Triangle Petroleum (TPLMQ) 10-Q 8 Dec 14 2015 Q3 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	9 Months Ended
	Oct. 31, 2014	Dec. 04, 2013
Document And Entity Information [Abstract]	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	31-Oct-14	'
Document Fiscal Period Focus	'Q3	'
Document Fiscal Year Focus	'2015	'
Entity Registrant Name	'Triangle Petroleum Corp	'
Entity Central Index Key	'0001281922	'
Trading Symbol	'tplm	'
Current Fiscal Year End Date	'--01-31	'
Entity Filer Category	'Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	76,611,272

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Oct. 31, 2014		Jan. 31, 2014
In Thousands, unless otherwise specified
CURRENT ASSETS	'		'
Cash and equivalents	$53,236		$81,750
Accounts receivable:	'		'
Oil, natural gas and natural gas liquids sales	31,482		20,450
Trade	166,668		86,074
Commodity derivative assets	18,918		955
Deferred tax asset	321		321
Inventory, deposits and prepaid expenses	7,839		6,248
Total current assets	278,464		195,798
Oil and natural gas properties, at cost, full cost method of accounting:	'		'
Unproved properties and properties under development, not being amortized	150,652		121,393
Proved properties	1,054,382		629,051
Total oil and natural gas properties	1,205,034		750,444
Less: accumulated amortization	-137,673		-67,657
Net oil and natural gas properties	1,067,361		682,787
Oilfield services equipment, net	80,114		46,586
Other property and equipment, net	32,579		24,507
Equity investment	74,124		68,536
Goodwill	1,680		1,680
Intangible assets, net	3,475		3,862
Commodity derivative assets	449		1,192
Other long-term assets	12,125		2,636
Total assets	1,550,371	[1]	1,027,584
CURRENT LIABILITIES	'		'
Accounts payable	101,752		60,016
Accrued liabilities:	'		'
Exploration and development	87,337		34,131
Other	91,911		53,037
Current portion of long-term debt	416		8,851
Asset retirement obligations	3,457		3,333
Total current liabilities	284,873		159,368
LONG-TERM LIABILITIES	'		'
5% convertible note	134,200		129,290
Borrowings on credit facilities	84,616		196,065
Other notes and mortgages payable	9,759		9,002
TUSA 6.75%	450,000		'
Asset retirement obligations	2,878		1,296
Deferred tax liability	47,085		8,262
Other	1,220		1,139
Total liabilities	1,014,631		504,422
COMMITMENTS AND CONTINGENCIES	'		'
STOCKHOLDERS' EQUITY	'		'
Common stock, $0.00001 par value, 140,000,000 shares authorized; 81,440,082 and 85,735,827 shares issued and outstanding at October 31, 2014 and January 31, 2014, respectively	1		1
Additional paid-in capital	535,739		571,701
Retained earnings (accumulated deficit)	'		-48,540
Total stockholders' equity	535,740		523,162
Total liabilities and stockholders' equity	$1,550,371		$1,027,584
[1]	Our Corporate and Other total assets consist primarily of cash and cash equivalents of $14.1 million and our investment in Caliber of $74.1 million, in addition to the Company’s investment in subsidiaries the results of which are subsequently eliminated.

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Oct. 31, 2014	Jan. 31, 2014
Common stock, par value	$0.00	$0.00
Common stock, shares authorized	140,000,000	140,000,000
Common stock, shares issued	81,440,082	85,735,827
Common stock, shares outstanding	81,440,082	85,735,827
TUSA Senior Notes [Member]	'	'
Debt instrument, interest rate	6.75%	'
Convertible Note [Member]	'	'
Debt instrument, interest rate	5.00%	5.00%

Condensed_Consolidated_Stateme

Condensed Consolidated Statements Of Operations (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Oct. 31, 2014	Oct. 31, 2013	Oct. 31, 2014	Oct. 31, 2013
REVENUES:	'	'	'	'
Oil, natural gas and natural gas liquids sales	$80,139	$55,477	$221,479	$111,176
Oilfield services	94,057	33,072	194,488	62,061
Total revenues	174,196	88,549	415,967	173,237
EXPENSES:	'	'	'	'
Production taxes	8,637	6,161	23,662	12,524
Lease operating expenses	7,454	4,443	18,741	9,489
Gathering, transportation and processing	4,380	1,443	11,915	1,549
Depreciation and amortization	32,581	18,609	80,465	37,000
Accretion of asset retirement obligations	149	983	324	1,000
Oilfield services	70,857	29,164	142,121	53,042
General and administrative, net of amounts capitalized:	'	'	'	'
Stock-based compensation	1,827	2,457	5,642	5,489
Salaries and benefits	7,725	4,740	20,519	11,998
Other general and administrative	7,241	3,389	18,124	6,684
Total operating expenses	140,851	71,389	321,513	138,775
INCOME FROM OPERATIONS	33,345	17,160	94,454	34,462
OTHER INCOME (EXPENSE):	'	'	'	'
Gain on equity investment derivatives	742	35,832	3,662	35,832
Gain (loss) from commodity derivatives	19,822	2,123	13,445	-1,064
Interest expense	-9,463	-1,993	-17,712	-5,434
Income from equity investment	393	'	457	'
Interest income	39	53	146	133
Other income (loss)	-180	15	-310	1,272
Total other income (expense)	11,353	36,030	-312	30,739
NET INCOME BEFORE INCOME TAXES	44,698	53,190	94,142	65,201
Income tax provision	-19,300	-5,969	-39,650	-5,969
NET INCOME	$25,398	$47,221	$54,492	$59,232
Net income per common share outstanding:	'	'	'	'
Basic	$0.30	$0.60	$0.64	$0.94
Diluted	$0.26	$0.50	$0.55	$0.78
Weighted average common shares outstanding:	'	'	'	'
Basic	85,242	79,059	85,769	62,817
Diluted	102,954	96,042	103,421	78,865

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements Of Cash Flows (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Oct. 31, 2014	Oct. 31, 2013
CASH FLOWS FROM OPERATING ACTIVITIES:	'	'
Net income	$54,492	$59,232
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation and amortization	80,465	37,000
Stock-based compensation	5,642	5,489
Interest expense not paid in cash	12,040	3,936
Accretion of asset retirement obligations	324	1,000
(Gain) loss on commodity derivatives	-13,445	1,064
Gain on equity investment derivatives	-3,662	-35,832
Settlements of commodity derivative instruments	-3,775	-779
Income from equity investment	-457	'
Unrealized income on securities held for investment	'	-1,040
Deferred income taxes	38,823	5,969
Accounts receivable:	'	'
Oil and natural gas sales	-11,032	-16,823
Trade	-80,594	-42,123
Related party	'	-2,031
Inventory, deposits and prepaid expenses	-157	-1,775
Accounts payable and accrued liabilities	21,724	2,936
Asset retirement expenditures	-137	-484
Other	2,172	'
Cash provided by operating activities	102,423	15,739
CASH FLOWS FROM INVESTING ACTIVITIES:	'	'
Oil and natural gas property expenditures and acquisitions	-351,156	-294,283
Purchases of oilfield services equipment	-41,263	-26,201
Purchases of other property and equipment	-12,079	-5,285
Equity investment in Caliber Midstream Partners, L.P.	'	-9,000
Sale of marketable securities	'	6,105
Sale of oil and natural gas properties	1,500	'
Other	188	'
Cash used in investing activities	-402,810	-328,664
CASH FLOWS FROM FINANCING ACTIVITIES:	'	'
Proceeds from issuance of common stock	'	245,333
Stock offering costs	'	-7,059
Proceeds from credit facilities	313,616	170,320
Repayments of credit facilities	-433,515	-30,700
Proceeds from notes payable	450,000	5,876
Repayments of other notes and mortgages payable	-300	'
Debt issuance costs	-12,714	-2,406
Cash paid to settle tax on vested restricted stock units	-2,666	-1,510
Issuance of common stock on exercise of options	'	117
Common stock repurchased and retired	-42,548	'
Cash provided by financing activities	271,873	379,971
NET INCREASE (DECREASE) IN CASH AND EQUIVALENTS	-28,514	67,046
CASH AND EQUIVALENTS, BEGINNING OF PERIOD	81,750	33,117
CASH AND EQUIVALENTS, END OF PERIOD	$53,236	$100,163

Condensed_Consolidated_Stateme2

Condensed Consolidated Statement Of Stockholders' Equity (USD $)	Common Stock [Member]	Additional Paid-In Capital [Member]	Retained Earnings (Accumulated Deficit) [Member]	Total
In Thousands, except Share data
Balance at Jan. 31, 2014	$1	$571,701	($48,540)	$523,162
Balance, shares at Jan. 31, 2014	85,735,827	'	'	85,735,827
Vesting of restricted stock units (net of shares surrendered for taxes)	'	-2,666	'	-2,666
Vesting of restricted stock units (net of shares surrendered for taxes), shares	635,999	'	'	'
Redeemed RockPile B-Units	'	-1,041	'	-1,041
Shares repurchased and retired	'	-38,790	-5,952	-44,742
Shares repurchased and retired, shares	-4,931,744	'	'	'
Stock-based compensation	'	6,535	'	6,535
Net income for the period	'	'	54,492	54,492
Balance at Oct. 31, 2014	$1	$535,739	'	$535,740
Balance, shares at Oct. 31, 2014	81,440,082	'	'	81,440,082

Description_Of_Business

Description Of Business	9 Months Ended
	Oct. 31, 2014
Description Of Business [Abstract]	'
Description Of Business	'
	1.  DESCRIPTION OF BUSINESS
	Triangle Petroleum Corporation (‘‘we,’’ ‘‘us,’’ ‘‘our,’’ the ‘‘Company,’’ or ‘‘Triangle’’) is a growth-oriented, 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 in McKenzie and Williams counties, North Dakota, and eastern Roosevelt and Sheridan counties, Montana (collectively, our “Core Acreage”).  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 primarily 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 services to oil and natural gas exploration and production companies in the Williston Basin.

Basis_Of_Presentation

Basis Of Presentation	9 Months Ended
	Oct. 31, 2014
Basis Of Presentation [Abstract]	'
Basis Of Presentation	'
	2.  BASIS OF PRESENTATION
	These unaudited condensed consolidated financial statements as of October 31, 2014, have been prepared 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 (1) adopt accounting policies within accounting rules set by the Financial Accounting Standards Board (“FASB”) and by the Securities and Exchange Commission (“SEC”), and (2) 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 condensed consolidated financial statements be read in conjunction with our audited financial statements and notes included in our Annual Report on Form 10-K for the fiscal year ended January 31, 2014, as filed with the SEC (the “Fiscal 2014 Form 10-K”).
	In the opinion of management, the interim data includes all adjustments, consisting only of normal recurring adjustments, necessary for a fair presentation of the results for the interim period.  The results of operations for the three and nine months ended
	October 31, 2014, are not necessarily indicative of the operating results for the entire fiscal year ending January 31, 2015.
	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
	The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period.  Management believes the major estimates and assumptions impacting our condensed consolidated financial statements are the following:
		·	estimates of proved reserves of oil and natural gas, which affect the calculations of amortization and consideration of any possible impairment of capitalized costs of proved oil and natural gas properties;
		·	estimates of the fair value of unproved oil and natural gas properties we own and the consideration of any possible impairment;
		·	assumptions impacting our estimates as to the future realization of deferred income tax assets and the amount of our deferred tax liabilities;
		·	consideration of any impairment of our other long-term assets;
		·	depreciation of property and equipment; and
		·	valuation of derivative instruments.
	Actual results may differ from estimates and assumptions of future events.  Future production may vary materially from estimated oil and natural gas proved reserves.  Actual future prices may vary significantly from price assumptions used for determining proved reserves and for financial reporting.
	Principles of Consolidation
	The accounts of Triangle and its wholly-owned subsidiaries are presented in the accompanying condensed consolidated financial statements.  All 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 20.0% and 50.0% and exercises significant influence.    Triangle Caliber Holdings, LLC, a wholly-owned subsidiary of Triangle, is a joint venture partner in Caliber.  The Company’s investment in Caliber is accounted for utilizing the equity method of accounting.
	Reclassifications
	Certain amounts in the condensed consolidated balance sheet as of January 31, 2014, and in our condensed consolidated statement of operations for the three and nine months ended October 31, 2013, have been reclassified to conform to the financial statement presentation for the period ended October 31, 2014.  Such reclassifications had no impact on consolidated total assets, stockholders’ equity or net income previously reported.

Summary_Of_Significant_Account

Summary Of Significant Accounting Policies	9 Months Ended
	Oct. 31, 2014
Summary Of Significant Accounting Policies [Abstract]	'
Summary Of Significant Accounting Policies	'
	3.  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	There have been no material changes to the Company’s significant accounting policies and estimates from those disclosed in Note 3 - Summary of Significant Accounting Policies in our audited financial statements included in our Fiscal 2014 Form 10-K.
	New Pronouncements Issued But Not Yet Adopted
	In April 2014, the FASB issued Accounting Standards Update (“ASU”) No. 2014-08, Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity.  ASU 2014-08 modifies the criteria for disposals to qualify as discontinued operations and expands related disclosures.  The guidance is effective for annual and interim reporting periods beginning after December 15, 2014.  Adoption of this amendment will not have a material effect on our financial position or results of operations.
	In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers, issued as a new Topic, Accounting Standards Codification Topic 606.  The new revenue recognition standard provides a five-step analysis of transactions to determine when and how revenue is recognized.  The core principle of the guidance is that a company should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.  This ASU is effective for the Company beginning in fiscal year 2017 and can be adopted by the Company either retrospectively or as a cumulative-effect adjustment as of the date of adoption.  We are currently evaluating the effect that adopting this new accounting guidance will have on our consolidated results of operations, cash flows and financial position.
	In August 2014, the FASB issued ASU No. 2014-15, which requires management of public and private companies to evaluate whether there are conditions and events that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the financial statements are issued (or available to be issued when applicable) and, if so, to disclose that fact.  Management will be required to make this evaluation for both annual and interim reporting periods, if applicable.  ASU No. 2014-15 is effective for annual periods ending after December 15, 2016 and interim periods within annual periods beginning after December 15, 2016.  The Company does not expect the adoption of this amendment to have a material impact on its consolidated financial statements.
	Accounting standard-setting organizations frequently issue new or revised accounting rules.  We regularly review new pronouncements to determine their impact, if any, on our condensed consolidated financial statements.  Other than the standards discussed above, there are no significant accounting standards applicable to Triangle which have not been adopted.

