
Debt instrument, interest rate	6.75%	6.75%	6.75%
Offering costs	10.5
Face value of notes repurchased	20.5
Repurchased amount	13.9
Gain (loss) on extinguishment of debt	$6.60
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%
Redemption Due to Change in Control Events [Member]
Debt Instrument [Line Items]
Redemption price, percentage	101.00%

Hedging_And_Commodity_Derivati2

Hedging And Commodity Derivative Financial Instruments - (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Apr. 30, 2015	Apr. 30, 2014
	item	Apr. 30, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Number of counterparties	4
Realized commodity derivative gains (losses)	$19,468	($818)
Unrealized commodity derivative gains (losses)	-33,442	-4,638
Crude Oil Derivative Contract [Member] \| Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized commodity derivative gains (losses)	19,468	-818
Unrealized commodity derivative gains (losses)	-33,442	-4,638
Commodity derivatives gains (losses)	($13,974)	($5,456)

Hedging_And_Commodity_Derivati3

Hedging And Commodity Derivative Financial Instruments - Notional - (Details)	3 Months Ended
	Apr. 30, 2015
Fiscal 2016 Collar [Member]
Derivative [Line Items]
End date	May 1, 2015 to January 31, 2016
Contract type	Collar
Basis	NYMEX
Quantity, (bbls)	3,826
Put strike price	86.52
Call strike price	98.72
Notional Disclosures [Abstract]
Notional amount per day (in Bbl)	3,826
Fiscal 2016 Swap [Member]
Derivative [Line Items]
End date	May 1, 2015 to January 31, 2016
Contract type	Swap
Basis	NYMEX
Quantity, (bbls)	1,170
Weighted average price	60.22
Notional Disclosures [Abstract]
Notional amount per day (in Bbl)	1,170
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
Weighted average price	60.23
Notional Disclosures [Abstract]
Notional amount per day (in Bbl)	2,746

Hedging_And_Commodity_Derivati4

Hedging And Commodity Derivative Financial Instruments - Fair values of commodity derivatives - (Details) (USD $)	Apr. 30, 2015	Jan. 31, 2015
In Thousands, unless otherwise specified	Apr. 30, 2015	Jan. 31, 2015
Derivatives, Fair Value [Line Items]
Derivative Assets	$24,796	$54,775
Derivative Liability	3,463
Crude Oil Derivative Contract [Member] \| Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets	24,796	54,775
Crude Oil Derivative Contract [Member] \| Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability	292
Crude Oil Derivative Contract [Member] \| Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability	$3,171

Oil_And_Natural_Gas_Properties2

Oil And Natural Gas Properties - (Details) (Marathon Oil Company [Member], USD $)	1 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014
	acre
Marathon Oil Company [Member]
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Number of acres purchased	41,100
Total consideration for acquisition	$90.40
Net downward adjustment included in the purchase price consideration	$9.60

Oil_And_Natural_Gas_Properties3

Oil And Natural Gas Properties - Proforma Financial Information - (Details) (USD $)	3 Months Ended
Share data in Thousands, except Per Share data, unless otherwise specified	Apr. 30, 2014
Acquisitions [Abstract]
Operating revenue	$106,647,000
Net income (loss)	15,919,000
Earnings (loss) per common share, basic	$0.19
Earnings (loss) per common share, diluted	$0.16
Weighted average common shares outstanding, basic	85,952
Weighted average common shares outstanding, diluted	103,314
Pro forma depreciation, amortization and accretion expense	$2,000,000

Equity_Investment_And_Equity_I2

Equity Investment And Equity Investment Derivatives - Equity Investment - (Details) (USD $)	3 Months Ended	12 Months Ended	0 Months Ended
	Apr. 30, 2015	Jan. 31, 2015	Feb. 02, 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%
Gain on Caliber capital transactions	2,900,000
Equity method investments, warrants received	3,626,667
Unrealized gain (loss)	$200,000
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
Warrants, exercise price (in dollars per share)	$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
Warrants, exercise price (in dollars per share)	$12.50