Segment_Reporting

Segment Reporting	9 Months Ended
	Oct. 31, 2014
Segment Reporting [Abstract]	'
Segment Reporting	'
	4.  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 basins of the United States.  The Exploration and Production operating segment, consisting of TUSA and several insignificant oil and gas subsidiaries, is responsible for finding and producing oil and natural gas.  The Oilfield Services segment, consisting of RockPile and several insignificant oilfield service subsidiaries, is responsible for a variety of oilfield and complementary services for both Triangle-operated wells and wells operated by third-parties.  Corporate and Other includes our corporate office and several subsidiaries that management does not consider to be part of the Exploration and Production or Oilfield Services segments.  Also included in Corporate and Other are our results from our investment in Caliber, including any changes in the fair value of our equity investment derivatives.
	Management evaluates the performance of our segments based upon net income (loss) before income taxes.  The following tables present selected financial information for our operating segments for the three months ended October 31, 2014 and 2013:
			For the Three Months Ended October 31, 2014
	(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
	Revenues:
	Oil, natural gas and natural gas liquids sales		$	80,139	$	-	$	-	$	-	$	80,139
	Oilfield services for third parties			-		96,810		-		-2,753		94,057
	Intersegment revenues			-		46,941		-		-46,941		-
	Total revenues			80,139		143,751		-		-49,694		174,196
	Expenses:
	Production taxes and other lease operating			16,091		-		-		-		16,091
	Gathering, transportation and processing			4,380		-		-		-		4,380
	Depreciation and amortization			27,998		6,249		125		-1,791		32,581
	Accretion of asset retirement obligations			149		-		-		-		149
	Cost of oilfield services			-		102,762		-		-31,905		70,857
	General and administrative, net of amounts capitalized:
	Stock-based compensation			93		146		1,588		-		1,827
	Other general and administrative			4,230		7,310		3,426		-		14,966
	Total operating expenses			52,941		116,467		5,139		-33,696		140,851
	Income (loss) from operations			27,198		27,284		-5,139		-15,998		33,345
	Other income (expense), net			12,263		-695		443		-658		11,353
	Net income (loss) before income taxes		$	39,461	$	26,589	$	-4,696	$	-16,656	$	44,698
			For the Three Months Ended October 31, 2013
	(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
	Revenues:
	Oil, natural gas and natural gas liquids sales		$	55,477	$	-	$	-	$	-	$	55,477
	Oilfield services for third parties			-		33,498		-		-426		33,072
	Intersegment revenues			-		32,681		-		-32,681		-
	Total revenues			55,477		66,179		-		-33,107		88,549
	Expenses:
	Production taxes and other lease operating			10,604		-		-		-		10,604
	Gathering, transportation and processing			1,443		-		-		-		1,443
	Depreciation and amortization			16,829		2,700		100		-1,020		18,609
	Accretion of asset retirement obligations			983		-		-		-		983
	Cost of oilfield services			-		49,839		-		-20,675		29,164
	General and administrative, net of amounts capitalized:
	Stock-based compensation			328		148		1,981		-		2,457
	Other general and administrative			2,594		3,150		2,385		-		8,129
	Total operating expenses			32,781		55,837		4,466		-21,695		71,389
	Income (loss) from operations			22,696		10,342		-4,466		-11,412		17,160
	Other income (expense), net			1,553		-242		35,103		-384		36,030
	Net income (loss) before income taxes		$	24,249	$	10,100	$	30,637	$	-11,796	$	53,190
	The following tables present selected financial information for our operating segments for the nine months ended October 31, 2014 and 2013:
			For the Nine Months Ended October 31, 2014
	(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
	Revenues:
	Oil, natural gas and natural gas liquids sales		$	221,479	$	-	$	-	$	-	$	221,479
	Oilfield services for third parties			-		200,460		-		-5,972		194,488
	Intersegment revenues			-		107,227		-		-107,227		-
	Total revenues			221,479		307,687		-		-113,199		415,967
	Expenses
	Production taxes and other lease operating			42,403		-		-		-		42,403
	Gathering, transportation and processing			11,915		-		-		-		11,915
	Depreciation and amortization			70,049		14,619		397		-4,600		80,465
	Accretion of asset retirement obligations			324		-		-		-		324
	Cost of oilfield services			-		215,340		-		-73,219		142,121
	General and administrative, net of amounts capitalized:
	Stock-based compensation			832		363		4,447		-		5,642
	Other general and administrative			11,450		17,660		9,533		-		38,643
	Total operating expenses			136,973		247,982		14,377		-77,819		321,513
	Income (loss) from operations			84,506		59,705		-14,377		-35,380		94,454
	Other income (expense), net			1,292		-1,869		1,734		-1,469		-312
Net income (loss) before income taxes		$	85,798	$	57,836	$	-12,643	$	-36,849	$	94,142
		As of October 31, 2014
Net oil and natural gas properties		$	1,152,302	$	-	$	-	$	-84,941	$	1,067,361
Oilfield services equipment - net		$	-	$	80,114	$	-	$	-	$	80,114
Other property and equipment - net		$	6,714	$	23,946	$	1,919	$	-	$	32,579
Total assets (1)		$	1,338,162	$	225,924	$	96,240	$	-109,955	$	1,550,371
Total liabilities		$	763,964	$	131,445	$	138,196	$	-18,974	$	1,014,631
	-1		Our Corporate and Other total assets consist primarily of cash and cash equivalents of $14.1 million and our investment in Caliber of $74.1 million, in addition to the Company’s investment in subsidiaries the results of which are subsequently eliminated.
		For the Nine Months Ended October 31, 2013
(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
Revenues:
Oil, natural gas and natural gas liquids sales		$	111,176	$	-	$	-	$	-	$	111,176
Oilfield services for third parties			-		65,780		-		-3,719		62,061
Intersegment revenues			-		72,116		-		-72,116		-
Total revenues			111,176		137,896		-		-75,835		173,237
Expenses:
Production taxes and other lease operating			22,013		-		-		-		22,013
Gathering, transportation and processing			1,549		-		-		-		1,549
Depreciation and amortization			33,558		5,667		230		-2,455		37,000
Accretion of asset retirement obligations			1,000		-		-		-		1,000
Cost of oilfield services			-		99,330		-		-46,288		53,042
General and administrative, net of amounts capitalized:
Stock-based compensation			897		458		4,134		-		5,489
Other general and administrative			5,844		7,576		5,262		-		18,682
Total operating expenses			64,861		113,031		9,626		-48,743		138,775
Income (loss) from operations			46,315		24,865		-9,626		-27,092		34,462
Other income (expense), net			-1,083		-611		34,110		-1,677		30,739
Net income (loss) before income taxes		$	45,232	$	24,254	$	24,484	$	-28,769	$	65,201
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, we deferred recognition of approximately an additional $2.8 million and $0.4 million in oilfield services income for the three month periods ended October 31, 2014 and 2013, respectively, and approximately $6.0 million and $3.7 million in oilfield services income for the nine month periods ended October 31, 2014 and 2013, respectively, associated with our non-operating partners’ share of costs charged by RockPile for well completion activities on properties we operate, by charging such oilfield services income against oilfield services revenue and crediting proved oil and natural gas properties.
In addition, we deferred approximately $0.7 million and $0.4 million of Caliber gross profit from our share of its income for the three months ended October 31, 2014 and 2013, respectively, and approximately $1.5 million and $1.7 million for the nine months ended October 31, 2014 and 2013, respectively, associated with services it provided which 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.

Property_And_Equipment

Property And Equipment	9 Months Ended
	Oct. 31, 2014
Property And Equipment [Abstract]	'
Property And Equipment	'
	5.  PROPERTY AND EQUIPMENT
	Acquisitions
	Marathon Oil & Gas Property Acquisition
	On June 30, 2014, we acquired from Marathon Oil Company (“Marathon”) certain oil and 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, which included a net downward adjustment of $9.6 million for certain pre-closing adjustments.  Additional post-closing adjustments may be required.  Transaction costs related to the acquisition incurred during the nine months ended October 31, 2014 of approximately $1.3 million are recorded in the statement of operations with general and administrative expenses.
	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 final purchase price allocation is pending the completion of management’s assessment of the fair value of the assets acquired and liabilities assumed.  Accordingly, the allocation may change as additional information becomes available and is assessed by the Company, and the impact of such changes may be material.
	The following table summarizes the preliminary purchase price and the preliminary estimated values of assets acquired and liabilities assumed:
	Preliminary purchase price:
	(in thousands)
	Cash			$	90,352
	Total consideration given			$	90,352
	Preliminary fair value allocation of purchase price:
	Oil and natural gas properties:
	Proved properties			$	71,044
	Unproved properties				20,262
	Total oil and natural gas properties				91,306
	Accounts payable				-469
	Asset retirement obligations assumed				-485
	Fair value of net assets acquired			$	90,352
	Pro Forma Financial Information
	The following unaudited pro forma financial information represents the combined results for the Company and the properties acquired from Kodiak Oil & Gas Corporation, in August of 2013, and Marathon for the three month and nine months ended October 31, 2013, and for the properties acquired from Marathon for the three and nine months ended October 31, 2014, as if the acquisitions had occurred on February 1, 2012 and February 1, 2013, respectively.
		For the Three Months Ended				For the Nine Months Ended
		October 31,				October 31,
	(in thousands, except per share data)	2014		2013		2014		2013
	Operating revenues	$	174,196	$	102,310	$	427,708	$	219,467
	Net income	$	25,398	$	52,305	$	57,110	$	75,913
	Earnings per common share
	Basic	$	0.30	$	0.66	$	0.67	$	1.21
	Diluted	$	0.26	$	0.55	$	0.58	$	0.99
	Weighted average common shares outstanding:
	Basic		85,242		79,059		85,769		62,817
	Diluted		102,954		96,042		103,421		78,865
	The pro forma information includes the effects of adjustments for depreciation, amortization and accretion expense of $3.7 million for the three months ended October 31, 2013, and $3.4 million and $14.1 million for the nine months ended October 31, 2014 and 2013, respectively.  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 acquisitions had been completed on February 1, 2012 or 2013, respectively, nor are they necessarily indicative of future results.  During the three and nine months ended October 31, 2014, the Company realized $5.2 million and $7.3 million of revenue, respectively, and $1.6 million and $2.7 million of net earnings, respectively, from the properties acquired from Marathon.
	June 6, 2014 Oil & Gas Property Acquisition
	On June 6, 2014, the Company acquired, from an unrelated third party, certain oil and gas leaseholds located in Williams County, North Dakota comprising approximately 4,600 net acres and various other related rights, permits, contracts, equipment and other assets for approximately $34.5 million in cash, which included a net downward adjustment of $0.5 million for certain pre-closing adjustments (the “June 6, 2014 Acquisition”).  Additional post-closing adjustments may be required.
	Oil and Natural Gas Property Additions
	During the nine months ended October 31, 2014, we acquired oil and natural gas properties, and participated in the drilling and/or completion of wells, for total consideration of approximately $454.6 million.
	During the three and nine months ended October 31, 2014, we capitalized $1.2 million and $3.6 million, respectively, of internal land, geology and operations department costs directly associated with property acquisition, exploration (including lease record maintenance) and development.  During the three and nine months ended October 31, 2013, we capitalized $1.0 million and $2.6 million, respectively, of internal land and geology costs directly associated with property acquisition, exploration (including lease record maintenance) and development.  The internal land and geology department costs were capitalized to unevaluated costs.
	Oilfield Services Equipment Additions
	Oilfield services equipment additions of $41.3 million during the nine months ended October 31, 2014, consist primarily of the costs for two hydraulic fracturing spreads and other complementary well completion and workover equipment, $32.8 million of which was in service and $8.5 million of which was not yet placed in service at October 31, 2014.

Equity_Investment

Equity Investment	9 Months Ended
	Oct. 31, 2014
Equity Investment [Abstract]	'
Equity Investment	'
	6.  EQUITY INVESTMENT
	The Company’s investment interest in Caliber is considered to be variable, and Caliber is considered to be a variable interest entity because the power to direct the activities that most significantly impact Caliber’s economic performance does not reside with the holders of equity investment at risk.  However, the Company is not considered the primary beneficiary of Caliber since it does not have the power to direct the activities of Caliber that are considered most significant to the economic performance of Caliber.  Under the equity method, our investment will be adjusted each period for contributions made, distributions received, the change in the fair value of our holdings of equity investment derivatives of Caliber, and our share of Caliber’s net income and accretion of any basis difference.  Our maximum exposure to loss related to Caliber is limited to our equity investment as presented in the accompanying condensed consolidated balance sheet at October 31, 2014.  On June 30, 2014, the Company vested in 4,000,000 Class A Trigger Units and its ownership interest in Caliber increased from 30% to approximately 32%.
	We evaluate our equity method investments for impairment when events or changes in circumstances indicate there is a loss in value of the investment that is other than a temporary decline.
	As of October 31, 2014, the balance of the Company’s investment in Caliber was $74.1 million, which consisted of the following:
	(in thousands, except units)		Units		Investment
	Balance - January 31, 2014				$	68,536
	Change in fair value of:
	Class A Trigger Units (1)		4,000,000			1,746
	Series 1 Warrants (2)		5,600,000			2,214
	Series 2 Warrants		2,400,000			-158
	Series 3 Warrants		3,000,000			-87
	Series 4 Warrants		2,000,000			-53
	Equity investment share of net income for the period before intra-company profit elimination					1,926
	Balance - October 31, 2014				$	74,124
		-1		The change in value was prior to the vesting of the Class A Trigger Units into Class A Units on June 30, 2014.
	(2)  On June 30, 2014, the 1.6 million Class A Trigger Unit Warrants then outstanding automatically converted into Series 1 Warrants upon the Company’s vesting of the Class A Trigger Units, resulting in an aggregate of 5,600,000 Series 1 Warrants outstanding.

Debt

Debt	9 Months Ended
	Oct. 31, 2014
Debt [Abstract]	'
Debt	'
	7.    DEBT
	As of the dates indicated in the table below, the Company’s debt consisted of the following:
	(in thousands)	31-Oct-14		31-Jan-14
	5% convertible note	$	134,200	$	129,290
	TUSA credit facility		33,000		183,000
	RockPile credit facility		51,616		21,515
	Other notes and mortgages payable		10,175		9,403
	TUSA 6.75% notes		450,000		-
	Total debt		678,991		343,208
	Less current portion of debt:
	RockPile credit facility		-		-8,450
	Other notes and mortgages payable		-416		-401
	Total long-term debt	$	678,575	$	334,357
	5% Convertible Note
	On July 31, 2012, the Company sold to NGP Triangle Holdings, LLC a $120.0 million Convertible Note (the “5% 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 5% 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 5% Convertible Note.  Such interest is paid-in-kind by adding to the principal balance of the 5% Convertible Note, provided that, after October 31, 2017, the Company has the option to make such interest payments in cash.  As of October 31, 2014, $14.2 million of accrued interest has been added to the principal balance of the 5% Convertible Note.
	TUSA Credit Facility
	On April 11, 2013, TUSA entered into an Amended and Restated Credit Agreement, which was subsequently amended on July 30, 2013, October 16, 2013, January 13, 2014, May 9, 2014, May 14, 2014, and June 6, 2014 (as amended, the “TUSA Credit Facility”).
	Borrowings under the TUSA Credit Facility mature on October 16, 2018 and bear interest, at TUSA’s option, at either (i) the ABR (the highest of (A) the administrative agent’s prime rate, (B) the federal funds rate plus 0.5%, or (C) the one-month Eurodollar rate (as defined in the TUSA Credit Facility) plus 1%), 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 TUSA Credit Facility contains various covenants and restrictive provisions that may, among other things, limit TUSA’s ability to sell assets, incur additional indebtedness, make investments or loans and create liens.  In addition, the facility contains financial covenants requiring TUSA to: (i)  maintain a ratio of consolidated current assets to consolidated current liabilities (as those terms are defined in the TUSA Credit Facility) of at least 1.0 to 1.0 and (ii) maintain a ratio of consolidated debt to consolidated EBITDAX (as those terms are defined in the TUSA Credit Facility and determined as of the end of each fiscal quarter for the then most-recently ended four fiscal quarters) that is not greater than 4.0 to 1.0.  As of October 31, 2014, TUSA was in compliance with all covenants under the TUSA Credit Facility.
	On November 25, 2014, TUSA entered into a Second Amended and Restated Credit Agreement (“the TUSA 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 lenders will redetermine the borrowing base under the TUSA Credit Agreement on a semi-annual basis by the beginning of each May and November.  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 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).  As of November 25, 2014, the borrowing base was set by the lenders at $435.0 million.
	TUSA will pay a per annum fee on all letters of credit issued under the TUSA Credit Agreement, which fee will equal the applicable margin for loans accruing interest based on the eurodollar rate and a fronting fee to the issuing lender equal to the greater of 0.125% of the letter of credit amount and $500 per letter of credit. TUSA will pay a commitment fee that ranges between 0.375% and 0.50% per annum on the unused availability under the TUSA Credit Agreement.
	The TUSA Credit Agreement is collateralized by certain of TUSA’s assets, including (1) at least 80% of the adjusted engineered value of TUSA’s oil and 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 Agreement are guaranteed by TUSA’s domestic subsidiaries.
	Second Lien Credit Facility
	On June 27, 2014, TUSA entered into a Second Lien Credit Agreement (the “Second Lien Credit Facility”), which provided for a $60.0 million second priority secured credit facility, which was funded at signing. All borrowings under the Second Lien Credit Facility were scheduled to mature on October 16, 2019 (nine months after the maturity of the TUSA Credit Facility).  Borrowings under the Second Lien Credit Facility bore interest, at our option, at either (i) LIBOR (subject to a floor) plus a margin of 7% or (ii) a base rate (subject to a floor) plus a margin of 6%.  The Second Lien Credit Facility also provided that no prepayment fees would be payable for prepayments made during the first twelve months.
	Upon issuance of the TUSA 6.75% Notes on July 18, 2014, TUSA terminated the Second Lien Credit Facility and repaid all amounts owing thereunder.
	RockPile Credit Facility
	On March 25, 2014, RockPile entered into a Credit Agreement (the "RockPile Credit Facility") to provide a $100.0 million senior secured revolving credit facility with an accordion feature that allows for the expansion of the facility up to an aggregate of $150.0 million.
	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 RockPile Credit Facility) 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.  All borrowings under the RockPile Credit Facility mature on March 25, 2019.
	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.  As of October 31, 2014, the weighted-average interest rate on the loan was 3.39% and $51.6 million was outstanding under the facility.
	The RockPile Credit Facility contains financial covenants requiring RockPile to comply with the following: (i) the ratio of RockPile’s consolidated debt to EBITDA (as defined in the RockPile Credit Facility) may not be greater than 2.75 to 1.00 (determined as of the end of each fiscal quarter for the then most-recently ended four fiscal quarters) and (ii) RockPile must maintain a ratio of Adjusted EBITDA to Fixed Charges (as defined in the RockPile Credit Facility) of at least 1.25 to 1.00 quarterly.  As of October 31, 2014, RockPile was in compliance with all financial covenants under the RockPile Credit Facility.
	On November 13, 2014, RockPile entered into Amendment No. 1 to Credit Agreement and Incremental Commitment Agreement (“Amendment No. 1”), which amended the RockPile Credit Facility to increase the borrowing capacity under the facility from $100.0 million to $150.0 million.  Following Amendment No. 1, the facility maintained the accordion feature that allows for expansion of the facility by up to an additional $50.0 million, resulting in aggregate borrowing capacity of $200.0 million. 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.
	TUSA 6.75% Notes
	On July 18, 2014, TUSA entered into an indenture (the “Indenture”) among TUSA, Foxtrot Resources LLC (the “Guarantor”), a TUSA wholly-owned subsidiary, and Wells Fargo Bank, National Association, as trustee, governing the terms of TUSA’s $450.0 million aggregate principal amount of TUSA 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 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 100.0% 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 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 contains covenants that, among other things, restrict TUSA’s ability and the ability of any guarantor subsidiary to sell certain assets; make certain dividends, distributions, investments and other restricted payments; incur certain additional indebtedness and issue preferred stock; create certain liens; enter into transactions with affiliates; designate subsidiaries as unrestricted subsidiaries, and consolidate, merge or sell substantially all of TUSA’s assets.  These covenants are subject to a number of important exceptions and qualifications.  As of October 31, 2014, TUSA was in compliance with all covenants under the TUSA 6.75% Notes.

Derivative_Instruments

Derivative Instruments	9 Months Ended
	Oct. 31, 2014
Derivative Instruments [Abstract]	'
Derivative Instruments	'
	8.  DERIVATIVE INSTRUMENTS
	The following summarizes the fair value of the Company’s derivative instruments (in thousands):
					As of October 31, 2014
	Underlier		Balance Sheet Classification		Gross Amount of Recognized Assets (Liabilities)			Gross Amount of Offset		Net Amount of Assets (Liabilities)
	Crude oil derivative contracts		Current Assets		$	18,918		$	-	$	18,918
	Crude oil derivative contracts		Long-term assets		$	449		$	-	$	449
	Equity investment derivatives		Equity investment		$	3,612		$	-	$	3,612
					As of January 31, 2014
	Underlier		Balance Sheet Classification		Gross Amount of Recognized Assets (Liabilities)			Gross Amount of Offset		Net Amount of Assets (Liabilities)
	Crude oil derivative contracts		Current assets		$	1,066		$	-111	$	955
	Crude oil derivative contracts		Long-term assets		$	1,192		$	-	$	1,192
	Equity investment derivatives		Equity investment		$	39,734		$	-	$	39,734
	The Company recorded gains on its commodity derivative activities of $19.8 million and $13.4 million, respectively, for the  three and nine months ended October 31, 2014.   The Company recorded a gain on commodity derivative activities of $2.1 million and a loss of $1.1 million, respectively, for the three and nine months ended October 31, 2013.  We recorded gains of $0.7 million and $3.7 million, respectively, on our equity investment derivatives for the three and nine months ended October 31, 2014 and a gain of $35.8 million for the three and nine months ended October 31, 2013.
	Commodity Derivative 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 three 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 and are included in the accompanying condensed consolidated balance sheets as derivative assets and liabilities.  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 gain (loss) from derivative activities line on the condensed consolidated statements of operations.  The Company’s cash flow is 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 condensed consolidated statements of cash flows.
	The Company's valuation estimate takes into consideration the counterparties' credit worthiness, the Company's credit worthiness, and the time value of money.  The consideration of the factors results in an estimated exit-price for each derivative asset or liability under a marketplace participant's view.  Management believes that this approach provides a reasonable, non-biased, verifiable, and consistent methodology for valuing commodity derivative instruments.
	The Company's commodity derivative contracts as of October 31, 2014 are summarized below:
	Term End Date		Contract Type		Basis (1)		Quantity (Bbl/d)		Weighted Average Put Strike	Weighted Average Call Strike
	Fiscal Year 2015		Collar		NYMEX		5,899		$87.40	$99.90
	Fiscal Year 2016		Collar		NYMEX		4,356		$86.85	$98.06
		-1		“NYMEX” refers to West Texas Intermediate crude oil prices at Cushing, Oklahoma as quoted on the New York Mercantile Exchange.
	Equity Investment Derivatives
	At October 31, 2014, the Company held Class A (Series 1 through Series 4) Warrants to acquire additional ownership in Caliber.  These instruments are valued using the following valuation techniques, which are generally less observable from objective sources.  As such, the Company has classified these instruments as Level 3 in fair value hierarchy (see Note 9 – Fair Value Measurements).
	The fair value of the Class A (Series 1 through Series 4) Warrants as of October 31, 2014, were estimated using a Monte Carlo Simulation (“MCS”) model.  An MCS model provides a numeric approach to stochastic stock movement to forecast the future stock price of the underlying Class A Units, as opposed to an analytic solution provided by Black-Scholes.  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 flow analysis.  The resulting value represented a marketable minority value of Caliber.  As the Class A Units represent a non-marketable equity interest in a private enterprise, an adjustment to our preliminary value estimates was made to account for the lack of liquidity.  The concluded fair value of a single Class A Unit of Caliber was determined to be $10.43 at October 31, 2014, an increase of $0.23 per unit from July 31, 2014, and an increase of $0.43 per unit from January 31, 2014.
	The MCS model assumed that the warrants would be exercised at the earlier of (a) the contractual life of 12 years, and (b) the point at which the exercise price would be reduced to $5.00 per warrant (at which point it would be advantageous for Triangle to exercise early to capture future distributions on the Class A Units).  The key inputs to the MCS model are the same as the Black-Scholes model previously used including 10-year historical volatilities for publicly-traded comparable companies, risk-free interest rates over the expected warrant term and dividend yields based on expected distributions.  The change in fair value during the three and nine months ended October 31, 2014 resulted in a $0.7 million and $2.0 million increase, respectively, in our equity investment account in the accompanying unaudited condensed consolidated balance sheet and as the gain on equity investment derivatives reflected in the accompanying unaudited condensed consolidated statement of operations.
	Also included in the gain on equity investment derivatives during the nine months ended October 31, 2014 was a gain of $1.7 million associated with the change in fair value of the 4.0 million Caliber Class A Trigger Units which vested on June 30, 2014.