Equity_Investment_And_Equity_I3

Equity Investment And Equity Investment Derivatives - Equity investment holdings summary - (Details) (Caliber Midstream Partners, L.P. [Member], USD $)	3 Months Ended	12 Months Ended
	Apr. 30, 2015	Jan. 31, 2015
Class A Units [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investments, units held	7,000,000	7,000,000
Series 1 Warrants [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investments, warrant excercise price	12.78
Equity method investments, units held	6,615,467	5,600,000
Series 2 Warrants [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investments, warrant excercise price	22.09
Equity method investments, units held	2,835,200	2,400,000
Series 3 Warrants [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investments, warrant excercise price	22.09
Equity method investments, units held	3,544,000	3,000,000
Series 4 Warrants [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investments, warrant excercise price	28.09
Equity method investments, units held	2,362,667	2,000,000
Series 6 Warrants [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investments, warrant excercise price	12.5
Equity method investments, units held	1,269,333

Equity_Investment_And_Equity_I4

Equity Investment And Equity Investment Derivatives - Equity investment activity summary (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Apr. 30, 2015
Schedule of Equity Method Investments [Line Items]
Equity investment, Beginning balance	$64,411
Gain on Caliber capital transactions	2,880
Equity investment, Ending balance	67,716
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	425
Gain on Caliber capital transactions	2,880
Equity investment, Ending balance	67,716
Fair value of warrants	$504

Capital_Stock_Details

Capital Stock (Details) (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Apr. 30, 2015	Jan. 31, 2015
Capital Stock [Line Items]
Common stock issued or reserved	106,500,000
Common stock, shares issued	75,327,056	75,174,442
Common stock, shares outstanding	75,327,056	75,174,442
Stock Repurchase authorized (Tranche 1)	$25
Common stock repurchased (in shares)	0
Authorized shares remaining repurchase	5,160,820
2011 Omnibus Incentive Plan
Capital Stock [Line Items]
Shares reserved for issuance	2,000,000
2014 Plan
Capital Stock [Line Items]
Shares reserved for issuance	2,900,000
Shares reserved for future grants	3,100,000
CEO Stand-Alone Stock Option Agreement
Capital Stock [Line Items]
Shares reserved for issuance	6,000,000
Convertible Notes Payable [Member]
Capital Stock [Line Items]
Shares reserved for issuance	17,200,000

ShareBased_Compensation_Detail

Share-Based Compensation (Details) (USD $)	3 Months Ended
In Thousands, except Share data in Millions, unless otherwise specified	Apr. 30, 2015	Apr. 30, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense before capitalized amount	$2,828	$2,347
Less amounts capitalized to oil and natural gas properties	-320	-339
Stock-based compensation, net	2,508	2,008
Series B Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum shares reserved under Plan	6
2014 Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum shares reserved under Plan	6
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense before capitalized amount	2,079	1,771
Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense before capitalized amount	698	486
RockPile Stock Based Compensation Related to Series [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense before capitalized amount	$51	$90

ShareBased_Compensation_Restri

Share-Based Compensation - Restricted stock units - (Details) (Restricted Stock Units (RSUs) [Member], USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Apr. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation	$25.10
Unrecognized compensation, recognition period	3 years 7 months 6 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	1,568,093
Units granted, Weighted Average Award Date Fair Value	$5
Units forfeited, Number of Shares	-50,588
Units forfeited, Weighted Average Award Date Fair Value	$8.92
Units that vested, Number of Shares	-221,472
Units that vested, Weighted Average Award Date Fair Value	$7.34
Outstanding, Unvested Ending Balance	4,210,078
Outstanding, Weighted-Average Grant Date Fair Value, Ending Balance	$6.86
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