Fair_Value_Measurements

Fair Value Measurements	9 Months Ended
	Oct. 31, 2014
Fair Value Measurements [Abstract]	'
Fair Value Measurements	'
	9.  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 flow 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 October 31, 2014 and January 31, 2014, by level within the fair value hierarchy:
			As of October 31, 2014
	(in thousands)		Level 1		Level 2		Level 3		Total
	Assets:
	Equity investment derivative assets		$	-	$	-	$	3,612	$	3,612
	Commodity derivative assets		$	-	$	19,367	$	-	$	19,367
	Liabilities:
	RockPile earn-out liability		$	-	$	-1,818	$	-	$	-1,818
			As of January 31, 2014
	(in thousands)		Level 1		Level 2		Level 3		Total
	Assets:
	Equity investment derivative assets		$	-	$	-	$	39,734	$	39,734
	Commodity derivative assets		$	-	$	2,147	$	-	$	2,147
	Liabilities:
	RockPile earn-out liability		$	-	$	-1,739	$	-	$	-1,739
	Commodity Derivative Instruments
	The Company determines its estimate of the fair value of its 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 consideration of 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 considers its counterparties to be of substantial credit quality and believes that such counterparties have the financial resources and willingness to meet their potential repayment obligations associated with the derivative transactions.  At October 31, 2014, derivative instruments utilized by the Company consisted of costless collars and swaps.  The crude oil derivative markets are highly active.  Although the Company's derivative instruments are valued using public indices, the instruments themselves are traded with third-party counterparties and are not openly traded on an exchange.  As such, the Company has classified these instruments as Level 2.
	Caliber Class A (Series 1 through Series 4) Warrants
	At October 31, 2014, the Caliber Class A (Series 1 through Series 4) Warrants are valued using valuation factors that are generally less observable from objective sources.  As such, the Company has classified these instruments as Level 3.
	RockPile 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 following table presents the rollforward of the fair values of the Company’s Level 3 financial assets and liabilities:
	(in thousands)		Class A Trigger Units		Warrants (1)
	Beginning balance, January 31, 2014		$	38,091	$	1,696
	Net unrealized gain			1,746		1,916
	Conversion to Class A units			-39,837		-
	Ending balance, October 31, 2014		$	-	$	3,612
		-1		Includes Caliber Class A (Series 1 through Series 4) Warrants.
	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 5% Convertible notes estimated fair value is based on discounted cash flow analysis and option pricing (Level 3).  The carrying amount of the Company’s revolving credit facilities approximated fair value because the interest rate of the facilities is variable. The fair value of other notes and mortgages payable is not significantly different than their carry values.  The fair value of the TUSA 6.75% notes is derived from quoted market prices (Level 1). This disclosure does not impact our financial position, results of operations or cash flows.
			October 31, 2014				31-Jan-14
			Carrying		Estimated		Carrying		Estimated
			Value		Fair Value		Value		Fair Value
	(in thousands)
	5% Convertible note		$	134,200	$	183,200	$	129,290	$	169,200
	Revolving credit facilities			84,616		84,616		196,065		196,065
	Other notes and mortgages payable			9,759		9,759		9,002		9,002
	TUSA 6.75% notes			450,000		398,300		-		-

Commitments_And_Contingencies

Commitments And Contingencies	9 Months Ended
	Oct. 31, 2014
Commitments And Contingencies [Abstract]	'
Commitments And Contingencies	'
	10.  COMMITMENTS AND CONTINGENCIES
	As of October 31, 2014, there were no known environmental or other regulatory matters related to the Company’s operations that were reasonably expected to result in a material liability other than asset retirement obligations which are reflected on the condensed consolidated balance sheet.  Non-compliance with environmental laws and regulations has not had, and is not expected to have, a material adverse effect on the Company’s financial position, results of operations or cash flows.
	Pursuant to the Third Amended and Restated Employment Agreement, dated July 4, 2013 (the "Employment Agreement"), between the Company and Jonathan Samuels, our President and Chief Executive Officer, Mr. Samuels is entitled to a cash bonus payable upon a liquidity event involving RockPile or Caliber based on the percentage gain realized by the Company relative to its investment in the relevant entity.  The amount of this bonus would be equivalent to 5.0% of that gain in Caliber for a Caliber liquidity event, and 3.5% of that gain in RockPile for a RockPile liquidity event.  The right to the bonus vests and becomes non-forfeitable in thirds on the first three anniversaries of the execution date of the Employment Agreement, with acceleration or forfeiture of the unvested portions of such right upon the occurrence of certain events.  Because consummation of a liquidity event involving RockPile or Caliber is contingent on many unknown factors, the Company has determined that the contingent liability associated with such a bonus is not probable at October 31, 2014, and, therefore, no amounts have been recorded in the accompanying condensed consolidated balance sheets.

Capital_Stock

Capital Stock	9 Months Ended
	Oct. 31, 2014
Capital Stock [Abstract]	'
Capital Stock	'
	11.  CAPITAL STOCK
	Common Stock
	During the nine months ended October 31, 2014, the Company issued 635,999 shares of its common stock (net of shares surrendered for related employee payroll tax withholding) for restricted stock units that vested during the period and, during the three months ended October 31, 2014, the Company repurchased and retired 4.9 million shares of common stock at an average cost of $9.07 per share.
	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 Company’s Board of Directors approved the 2014 Equity Incentive Plan (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 reserved for issuance under the 2014 Plan is 6.0 million shares, subject to adjustment for certain transactions.
	For the three and nine months ended October 31, 2014 and 2013, the Company recorded stock-based compensation related to restricted stock units, stock options and RockPile Series B Units as follows:
			Three Months Ended October 31,
			2014			2013
	(in thousands)
	Restricted stock units		$	1,298		$	2,059
	Stock options			627			648
	RockPile stock based compensation related to Series B Units			146			148
				2,071			2,855
	Less amounts capitalized to oil and natural gas properties			-244			-398
	Compensation expense		$	1,827		$	2,457
			Nine Months Ended October 31,
			2014			2013
	(in thousands)
	Restricted stock units		$	4,572		$	5,419
	Stock options			1,600			648
	RockPile stock based compensation related to Series B Units			363			458
				6,535			6,525
	Less amounts capitalized to oil and natural gas properties			-893			-1,036
	Compensation expense		$	5,642		$	5,489
	Restricted Stock Units
	During the nine months ended October 31, 2014, the Company granted 1,380,200 restricted stock units as compensation to employees, officers and directors.  Restricted stock units vest over one to five years.  As of October 31, 2014, there was approximately $20.8 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 2.4 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 status of restricted stock units outstanding:
			Number of Shares		Weighted- Average Award Date Fair Value
	Restricted stock units outstanding - January 31, 2014		2,875,624		$	6.75
	Units granted		1,380,200		$	9.67
	Units forfeited		-330,171		$	7.15
	Units that vested		-922,393		$	7.18
	Restricted stock units outstanding - October 31, 2014		3,003,260		$	7.84
	Stock Options
	On September 9, 2014, the Company granted options to acquire 700,000 shares of the Company’s common stock pursuant to the 2014 Plan at the following exercise prices: 233,333 shares at $12.00 per share (which expire on September 9, 2021), 233,333 shares at $14.00 per share (which expire on September 9, 2021) and 233,334 at $16.00 per share (which expire on September 9, 2024).  Each tranche vests in three equal installments on the first three anniversaries of the grant date.
	Compensation expense related to stock options is calculated using the Black-Scholes valuation model.  Expected volatility is generally based on the historical volatility of Triangle's common stock.  The expected term of the options is estimated based on factors such as vesting periods, contractual expiration dates, historical trends in the Company's common stock price and historical exercise behavior.  The risk-free rate for the expected term (from service inception to option exercise) of the options is based on the yields of U.S. Treasury instruments with lives comparable to the estimated expected option term or life.
	The following assumptions were used for the Black-Scholes model to calculate the share-based compensation expense for the options granted:
	Risk free rate			1.06%
	Dividend yield			-
	Expected volatility			54%
	Weighted average expected stock option life (years)			3.0
	As of October 31, 2014, there was approximately $19.3 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 3.6 years.  The following table summarizes the status of stock options outstanding:
			Number of Shares		Weighted Average Exercise Price
	Options outstanding - January 31, 2014 (108,333 exercisable)		6,108,333		$	11.07
	Options forfeited		-		$	-
	Options exercised		-		$	-
	Options granted		700,000		$	14.00
	Options outstanding - October 31, 2014 (708,333 exercisable)		6,808,333		$	11.37
	The following table presents additional information related to the stock options outstanding at October 31, 2014:
					Remaining
	Exercise Price				Contractual Life		Number of shares
	per Share				(years)		Outstanding		Exercisable
	$	1.25			0.08			108,333		108,333
	$	7.50			8.68			750,000		75,000
	$	8.50			8.68			750,000		75,000
	$	10.00			8.68			1,500,000		150,000
	$	12.00			8.68			1,500,000		150,000
	$	12.00			6.86			233,333		-
	$	14.00			6.86			233,333		-
	$	15.00			8.68			1,500,000		150,000
	$	16.00			9.87			233,334		-
							6,808,333		708,333
Weighted average exercise price per share						$	11.37	$	9.72
Weighted average remaining contractual life							8.46		7.36
RockPile Share-Based Compensation
Effective October 22, 2012, RockPile's Board of Managers approved the Second Amended and Restated Limited Liability Company Agreement, as further amended on February 20, 2013 (“RockPile LLC Agreement”), which includes provisions allowing RockPile to issue an aggregate of up to 6.0 million Series B Units in multiple series designated by a sequential number (i.e., Series B-1, Series B-2, etc.) with the ability to re-issue forfeited or redeemed Series B Units.  RockPile issued 1,412,000 Series B Units and redeemed 180,000 B-1 Units during the nine months ended October 31, 2014.
A summary of the activity for RockPile’s Series B Units is as follows:
	Series		Series		Series		Series	Total
	B-1 units		B-2 units		B-3 units		B-4 units
Units outstanding - January 31, 2014	3,100,000		60,000		910,000		-	4,070,000
Units forfeited	-		-		-		-	-
Units redeemed	-180,000		-		-		-	-180,000
Units granted	-		-		-		1,412,000	1,412,000
Units outstanding - October 31, 2014	2,920,000		60,000		910,000		1,412,000	5,302,000
Vested	2,386,667		30,000		188,000		-	2,604,667
Unvested	533,333		30,000		722,000		1,412,000	2,697,333
As of October 31, 2014, there was approximately $2.7 million of unrecognized compensation cost related to unvested Series B Units.  We expect to recognize such cost on a pro-rata basis on the Series B Units’ vesting schedule during the next five fiscal years.

Earnings_Per_Share

Earnings Per Share	9 Months Ended
	Oct. 31, 2014
Earnings Per Share [Abstract]	'
Earnings Per Share	'
	12.  EARNINGS PER SHARE
	Basic net income (loss) per common share is computed by dividing net income (loss) attributable to 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, and (ii) vesting of restricted stock units.  The treasury stock method assumes exercise, vesting or conversion at the beginning of a period of 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.
	The potential dilution from the conversion of the 5% Convertible Note is determined using the “if converted” method whereby the shares issuable upon conversion are added to the denominator and the current period interest expense is added to the numerator, on an after-tax basis, to determine the dilutive effect of such conversion if it had occurred at the beginning of the period.
	The table below sets forth the computations of net income per common share (basic and diluted) for the three and nine months ended October 31, 2014 and 2013:
		For the Three Months Ended				For the Nine Months Ended
		October 31,				October 31,
	(in thousands, except per share data)	2014		2013		2014		2013
	Net income attributable to common stockholders	$	25,398	$	47,221	$	54,492	$	59,232
	Effect of 5% Convertible Note conversion		919		881		2,852		2,503
	Net income attributable to common stockholders after effect of debt conversion		26,317		48,102		57,344		61,735
	Basic weighted average common shares outstanding		85,242		79,059		85,769		62,817
	Effect of dilutive securities		17,712		16,983		17,652		16,048
	Diluted weighted average common shares outstanding		102,954		96,042		103,421		78,865
	Basic net income per share	$	0.30	$	0.60	$	0.64	$	0.94
	Diluted net income per share	$	0.26	$	0.50	$	0.55	$	0.78
	Of the stock options, restricted stock units and convertible debt outstanding at October 31, 2014, 6.7 million outstanding options were anti-dilutive for the three and nine month periods ended October 31, 2014, and 0.04 million and 0.08 million of restricted stock units were anti-dilutive for the three and nine months periods ended October 31, 2014, respectively, and therefore were excluded from the calculation of the diluted net income per share for those three and nine month periods.  These awards could potentially be dilutive in future periods.

Income_Taxes

Income Taxes	9 Months Ended
	Oct. 31, 2014
Income Taxes [Abstract]	'
Income Taxes	'
	13.  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.
	The effective tax rate for the nine months ended October 31, 2014 was 42.1%, which differs from the statutory income tax rate due primarily to permanent book to tax differences and state income taxes.
	As of October 31, 2014, the Company had no unrecognized tax benefits (or associated ASC 740-10-25 liabilities) for ASC 740-10-25 purposes.  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 ASC 740-10-25 position during the first three quarters of fiscal year 2015.  Given the substantial net operating loss carry forwards 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 adjust only net operating loss carry forwards.

Related_Party_Transactions

Related Party Transactions	9 Months Ended
	Oct. 31, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	14.  RELATED PARTY TRANSACTIONS
	On October 1, 2012, Triangle entered into a Services Agreement with Caliber GP (the general partner of Caliber) and Caliber to provide administrative services to Caliber necessary to operate, manage, maintain and report the operating results of Caliber's gathering pipelines, transportation pipelines, related equipment and other assets.
	On September 12, 2013, TUSA and Caliber North Dakota amended and restated two midstream services agreements, which the parties originally entered into on October 1, 2012.  Caliber North Dakota is a wholly-owned subsidiary of Caliber.  The two original midstream services agreements were as follows:  (a) an agreement for crude oil gathering, stabilization, treating and redelivery, and (b) an agreement for (i) natural gas compression, gathering, dehydration, processing and redelivery; (ii) produced water transportation and disposal services; and (iii) fresh water transportation for TUSA’s oil and natural gas drilling and production operations.  The two agreements were revised to include an additional acreage dedication from TUSA to Caliber North Dakota and an increased firm volume commitment by Caliber North Dakota for each service line.  The revenue commitment language included in the original midstream services agreements was removed and replaced by a stand-alone agreement.
	TUSA maintained the commitment included in the original midstream services agreement to deliver minimum monthly revenues derived from the fees paid by TUSA to Caliber North Dakota for volumes of oil, natural gas, produced water, and fresh water for a primary term of 15 years beginning on the in-service date of the Caliber North Dakota facilities and added a commitment to deliver additional minimum monthly revenues derived from the fees paid by TUSA to Caliber North Dakota related to the increased acreage dedication and increased firm volume commitment.  The minimum commitment over the term of the agreements is $405.0 million, of which $375.3 million remained at October 31, 2014.
	On September 12, 2013, TUSA and Caliber Measurement Services LLC ("Caliber Measurement"), a wholly-owned subsidiary of Caliber, entered into a gathering services agreement pursuant to which Caliber Measurement will provide certain gathering-related measurement services to TUSA.
	On May 14, 2014, TUSA and Caliber Midstream Fresh Water Partners LLC ("Caliber Fresh Water"), which is owned 51% by a wholly-owned subsidiary of Caliber and 49% by a third party, entered into a fresh water sales agreement pursuant to which Caliber Fresh Water 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.  The agreement obligates TUSA to purchase all of the fresh water it requires for its drilling and operating activities in North Dakota exclusively from Caliber Fresh Water, subject to availability, but it does not require TUSA to purchase a minimum volume of fresh water.
	On May 14, 2014, TUSA entered into a Purchase and Sale Agreement with Caliber North Dakota whereby TUSA agreed to sell two salt water disposal wells to Caliber North Dakota for $7.5 million, subject to necessary regulatory approvals.  During the third quarter of fiscal 2015, the Company received the necessary approvals with respect to one of the salt water disposal wells and consummated that sale for total proceeds of $1.5 million, all of which was recorded as a reduction to the Company’s proved oil and natural gas properties and no gain or loss was recognized.  As of October 31, 2014, the sale of the second salt water disposal well had not yet been consummated; however, the Company expects to finalize the transaction during its fiscal 2015 fourth quarter.
	For the three and nine months ended October 31, 2014, Caliber North Dakota had $14.4 million and $28.0 million of revenue, respectively, of which $11.6 million and $23.8 million, respectively, were from TUSA.
	For the three and nine month period ended October 31, 2014, Triangle received $0.1 million and $0.7 million, respectively, from Caliber for certain administrative services supplemental to those provided by Caliber employees.  The administrative services were provided pursuant to the October 1, 2012 Services Agreement between Triangle and Caliber.

Supplemental_Disclosures_Of_Ca

Supplemental Disclosures Of Cash Flow Information	9 Months Ended
	Oct. 31, 2014
Supplemental Disclosures of Cash Flow Information [Abstract]	'
Supplemental Disclosures of Cash Flow Information	'
	15.  SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
		For the Nine Months Ended
		October 31,
	(in thousands)	2014		2013
	Cash paid during the period for:
	Interest expense	$	5,672	$	2,260
	Income taxes	$	550	$	-
	Non-cash investing activities:
	Additions (reductions) to oil and natural gas properties through:
	Increased accounts payable and accrued liabilities	$	103,415	$	28,874
	Issuance of common stock	$	-	$	2,435
	Capitalized stock based compensation	$	893	$	1,036
	Change in asset retirement obligations	$	1,519	$	608
	Capitalized interest	$	3,422	$	1,956
	Acquisition of oilfield services equipment through notes payable and liabilities	$	-	$	2,262
	Non-cash financing activities:
	Notes payable issued for redemption of RockPile B units	$	1,041	$	-

Significant_Changes_in_Proved_

Significant Changes in Proved Oil And Natural Gas Reserves	9 Months Ended
	Oct. 31, 2014
Significant Changes In Proved Oil And Natural Gas Reserves (Abstract)	'
Significant Changes In Proved Oil And Natural Gas Reserves	'
	16.  SIGNIFICANT CHANGES IN PROVED OIL AND NATURAL GAS RESERVES
	Our proved oil and natural gas reserves at October 31, 2014 increased from our proved oil and natural gas reserves at
	January 31, 2014.  Our proved reserves are in the Bakken and Three Forks formations in the North Dakota Counties of McKenzie, Williams, Stark, Mountrail and Dunn, and in Roosevelt and Sheridan Counties, Montana.
	The reserve estimates at October 31, 2014 were estimated by our in-house reservoir engineer, who has been a Petroleum Engineer since 1995 and has over 19 years of experience.  Our reserve estimate at January 31, 2014, was audited by Cawley, Gillespie & Associates, Inc., an independent petroleum engineering firm.  Proved reserves are the estimated quantities of oil and natural gas, which by analysis of geoscience and engineering data can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations.  Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined, and the price to be used is the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period.  For the purposes of preparing the estimates of proved reserves presented below, such average prices were $86.29 per barrel of oil, $43.23 per barrel of natural gas liquids and $5.79 per Mcf of natural gas for the reserves presented as of October 31, 2014.  For the reserves presented as of January 31, 2014, the average prices were $93.09 per barrel of oil, $44.10 per barrel of natural gas liquids and $3.99 per Mcf of natural gas.
		% of	31-Oct-14				January 31,
		Reserves	Oil	Gas	NGL		2014
	Reserve Category	(Mboe)	(Mbbls)	(MMcf)	(Mbbls)	Mboe	Mboe
	Proved Developed	57%	26,816	22,242	2,072	32,595	16,995
	Proved Undeveloped	43%	19,605	16,407	2,185	24,525	23,319
	Total Proved	100%	46,421	38,649	4,257	57,120	40,314
	The primary reasons for the increase in proved reserves is the drilling and completion of wells in the first nine months of fiscal year 2015, as well as the Marathon acquisition and the June 6, 2014 Acquisition, both of which closed during the nine months ended October 31, 2014.  Our net interest in proved developed wells increased 121% from 50.0 net wells at January 31, 2014 to 110.3 net wells at October 31, 2014, and our net interest in proved undeveloped locations increased 9% from 52.5 net future development wells at January 31, 2014 to 57.2 net future development wells at October 31, 2014.

Basis_Of_Presentation_Policy

Basis Of Presentation (Policy)	9 Months Ended
	Oct. 31, 2014
Basis Of Presentation [Abstract]	'
Use of Estimates	'
	Use of Estimates
	The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period.  Management believes the major estimates and assumptions impacting our condensed consolidated financial statements are the following:
		·	estimates of proved reserves of oil and natural gas, which affect the calculations of amortization and consideration of any possible impairment of capitalized costs of proved oil and natural gas properties;
		·	estimates of the fair value of unproved oil and natural gas properties we own and the consideration of any possible impairment;
		·	assumptions impacting our estimates as to the future realization of deferred income tax assets and the amount of our deferred tax liabilities;
		·	consideration of any impairment of our other long-term assets;
		·	depreciation of property and equipment; and
		·	valuation of derivative instruments.
	Actual results may differ from estimates and assumptions of future events.  Future production may vary materially from estimated oil and natural gas proved reserves.  Actual future prices may vary significantly from price assumptions used for determining proved reserves and for financial reporting.
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 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 20.0% and 50.0% and exercises significant influence.    Triangle Caliber Holdings, LLC, a wholly-owned subsidiary of Triangle, is a joint venture partner in Caliber.  The Company’s investment in Caliber is accounted for utilizing the equity method of accounting.
Reclassifications	'
	Reclassifications
	Certain amounts in the condensed consolidated balance sheet as of January 31, 2014, and in our condensed consolidated statement of operations for the three and nine months ended October 31, 2013, have been reclassified to conform to the financial statement presentation for the period ended October 31, 2014.  Such reclassifications had no impact on consolidated total assets, stockholders’ equity or net income previously reported.

Summary_Of_Significant_Account1

Summary Of Significant Accounting Policies (Policy)	9 Months Ended
	Oct. 31, 2014
Summary Of Significant Accounting Policies [Abstract]	'
New Pronouncements Issued But Not Yet Adopted	'
	New Pronouncements Issued But Not Yet Adopted
	In April 2014, the FASB issued Accounting Standards Update (“ASU”) No. 2014-08, Presentation of Financial Statements (Topic 205) and Property, Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity.  ASU 2014-08 modifies the criteria for disposals to qualify as discontinued operations and expands related disclosures.  The guidance is effective for annual and interim reporting periods beginning after December 15, 2014.  Adoption of this amendment will not have a material effect on our financial position or results of operations.
	In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers, issued as a new Topic, Accounting Standards Codification Topic 606.  The new revenue recognition standard provides a five-step analysis of transactions to determine when and how revenue is recognized.  The core principle of the guidance is that a company should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.  This ASU is effective for the Company beginning in fiscal year 2017 and can be adopted by the Company either retrospectively or as a cumulative-effect adjustment as of the date of adoption.  We are currently evaluating the effect that adopting this new accounting guidance will have on our consolidated results of operations, cash flows and financial position.
	In August 2014, the FASB issued ASU No. 2014-15, which requires management of public and private companies to evaluate whether there are conditions and events that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the financial statements are issued (or available to be issued when applicable) and, if so, to disclose that fact.  Management will be required to make this evaluation for both annual and interim reporting periods, if applicable.  ASU No. 2014-15 is effective for annual periods ending after December 15, 2016 and interim periods within annual periods beginning after December 15, 2016.  The Company does not expect the adoption of this amendment to have a material impact on its consolidated financial statements.
	Accounting standard-setting organizations frequently issue new or revised accounting rules.  We regularly review new pronouncements to determine their impact, if any, on our condensed consolidated financial statements.  Other than the standards discussed above, there are no significant accounting standards applicable to Triangle which have not been adopted.

Segment_Reporting_Tables

Segment Reporting (Tables)	9 Months Ended
	Oct. 31, 2014
Segment Reporting [Abstract]	'
Schedule Of Segment Reporting	'
			For the Three Months Ended October 31, 2014
	(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
	Revenues:
	Oil, natural gas and natural gas liquids sales		$	80,139	$	-	$	-	$	-	$	80,139
	Oilfield services for third parties			-		96,810		-		-2,753		94,057
	Intersegment revenues			-		46,941		-		-46,941		-
	Total revenues			80,139		143,751		-		-49,694		174,196
	Expenses:
	Production taxes and other lease operating			16,091		-		-		-		16,091
	Gathering, transportation and processing			4,380		-		-		-		4,380
	Depreciation and amortization			27,998		6,249		125		-1,791		32,581
	Accretion of asset retirement obligations			149		-		-		-		149
	Cost of oilfield services			-		102,762		-		-31,905		70,857
	General and administrative, net of amounts capitalized:
	Stock-based compensation			93		146		1,588		-		1,827
	Other general and administrative			4,230		7,310		3,426		-		14,966
	Total operating expenses			52,941		116,467		5,139		-33,696		140,851
	Income (loss) from operations			27,198		27,284		-5,139		-15,998		33,345
	Other income (expense), net			12,263		-695		443		-658		11,353
	Net income (loss) before income taxes		$	39,461	$	26,589	$	-4,696	$	-16,656	$	44,698
			For the Three Months Ended October 31, 2013
	(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
	Revenues:
	Oil, natural gas and natural gas liquids sales		$	55,477	$	-	$	-	$	-	$	55,477
	Oilfield services for third parties			-		33,498		-		-426		33,072
	Intersegment revenues			-		32,681		-		-32,681		-
	Total revenues			55,477		66,179		-		-33,107		88,549
	Expenses:
	Production taxes and other lease operating			10,604		-		-		-		10,604
	Gathering, transportation and processing			1,443		-		-		-		1,443
	Depreciation and amortization			16,829		2,700		100		-1,020		18,609
	Accretion of asset retirement obligations			983		-		-		-		983
	Cost of oilfield services			-		49,839		-		-20,675		29,164
	General and administrative, net of amounts capitalized:
	Stock-based compensation			328		148		1,981		-		2,457
	Other general and administrative			2,594		3,150		2,385		-		8,129
	Total operating expenses			32,781		55,837		4,466		-21,695		71,389
	Income (loss) from operations			22,696		10,342		-4,466		-11,412		17,160
	Other income (expense), net			1,553		-242		35,103		-384		36,030
	Net income (loss) before income taxes		$	24,249	$	10,100	$	30,637	$	-11,796	$	53,190
	The following tables present selected financial information for our operating segments for the nine months ended October 31, 2014 and 2013:
			For the Nine Months Ended October 31, 2014
	(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
	Revenues:
	Oil, natural gas and natural gas liquids sales		$	221,479	$	-	$	-	$	-	$	221,479
	Oilfield services for third parties			-		200,460		-		-5,972		194,488
	Intersegment revenues			-		107,227		-		-107,227		-
	Total revenues			221,479		307,687		-		-113,199		415,967
	Expenses
	Production taxes and other lease operating			42,403		-		-		-		42,403
	Gathering, transportation and processing			11,915		-		-		-		11,915
	Depreciation and amortization			70,049		14,619		397		-4,600		80,465
	Accretion of asset retirement obligations			324		-		-		-		324
	Cost of oilfield services			-		215,340		-		-73,219		142,121
	General and administrative, net of amounts capitalized:
	Stock-based compensation			832		363		4,447		-		5,642
	Other general and administrative			11,450		17,660		9,533		-		38,643
	Total operating expenses			136,973		247,982		14,377		-77,819		321,513
	Income (loss) from operations			84,506		59,705		-14,377		-35,380		94,454
	Other income (expense), net			1,292		-1,869		1,734		-1,469		-312
	Net income (loss) before income taxes		$	85,798	$	57,836	$	-12,643	$	-36,849	$	94,142
			As of October 31, 2014
	Net oil and natural gas properties		$	1,152,302	$	-	$	-	$	-84,941	$	1,067,361
Oilfield services equipment - net		$	-	$	80,114	$	-	$	-	$	80,114
Other property and equipment - net		$	6,714	$	23,946	$	1,919	$	-	$	32,579
Total assets (1)		$	1,338,162	$	225,924	$	96,240	$	-109,955	$	1,550,371
Total liabilities		$	763,964	$	131,445	$	138,196	$	-18,974	$	1,014,631
	-1		Our Corporate and Other total assets consist primarily of cash and cash equivalents of $14.1 million and our investment in Caliber of $74.1 million, in addition to the Company’s investment in subsidiaries the results of which are subsequently eliminated.
		For the Nine Months Ended October 31, 2013
(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
Revenues:
Oil, natural gas and natural gas liquids sales		$	111,176	$	-	$	-	$	-	$	111,176
Oilfield services for third parties			-		65,780		-		-3,719		62,061
Intersegment revenues			-		72,116		-		-72,116		-
Total revenues			111,176		137,896		-		-75,835		173,237
Expenses:
Production taxes and other lease operating			22,013		-		-		-		22,013
Gathering, transportation and processing			1,549		-		-		-		1,549
Depreciation and amortization			33,558		5,667		230		-2,455		37,000
Accretion of asset retirement obligations			1,000		-		-		-		1,000
Cost of oilfield services			-		99,330		-		-46,288		53,042
General and administrative, net of amounts capitalized:
Stock-based compensation			897		458		4,134		-		5,489
Other general and administrative			5,844		7,576		5,262		-		18,682
Total operating expenses			64,861		113,031		9,626		-48,743		138,775
Income (loss) from operations			46,315		24,865		-9,626		-27,092		34,462
Other income (expense), net			-1,083		-611		34,110		-1,677		30,739
Net income (loss) before income taxes		$	45,232	$	24,254	$	24,484	$	-28,769	$	65,201