ShareBased_Compensation_Stock_

Share-Based Compensation - Stock options - (Details) (Employee Stock Option [Member], USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Apr. 30, 2015
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Outstanding options	6,700,000
Number of shares exercisable	600,000
Weighted average exercise price per share	$11.54
Weighted average remaining contractual life (years)	8 years 1 month 6 days
Weighted average exercise price per share (exercisable)	$11.25
Weighted average remaining contractual life (years) (exercisable)	8 years 2 months 5 days
Unrecognized compensation cost related to awards	$17.90
Unrecognized compensation, recognition period	3 years 1 month 6 days
$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	8 years 2 months 5 days
Outstanding options	750,000
Number of shares exercisable	75,000
$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	8 years 2 months 5 days
Outstanding options	750,000
Number of shares exercisable	75,000
$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	8 years 2 months 5 days
Outstanding options	1,500,000
Number of shares exercisable	150,000
$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	8 years 2 months 5 days
Outstanding options	1,500,000
Number of shares exercisable	150,000
$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	8 years 2 months 5 days
Outstanding options	1,500,000
Number of shares exercisable	150,000
$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 4 months 13 days
Outstanding options	233,333
$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 4 months 13 days
Outstanding options	233,333
$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 4 months 13 days
Outstanding options	233,334

ShareBased_Compensation_Rockpi

Share-Based Compensation - Rockpile share based compensation - (Details) (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Apr. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding, Number of Units, Beginning Balance	5,302,000
Outstanding, Number of Units, Ending Balance	5,302,000
Grants, Number of Vested Units	3,138,000
Grants, Number of Unvested Units	2,164,000
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
Unrecognized compensation, recognition period	5 years
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
Outstanding, Number of Units, Ending Balance	910,000
Grants, Number of Vested Units	188,000
Grants, Number of Unvested Units	722,000
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
Outstanding, Number of Units, Ending Balance	1,412,000
Grants, Number of Unvested Units	1,412,000
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	7 months
Maximum [Member] \| Series B Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based awards vesting period	52 months

Fair_Value_Measurements_Assets

Fair Value Measurements - Assets and liabilities table - (Details) (USD $)	3 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Apr. 30, 2015	Jan. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	$24,796	$54,775
Commodity derivative Liabilities	-3,463
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative Liabilities	-3,463
Rockpile earn-out liability	-1,226	-1,825
Fair Value, Measurements, Recurring [Member] \| Equity Investment Derivative [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	504	504
Fair Value, Measurements, Recurring [Member] \| Crude Oil Derivative Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	24,796	54,775
Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative Liabilities	-3,463
Rockpile earn-out liability	-1,226	-1,825
Fair Value, Measurements, Recurring [Member] \| 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	24,796	54,775
Fair Value, Measurements, Recurring [Member] \| 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	$504	$504

Fair_Value_Measurements_Debt_i

Fair Value Measurements - Debt instruments carrying value - (Details) (USD $)	Apr. 30, 2015	Jan. 31, 2015	Jul. 18, 2014
In Thousands, unless otherwise specified	Apr. 30, 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	137,576	135,877
Convertible note	154,884	137,790
Long-term portion of credit facilities	245,288	224,159
Revolving credit facilities, carrying value	245,288	224,159
Revolving credit facilities, fair value	245,288	224,159
TUSA 6.75% notes, carrying value	429,500	429,500
TUSA 6.75% notes, fair value	365,505	303,871
Other notes and mortgages payable, carrying value	10,490	10,605
Other notes and mortgages payable, fair value	10,490	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) (USD $)	3 Months Ended
	Apr. 30, 2015
	item
Related Party Transaction [Line Items]
Number of salt water disposal wells sold	1
Proceeds from sale of salt water disposal wells	$6,000,000
Caliber North Dakota LLC [Member]
Related Party Transaction [Line Items]
Term of midstream agreements with Caliber	15 years
Minmum commitment over term of agreements	405,000,000
Remaining commitment	$347,000,000

Supplemental_Disclosures_Of_Ca1

Supplemental Disclosures Of Cash Flow Information (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Apr. 30, 2015	Apr. 30, 2014
Supplemental Disclosures of Cash Flow Information [Abstract]
Interest expense	$1,890	$1,661
Increased accounts payable and accrued liabilities	-7,932	10,167
Capitalized stock-based compensation	320	339
Change in asset retirement obligations	$242	$197

Uncategorized_Items

Uncategorized Items	1/31/13
Uncategorized Items	USD ($)
[us-gaap_Cash]	67,871,000