Property_And_Equipment_Tables

Property And Equipment (Tables)	9 Months Ended
	Oct. 31, 2014
Property, Plant and Equipment [Line Items]	'
Proforma Schedule For Oil And Natural Gas Acquisition	'
		For the Three Months Ended				For the Nine Months Ended
		October 31,				October 31,
	(in thousands, except per share data)	2014		2013		2014		2013
	Operating revenues	$	174,196	$	102,310	$	427,708	$	219,467
	Net income	$	25,398	$	52,305	$	57,110	$	75,913
	Earnings per common share
	Basic	$	0.30	$	0.66	$	0.67	$	1.21
	Diluted	$	0.26	$	0.55	$	0.58	$	0.99
	Weighted average common shares outstanding:
	Basic		85,242		79,059		85,769		62,817
	Diluted		102,954		96,042		103,421		78,865
Marathon Oil And Gas [Member]	'
Property, Plant and Equipment [Line Items]	'
Schedule Of Purchase Price Allocation Of Oil And Natural Gas Acquisition	'
	Preliminary purchase price:
	(in thousands)
	Cash			$	90,352
	Total consideration given			$	90,352
	Preliminary fair value allocation of purchase price:
	Oil and natural gas properties:
	Proved properties			$	71,044
	Unproved properties				20,262
	Total oil and natural gas properties				91,306
	Accounts payable				-469
	Asset retirement obligations assumed				-485
	Fair value of net assets acquired			$	90,352

Equity_Investment_Tables

Equity Investment (Tables)	9 Months Ended
	Oct. 31, 2014
Equity Investment [Abstract]	'
Schedule Of Equity Investment In Caliber	'
	(in thousands, except units)		Units		Investment
	Balance - January 31, 2014				$	68,536
	Change in fair value of:
	Class A Trigger Units (1)		4,000,000			1,746
	Series 1 Warrants (2)		5,600,000			2,214
	Series 2 Warrants		2,400,000			-158
	Series 3 Warrants		3,000,000			-87
	Series 4 Warrants		2,000,000			-53
	Equity investment share of net income for the period before intra-company profit elimination					1,926
	Balance - October 31, 2014				$	74,124
		-1		The change in value was prior to the vesting of the Class A Trigger Units into Class A Units on June 30, 2014.
	(2)  On June 30, 2014, the 1.6 million Class A Trigger Unit Warrants then outstanding automatically converted into Series 1 Warrants upon the Company’s vesting of the Class A Trigger Units, resulting in an aggregate of 5,600,000 Series 1 Warrants outstanding.

Debt_Tables

Debt (Tables)	9 Months Ended
	Oct. 31, 2014
Debt [Abstract]	'
Schedule Of Debt	'
	(in thousands)	31-Oct-14		31-Jan-14
	5% convertible note	$	134,200	$	129,290
	TUSA credit facility		33,000		183,000
	RockPile credit facility		51,616		21,515
	Other notes and mortgages payable		10,175		9,403
	TUSA 6.75% notes		450,000		-
	Total debt		678,991		343,208
	Less current portion of debt:
	RockPile credit facility		-		-8,450
	Other notes and mortgages payable		-416		-401
	Total long-term debt	$	678,575	$	334,357

Derivative_Instruments_Tables

Derivative Instruments (Tables)	9 Months Ended
	Oct. 31, 2014
Derivative Instruments [Abstract]	'
Schedule Of Derivative Instruments In Statement Of Financial Position, Fair Value	'
					As of October 31, 2014
	Underlier		Balance Sheet Classification		Gross Amount of Recognized Assets (Liabilities)			Gross Amount of Offset		Net Amount of Assets (Liabilities)
	Crude oil derivative contracts		Current Assets		$	18,918		$	-	$	18,918
	Crude oil derivative contracts		Long-term assets		$	449		$	-	$	449
	Equity investment derivatives		Equity investment		$	3,612		$	-	$	3,612
					As of January 31, 2014
	Underlier		Balance Sheet Classification		Gross Amount of Recognized Assets (Liabilities)			Gross Amount of Offset		Net Amount of Assets (Liabilities)
	Crude oil derivative contracts		Current assets		$	1,066		$	-111	$	955
	Crude oil derivative contracts		Long-term assets		$	1,192		$	-	$	1,192
	Equity investment derivatives		Equity investment		$	39,734		$	-	$	39,734
Summary Of Derivative Instruments	'
	Term End Date		Contract Type		Basis (1)		Quantity (Bbl/d)		Weighted Average Put Strike	Weighted Average Call Strike
	Fiscal Year 2015		Collar		NYMEX		5,899		$87.40	$99.90
	Fiscal Year 2016		Collar		NYMEX		4,356		$86.85	$98.06
		-1		“NYMEX” refers to West Texas Intermediate crude oil prices at Cushing, Oklahoma as quoted on the New York Mercantile Exchange.

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	9 Months Ended
	Oct. 31, 2014
Fair Value Measurements [Abstract]	'
Schedule Of Fair Value, Assets And Liabilities Measured On Recurring Basis	'
			As of October 31, 2014
	(in thousands)		Level 1		Level 2		Level 3		Total
	Assets:
	Equity investment derivative assets		$	-	$	-	$	3,612	$	3,612
	Commodity derivative assets		$	-	$	19,367	$	-	$	19,367
	Liabilities:
	RockPile earn-out liability		$	-	$	-1,818	$	-	$	-1,818
			As of January 31, 2014
	(in thousands)		Level 1		Level 2		Level 3		Total
	Assets:
	Equity investment derivative assets		$	-	$	-	$	39,734	$	39,734
	Commodity derivative assets		$	-	$	2,147	$	-	$	2,147
	Liabilities:
	RockPile earn-out liability		$	-	$	-1,739	$	-	$	-1,739
Rollforward Of Level 3 Financial Liabilities	'
	(in thousands)		Class A Trigger Units		Warrants (1)
	Beginning balance, January 31, 2014		$	38,091	$	1,696
	Net unrealized gain			1,746		1,916
	Conversion to Class A units			-39,837		-
	Ending balance, October 31, 2014		$	-	$	3,612
		-1		Includes Caliber Class A (Series 1 through Series 4) Warrants.
Summary Of Fair Value Of Financial Instruments	'
			October 31, 2014				31-Jan-14
			Carrying		Estimated		Carrying		Estimated
			Value		Fair Value		Value		Fair Value
	(in thousands)
	5% Convertible note		$	134,200	$	183,200	$	129,290	$	169,200
	Revolving credit facilities			84,616		84,616		196,065		196,065
	Other notes and mortgages payable			9,759		9,759		9,002		9,002
	TUSA 6.75% notes			450,000		398,300		-		-

Capital_Stock_Tables

Capital Stock (Tables)	9 Months Ended
	Oct. 31, 2014
Capital Stock [Abstract]	'
Non-Cash Stock-Based Compensation Cost	'
			Three Months Ended October 31,
			2014			2013
	(in thousands)
	Restricted stock units		$	1,298		$	2,059
	Stock options			627			648
	RockPile stock based compensation related to Series B Units			146			148
				2,071			2,855
	Less amounts capitalized to oil and natural gas properties			-244			-398
	Compensation expense		$	1,827		$	2,457
			Nine Months Ended October 31,
			2014			2013
	(in thousands)
	Restricted stock units		$	4,572		$	5,419
	Stock options			1,600			648
	RockPile stock based compensation related to Series B Units			363			458
				6,535			6,525
	Less amounts capitalized to oil and natural gas properties			-893			-1,036
	Compensation expense		$	5,642		$	5,489
Restricted Stock Units Outstanding	'
			Number of Shares		Weighted- Average Award Date Fair Value
	Restricted stock units outstanding - January 31, 2014		2,875,624		$	6.75
	Units granted		1,380,200		$	9.67
	Units forfeited		-330,171		$	7.15
	Units that vested		-922,393		$	7.18
	Restricted stock units outstanding - October 31, 2014		3,003,260		$	7.84
Stock Option Valuation Assumptions	'
	Risk free rate			1.06%
	Dividend yield			-
	Expected volatility			54%
	Weighted average expected stock option life (years)			3.0
Stock Options Outstanding	'
			Number of Shares		Weighted Average Exercise Price
	Options outstanding - January 31, 2014 (108,333 exercisable)		6,108,333		$	11.07
	Options forfeited		-		$	-
	Options exercised		-		$	-
	Options granted		700,000		$	14.00
	Options outstanding - October 31, 2014 (708,333 exercisable)		6,808,333		$	11.37
Stock Options Outstanding By Exercise Price	'
					Remaining
	Exercise Price				Contractual Life		Number of shares
	per Share				(years)		Outstanding		Exercisable
	$	1.25			0.08			108,333		108,333
	$	7.50			8.68			750,000		75,000
	$	8.50			8.68			750,000		75,000
	$	10.00			8.68			1,500,000		150,000
	$	12.00			8.68			1,500,000		150,000
	$	12.00			6.86			233,333		-
	$	14.00			6.86			233,333		-
	$	15.00			8.68			1,500,000		150,000
	$	16.00			9.87			233,334		-
								6,808,333		708,333
	Weighted average exercise price per share						$	11.37	$	9.72
	Weighted average remaining contractual life							8.46		7.36
Summary Of Series B Unit Activity	'
		Series		Series		Series		Series	Total
		B-1 units		B-2 units		B-3 units		B-4 units
	Units outstanding - January 31, 2014	3,100,000		60,000		910,000		-	4,070,000
	Units forfeited	-		-		-		-	-
	Units redeemed	-180,000		-		-		-	-180,000
	Units granted	-		-		-		1,412,000	1,412,000
	Units outstanding - October 31, 2014	2,920,000		60,000		910,000		1,412,000	5,302,000
	Vested	2,386,667		30,000		188,000		-	2,604,667
	Unvested	533,333		30,000		722,000		1,412,000	2,697,333

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	9 Months Ended
	Oct. 31, 2014
Earnings Per Share [Abstract]	'
Computations Of Basic And Diluted Net Loss Per Share	'
		For the Three Months Ended				For the Nine Months Ended
		October 31,				October 31,
	(in thousands, except per share data)	2014		2013		2014		2013
	Net income attributable to common stockholders	$	25,398	$	47,221	$	54,492	$	59,232
	Effect of 5% Convertible Note conversion		919		881		2,852		2,503
	Net income attributable to common stockholders after effect of debt conversion		26,317		48,102		57,344		61,735
	Basic weighted average common shares outstanding		85,242		79,059		85,769		62,817
	Effect of dilutive securities		17,712		16,983		17,652		16,048
	Diluted weighted average common shares outstanding		102,954		96,042		103,421		78,865
	Basic net income per share	$	0.30	$	0.60	$	0.64	$	0.94
	Diluted net income per share	$	0.26	$	0.50	$	0.55	$	0.78

Recovered_Sheet1

Supplemental Disclosures of Cash Flow Information (Tables)	9 Months Ended
	Oct. 31, 2014
Supplemental Disclosures of Cash Flow Information [Abstract]	'
Schedule of Supplemental Cash Flow Disclosures	'
		For the Nine Months Ended
		October 31,
	(in thousands)	2014		2013
	Cash paid during the period for:
	Interest expense	$	5,672	$	2,260
	Income taxes	$	550	$	-
	Non-cash investing activities:
	Additions (reductions) to oil and natural gas properties through:
	Increased accounts payable and accrued liabilities	$	103,415	$	28,874
	Issuance of common stock	$	-	$	2,435
	Capitalized stock based compensation	$	893	$	1,036
	Change in asset retirement obligations	$	1,519	$	608
	Capitalized interest	$	3,422	$	1,956
	Acquisition of oilfield services equipment through notes payable and liabilities	$	-	$	2,262
	Non-cash financing activities:
	Notes payable issued for redemption of RockPile B units	$	1,041	$	-

Recovered_Sheet2

Significant Changes In Proved Oil And Natural Gas Reserves (Tables)	9 Months Ended
	Oct. 31, 2014
Significant Changes In Proved Oil And Natural Gas Reserves (Abstract)	'
Proved Oil And Natural Gas Reserves	'
		% of	31-Oct-14				January 31,
		Reserves	Oil	Gas	NGL		2014
	Reserve Category	(Mboe)	(Mbbls)	(MMcf)	(Mbbls)	Mboe	Mboe
	Proved Developed	57%	26,816	22,242	2,072	32,595	16,995
	Proved Undeveloped	43%	19,605	16,407	2,185	24,525	23,319
	Total Proved	100%	46,421	38,649	4,257	57,120	40,314

Segment_Reporting_Narrative_De

Segment Reporting (Narrative) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Oct. 31, 2014	Oct. 31, 2013	Oct. 31, 2014	Oct. 31, 2013
			segment
Segment Reporting [Abstract]	'	'	'	'
Number of reportable segments	'	'	2	'
Deferred Revenue	$2.80	$0.40	$6	$3.70
Deferred gross profit	$0.70	$0.40	$1.50	$1.70

Segment_Reporting_Schedule_Of_

Segment Reporting (Schedule Of Segment Reporting) (Details) (USD $)	3 Months Ended			9 Months Ended
In Thousands, unless otherwise specified	Oct. 31, 2014		Oct. 31, 2013	Oct. 31, 2014		Oct. 31, 2013	Jan. 31, 2014
Revenues:	'		'	'		'	'
Oil, natural gas and natural gas liquids sales	$80,139		$55,477	$221,479		$111,176	'
Oilfield services for third parties	94,057		33,072	194,488		62,061	'
Total revenues	174,196		88,549	415,967		173,237	'
Expenses:	'		'	'		'	'
Production taxes and other lease operating	16,091		10,604	42,403		22,013	'
Gathering, transportation and processing	4,380		1,443	11,915		1,549	'
Depreciation and amortization	32,581		18,609	80,465		37,000	'
Accretion of asset retirement obligations	149		983	324		1,000	'
Cost of oilfield services	70,857		29,164	142,121		53,042	'
Stock-based compensation	1,827		2,457	5,642		5,489	'
Other general and administrative	14,966		8,129	38,643		18,682	'
Total operating expenses	140,851		71,389	321,513		138,775	'
Income (loss) from operations	33,345		17,160	94,454		34,462	'
Other income (expense), net	11,353		36,030	-312		30,739	'
NET INCOME (LOSS) BEFORE INCOME TAXES	44,698		53,190	94,142		65,201	'
Net oil and natural gas properties	1,067,361		'	1,067,361		'	682,787
Oilfield services equipment - net	80,114		'	80,114		'	46,586
Other property and equipment - net	32,579		'	32,579		'	24,507
Total assets	1,550,371	[1]	'	1,550,371	[1]	'	1,027,584
Total liabilities	1,014,631		'	1,014,631		'	504,422
Cash and equivalents	53,236		'	53,236		'	81,750
Equity investment	74,124		'	74,124		'	68,536
Caliber Midstream LP [Member]	'		'	'		'	'
Expenses:	'		'	'		'	'
Equity investment	74,124		'	74,124		'	68,536
Eliminations [Member]	'		'	'		'	'
Revenues:	'		'	'		'	'
Oilfield services for third parties	-2,753		-426	-5,972		-3,719	'
Total revenues	-49,694		-33,107	-113,199		-75,835	'
Expenses:	'		'	'		'	'
Depreciation and amortization	-1,791		-1,020	-4,600		-2,455	'
Cost of oilfield services	-31,905		-20,675	-73,219		-46,288	'
Total operating expenses	-33,696		-21,695	-77,819		-48,743	'
Income (loss) from operations	-15,998		-11,412	-35,380		-27,092	'
Other income (expense), net	-658		-384	-1,469		-1,677	'
NET INCOME (LOSS) BEFORE INCOME TAXES	-16,656		-11,796	-36,849		-28,769	'
Net oil and natural gas properties	-84,941		'	-84,941		'	'
Total assets	-109,955	[1]	'	-109,955	[1]	'	'
Total liabilities	-18,974		'	-18,974		'	'
Intersegment Revenues [Member] | Eliminations [Member]	'		'	'		'	'
Revenues:	'		'	'		'	'
Total revenues	-46,941		-32,681	-107,227		-72,116	'
Exploration and Production [Member]	'		'	'		'	'
Revenues:	'		'	'		'	'
Oil, natural gas and natural gas liquids sales	80,139		55,477	221,479		111,176	'
Total revenues	80,139		55,477	221,479		111,176	'
Expenses:	'		'	'		'	'
Production taxes and other lease operating	16,091		10,604	42,403		22,013	'
Gathering, transportation and processing	4,380		1,443	11,915		1,549	'
Depreciation and amortization	27,998		16,829	70,049		33,558	'
Accretion of asset retirement obligations	149		983	324		1,000	'
Stock-based compensation	93		328	832		897	'
Other general and administrative	4,230		2,594	11,450		5,844	'
Total operating expenses	52,941		32,781	136,973		64,861	'
Income (loss) from operations	27,198		22,696	84,506		46,315	'
Other income (expense), net	12,263		1,553	1,292		-1,083	'
NET INCOME (LOSS) BEFORE INCOME TAXES	39,461		24,249	85,798		45,232	'
Net oil and natural gas properties	1,152,302		'	1,152,302		'	'
Other property and equipment - net	6,714		'	6,714		'	'
Total assets	1,338,162	[1]	'	1,338,162	[1]	'	'
Total liabilities	763,964		'	763,964		'	'
Oilfield Services [Member]	'		'	'		'	'
Revenues:	'		'	'		'	'
Oilfield services for third parties	96,810		33,498	200,460		65,780	'
Total revenues	143,751		66,179	307,687		137,896	'
Expenses:	'		'	'		'	'
Depreciation and amortization	6,249		2,700	14,619		5,667	'
Cost of oilfield services	102,762		49,839	215,340		99,330	'
Stock-based compensation	146		148	363		458	'
Other general and administrative	7,310		3,150	17,660		7,576	'
Total operating expenses	116,467		55,837	247,982		113,031	'
Income (loss) from operations	27,284		10,342	59,705		24,865	'
Other income (expense), net	-695		-242	-1,869		-611	'
NET INCOME (LOSS) BEFORE INCOME TAXES	26,589		10,100	57,836		24,254	'
Oilfield services equipment - net	80,114		'	80,114		'	'
Other property and equipment - net	23,946		'	23,946		'	'
Total assets	225,924	[1]	'	225,924	[1]	'	'
Total liabilities	131,445		'	131,445		'	'
Oilfield Services [Member] | Intersegment Revenues [Member]	'		'	'		'	'
Revenues:	'		'	'		'	'
Total revenues	46,941		32,681	107,227		72,116	'
Corporate And Other [Member]	'		'	'		'	'
Expenses:	'		'	'		'	'
Depreciation and amortization	125		100	397		230	'
Stock-based compensation	1,588		1,981	4,447		4,134	'
Other general and administrative	3,426		2,385	9,533		5,262	'
Total operating expenses	5,139		4,466	14,377		9,626	'
Income (loss) from operations	-5,139		-4,466	-14,377		-9,626	'
Other income (expense), net	443		35,103	1,734		34,110	'
NET INCOME (LOSS) BEFORE INCOME TAXES	-4,696		30,637	-12,643		24,484	'
Other property and equipment - net	1,919		'	1,919		'	'
Total assets	96,240	[1]	'	96,240	[1]	'	'
Total liabilities	138,196		'	138,196		'	'
Cash and equivalents	$14,100		'	$14,100		'	'
[1]	Our Corporate and Other total assets consist primarily of cash and cash equivalents of $14.1 million and our investment in Caliber of $74.1 million, in addition to the Company’s investment in subsidiaries the results of which are subsequently eliminated.

Property_And_Equipment_Narrati

Property And Equipment (Narrative) (Details) (USD $)

3 Months Ended

9 Months Ended

0 Months Ended

9 Months Ended

1 Months Ended

3 Months Ended

9 Months Ended

Oct. 31, 2014

Oct. 31, 2013

Oct. 31, 2014

Oct. 31, 2013

Oct. 31, 2014

Oct. 31, 2014

Oct. 31, 2014

Jun. 06, 2014

Oct. 31, 2014

Jun. 06, 2014

Jun. 30, 2014

Oct. 31, 2014

Oct. 31, 2014

Oilfield Service Equipment [Member]

Oilfield Service Equipment In Service [Member]

Oilfield Service Equipment Not Yet Placed In Service [Member]

Oil And Gas Property [Member]

Oil And Gas Property [Member]

Oil And Gas Property [Member]

Marathon Oil And Gas [Member]

Marathon Oil And Gas [Member]

Marathon Oil And Gas [Member]

acre

acre

Property, Plant and Equipment [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of acres purchased

'

'

'

'

'

'

'

'

'

4,600

41,100

'

'

Total consideration to purchase oil and gas properties

'

'

'

'

'

'

'

$34,500,000

$454,600,000

'

$90,400,000

'

'

Pre-closing adjustment

'

'

'

'

'

'

'

'

'

500,000

9,600,000

'

'

Pro forma depreciation, amortization and accretion expense

'

3,700,000

3,400,000

14,100,000

'

'

'

'

'

'

'

'

'

Capitalized internal costs for property acquisition

1,200,000

1,000,000

3,600,000

2,600,000

'

'

'

'

'

'

'

'

'

Depreciable asset, gross

'

'

'

'

41,300,000

32,800,000

8,500,000

'

'

'

'

'

'

Acquisition Costs

'

'

'

'

'

'

'

'

'

'

'

'

1,300,000

Revenues

174,196,000

88,549,000

415,967,000

173,237,000

'

'

'

'

'

'

'

5,200,000

7,300,000

Net income for the period

$25,398,000

$47,221,000

$54,492,000

$59,232,000

'

'

'

'

'

'

'

$1,600,000

$2,700,000

Property_And_Equipment_Schedul

Property And Equipment (Schedule Of Purchase Price Allocation Of Oil And Natural Gas Property Acquisitions) (Details) (Marathon Oil And Gas [Member], USD $)	1 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014
Property, Plant and Equipment [Line Items]	'
Total consideration given	$90,400
Preliminary [Member]	'
Property, Plant and Equipment [Line Items]	'
Cash	90,352
Total consideration given	90,352
Proved properties	71,044
Unproved properties	20,262
Total oil and natural gas properties	91,306
Accounts payable	-469
Asset retirement obligation assumed	-485
Fair value of net assets acquired	$90,352

Property_And_Equipment_Schedul1

Property And Equipment (Schedule of Pro Forma Financial Information) (Details) (Kodiak Oil And Gas, Marathon Oil And Gas [Member], USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Oct. 31, 2014	Oct. 31, 2013	Oct. 31, 2014	Oct. 31, 2013
Kodiak Oil And Gas, Marathon Oil And Gas [Member]	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'
Operating revenues	$174,196	$102,310	$427,708	$219,467
Net income	$25,398	$52,305	$57,110	$75,913
Earnings (loss) per common share, basic	$0.30	$0.66	$0.67	$1.21
Earnings (loss) per common share, diluted	$0.26	$0.55	$0.58	$0.99
Weighted average common shares outstanding, basic	85,242	79,059	85,769	62,817
Weighted average common shares outstanding, diluted	102,954	96,042	103,421	78,865

Equity_Investment_Narrative_De

Equity Investment (Narrative) (Details) (USD $)	Oct. 31, 2014	Jan. 31, 2014	Jun. 30, 2014	Oct. 31, 2014	Jan. 31, 2014	Jun. 30, 2014	Jun. 29, 2014	Oct. 31, 2014
In Thousands, except Share data, unless otherwise specified			Class A Triggering Units [Member]	Caliber Midstream LP [Member]	Caliber Midstream LP [Member]	Caliber Midstream LP [Member]	Caliber Midstream LP [Member]	Caliber Midstream LP [Member]
						Class A Triggering Units [Member]	Class A Triggering Units [Member]	Series 1 Warrants [Member]
Schedule of Equity Method Investments [Line Items]	'	'	'	'	'	'	'	'
Ownership interest	'	'	'	'	'	32.00%	30.00%	'
Equity investment, number of units vested	'	'	'	'	'	4,000,000	'	'
Number of units converted	'	'	1,600,000	'	'	'	'	'
Equity method investments, warrants received	'	'	'	'	'	'	'	5,600,000	[1]
Equity investment	$74,124	$68,536	'	$74,124	$68,536	'	'	'
[1]	On June 30, 2014, the 1.6 million Class A Trigger Unit Warrants then outstanding automatically converted into Series 1 Warrants upon the Company’s vesting of the Class A Trigger Units, resulting in an aggregate of 5,600,000 Series 1 Warrants outstanding.

Equity_Investment_Schedule_Of_

Equity Investment (Schedule Of Equity Investment In Caliber) (Details) (USD $)	Oct. 31, 2014	Jan. 31, 2014	Oct. 31, 2014	Oct. 31, 2014		Oct. 31, 2014		Oct. 31, 2014	Oct. 31, 2014	Oct. 31, 2014
In Thousands, except Share data, unless otherwise specified			Caliber Midstream LP [Member]	Caliber Midstream LP [Member]		Caliber Midstream LP [Member]		Caliber Midstream LP [Member]	Caliber Midstream LP [Member]	Caliber Midstream LP [Member]
				Class A Triggering Units [Member]		Series 1 Warrants [Member]		Series 2 Warrants [Member]	Series 3 Warrants [Member]	Series 4 Warrants [Member]
Schedule of Equity Method Investments [Line Items]	'	'	'	'		'		'	'	'
Equity investment, Beginning balance	$74,124	$68,536	$68,536	'		'		'	'	'
Equity method investments, Class A Units received	'	'	'	4,000,000	[1]	'		'	'	'
Equity method investments, warrants received	'	'	'	'		5,600,000	[2]	2,400,000	3,000,000	2,000,000
Increase (decrease) in equity method investment	'	'	'	1,746	[1]	2,214	[2]	-158	-87	-53
Equity investment share of net income for the period before intra-company profit elimination	'	'	1,926	'		'		'	'	'
Equity investment, Ending balance	$74,124	$68,536	$74,124	'		'		'	'	'
[1]	The change in value was prior to the vesting of the Class A Trigger Units into Class A Units on June 30, 2014.
[2]	On June 30, 2014, the 1.6 million Class A Trigger Unit Warrants then outstanding automatically converted into Series 1 Warrants upon the Company’s vesting of the Class A Trigger Units, resulting in an aggregate of 5,600,000 Series 1 Warrants outstanding.

Debt_Schedule_Of_Debt_Details

Debt (Schedule Of Debt) (Details) (USD $)	Oct. 31, 2014	Jan. 31, 2014
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'	'
5% convertible note	$134,200	$129,290
Other notes and mortgages payable	10,175	9,403
Other Notes Payable	10,175	9,403
TUSA 6.75%	450,000	'
Total debt	678,991	343,208
Total long-term debt	678,575	334,357
TUSA Senior Notes [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt instrument, interest rate	6.75%	'
Convertible Note [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt instrument, interest rate	5.00%	5.00%
TUSA [Member]	'	'
Debt Instrument [Line Items]	'	'
Credit facility	33,000	183,000
Rockpile [Member]	'	'
Debt Instrument [Line Items]	'	'
Credit facility	51,616	21,515
Less current portion of credit facility	'	-8,450
Other notes and mortgages payable	($416)	($401)

Debt_5_Convertible_Note_Narrat

Debt (5% Convertible Note Narrative) (Details) (Convertible Note [Member], USD $)	9 Months Ended
	Oct. 31, 2014	Jan. 31, 2014
Convertible Note [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt instrument, sale date	31-Jul-12	'
Debt instrument, face amount	$120,000,000	'
Debt instrument, interest rate	5.00%	5.00%
Convertible note, conversion price	$8	'
Convertible date	16-Nov-12	'
Accrued interest	$14,200,000	'

Debt_TUSA_Credit_Facility_Narr

Debt (TUSA Credit Facility Narrative) (Details) (USD $)

Oct. 31, 2014

Oct. 31, 2014

Nov. 25, 2014

Nov. 25, 2014

Nov. 25, 2014

Nov. 25, 2014

Oct. 31, 2014

Oct. 31, 2014

Oct. 31, 2014

Oct. 31, 2014

Oct. 31, 2014

Oct. 31, 2014

TUSA Senior Notes [Member]

TUSA [Member]

TUSA [Member]

TUSA [Member]

Minimum [Member]

Maximum [Member]

Federal Funds Rate [Member]

Eurodollar Rate Plus 1% [Member]

Eurodollar Rate Plus 1% [Member]

Eurodollar Rate Plus 1% [Member]

Eurodollar [Member]

Eurodollar [Member]

Subsequent Event [Member]

Letter of Credit [Member]

TUSA [Member]

TUSA [Member]

TUSA [Member]

TUSA [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Subsequent Event [Member]

Letter of Credit [Member]

Letter of Credit [Member]

TUSA [Member]

TUSA [Member]

TUSA [Member]

TUSA [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Line of Credit Facility [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility, maximum borrowing capacity

'

'

$1,000,000,000

'

'

'

'

'

'

'

'

'

Letter of credit sublimit

'

'

15,000,000

'

'

'

'

'

'

'

'

'

Credit agreement borrowing base

'

'

435,000,000

'

'

'

'

'

'

'

'

'

Credit facility, margin on dollar amount based on usage

'

'

'

'

'

'

'

'

0.50%

1.50%

1.50%

2.50%

Credit facility, basis spread on interest rate

'

'

'

'

'

'

0.50%

1.00%

'

'

'

'

Credit facility, fronting fee percentage

'

'

'

0.13%

'

'

'

'

'

'

'

'

Line of Credit Facility, Commitment Fee Amount

'

'

'

$500

'

'

'

'

'

'

'

'

Credit facility, commitment fee percentage

'

'

'

'

0.38%

0.50%

'

'

'

'

'

'

Credit facility, ratio of current assets to current liabilities defined by credit facility

'

1

'

'

'

'

'

'

'

'

'

'

Credit facility, ratio of consolidated debt to consolidated EBITDAX

'

4

'

'

'

'

'

'

'

'

'

'

Percentage of Oil and Gas Interests Used For Collateral

'

'

80.00%

'

'

'

'

'

'

'

'

'

Debt instrument, interest rate

6.75%

'

'

'

'

'

'

'

'

'

'

'

Debt_Second_Lien_Credit_Facili

Debt (Second Lien Credit Facility Narrative) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Oct. 31, 2014	Jun. 27, 2014
TUSA Senior Notes [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Debt instrument, interest rate	6.75%	'
Second Lien Credit Facility [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Credit facility, maximum borrowing capacity	'	$60
Credit facility, maturity date	16-Oct-19	'
LIBOR [Member] | Second Lien Credit Facility [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Credit facility, basis spread on interest rate	7.00%	'
Base Rate [Member] | Second Lien Credit Facility [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Credit facility, basis spread on interest rate	6.00%	'

Debt_Rockpile_Debt_Narrative_D

Debt (Rockpile Debt Narrative) (Details) (USD $)

Oct. 31, 2014

Jan. 31, 2014

Oct. 31, 2014

Mar. 25, 2014

Jan. 31, 2014

Nov. 13, 2014

Oct. 31, 2014

Oct. 31, 2014

Oct. 31, 2014

Oct. 31, 2014

Nov. 13, 2014

Oct. 31, 2014

Mar. 25, 2014

Oct. 31, 2014

Oct. 31, 2014

Oct. 31, 2014

Oct. 31, 2014

Oct. 31, 2014

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Minimum [Member]

Minimum [Member]

Minimum [Member]

Subsequent Event [Member]

Federal Funds Rate [Member]

Eurodollar Rate Plus 1% [Member]

Letter of Credit [Member]

Senior Secured Revolving Credit Facility [Member]

Senior Secured Revolving Credit Facility [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Subsequent Event [Member]

Eurodollar Rate Plus 1% [Member]

Eurodollar [Member]

Eurodollar Rate Plus 1% [Member]

Eurodollar [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility, maximum borrowing capacity

'

'

'

$100,000,000

'

$200,000,000

'

'

'

$100,000,000

$150,000,000

'

$150,000,000

'

'

'

'

'

Line Of Credit Facility Accordion Feature

'

'

'

'

'

50,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility, basis spread on interest rate

'

'

'

'

'

'

0.50%

1.00%

'

'

'

'

'

'

'

'

'

'

Credit facility, margin on dollar amount based on usage

'

'

'

'

'

'

'

'

'

'

'

'

'

2.25%

3.25%

'

1.50%

2.50%

Commitment fee percentage

'

'

'

'

'

'

'

'

0.13%

'

'

0.50%

'

'

'

0.38%

'

'

Credit facility, interest rate at period end

'

'

3.39%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ratio of consolidated debt to EBITDA

'

'

'

'

'

'

'

'

'

'

'

2.75

'

'

'

'

'

'

Ratio of Adjusted EBITDA to Fixed Charges

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.25

'

'

Carrying value of debt

678,991,000

343,208,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument, maturity date

'

'

'

'

'

'

'

'

'

25-Mar-19

'

'

'

'

'

'

'

'

Credit facility

'

'

$51,616,000

'

$21,515,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt_TUSA_675_Notes_Narrative_

Debt (TUSA 6.75% Notes Narrative) (Details) (TUSA Senior Notes [Member], USD $)	9 Months Ended
	Oct. 31, 2014
Debt Instrument [Line Items]	'
Debt instrument, issuance date	18-Jul-14
Debt instrument, maturity date	15-Jul-22
Debt instrument, face amount	$450,000,000
Debt instrument, interest rate	6.75%
Offering costs	$10,500,000
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%

Derivative_Instruments_Narrati

Derivative Instruments (Narrative) (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Share data, unless otherwise specified	Oct. 31, 2014	Oct. 31, 2013	Oct. 31, 2014	Oct. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Gain (loss) from commodity derivatives	$19,822	$2,123	$13,445	($1,064)
Gain (loss) on equity investment derivative	742	35,832	3,662	35,832
Class A Trigger Unit Warrant [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Equity investment, number of units vested	4,000,000	'	4,000,000	'
Gain (loss) on equity investment derivative	'	'	1,700	'
Series 1, Series 2, Series 3 and Series 4 Warrants [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Expected term of warrants	'	'	'12 years	'
Equity Method Investments, warrant floor price	'	'	$5	'
Increase (decrease) in equity method investment	$700	'	$2,000	'
Caliber Midstream LP [Member] | Class A Units [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Equity method investments, Class A units exercise price	'	'	$10.43	'
Equity method investments, Class A units decrease in exercise price	$0.23	'	'	'
Equity method investments, Class A units increase in exercise price	'	'	$0.43	'

Derivative_Instruments_Schedul

Derivative Instruments (Schedule Of Derivative Instruments In Statement Of Financial Position, Fair Value) (Details) (USD $)	Oct. 31, 2014	Jan. 31, 2014
In Thousands, unless otherwise specified
Commodity Derivative [Member] | Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	$18,918	$1,066
Derivative Asset, Fair Value, Gross Liability	'	-111
Derivative Assets	18,918	955
Commodity Derivative [Member] | Long-Term Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	449	1,192
Derivative Asset, Fair Value, Gross Liability	'	'
Derivative Assets	449	1,192
Equity Investment Derivative [Member] | Equity Investment [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	3,612	39,734
Derivative Asset, Fair Value, Gross Liability	'	'
Derivative Assets	$3,612	$39,734

Derivative_Instruments_Summary

Derivative Instruments (Summary Of Derivative Instruments) (Details)	9 Months Ended
	Oct. 31, 2014
Fiscal 2015 Collar [Member]	'
Derivative [Line Items]	'
End date	'Fiscal Year 2015
Basis	'NYMEX	[1]
Quantity, (bopd)	5,899
Put strike price	87.4
Call strike price	99.9
Fiscal 2016 Collar [Member]	'
Derivative [Line Items]	'
End date	'Fiscal Year 2016
Basis	'NYMEX	[1]
Quantity, (bopd)	4,356
Put strike price	86.85
Call strike price	98.06
[1]	“NYMEX” refers to West Texas Intermediate crude oil prices at Cushing, Oklahoma as quoted on the New York Mercantile Exchange.

Fair_Value_Measurements_Schedu

Fair Value Measurements (Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis) (Details) (Fair Value, Measurements, Recurring [Member], USD $)	9 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Oct. 31, 2014	Jan. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative assets	$3,612	$39,734
Earn-out liability	-1,818	-1,739
Commodity Derivative [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative assets	19,367	2,147
Fair Value, Inputs, Level 2 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Earn-out liability	-1,818	-1,739
Fair Value, Inputs, Level 2 [Member] | Commodity Derivative [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative assets	19,367	2,147
Fair Value, Inputs, Level 3 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative assets	$3,612	$39,734

Fair_Value_Measurements_Rollfo

Fair Value Measurements (Rollforward Of Level 3 Financial Assets And Liabilities) (Details) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Oct. 31, 2014	Oct. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Interest paid in-kind	$12,040	$3,936
Class A Triggering Units [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Assets, Beginning Balance	38,091	'
Net unrealized gain	1,746	'
Conversion to Class A units	-39,837	'
Warrants [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Assets, Beginning Balance	1,696	'
Net unrealized gain	1,916	'
Assets, Ending Balance	$3,612	'

Fair_Value_Measurements_Summar

Fair Value Measurements (Summary Of Fair Value Of Financial Instruments) (Details) (USD $)	Oct. 31, 2014	Jan. 31, 2014
In Thousands, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
5% convertible note, carrying value	$134,200	$129,290
5% Convertible note, fair value	183,200	169,200
Revolving credit facilities, carrying value	84,616	196,065
Revolving credit facilities, fair value	84,616	196,065
Other notes and mortgages payable, carrying value	9,759	9,002
Other notes and mortgages payable, fair value	9,759	9,002
TUSA 6.75% notes, carrying value	450,000	'
TUSA 6.75% notes, fair value	$398,300	'
Convertible Note [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Debt instrument, interest rate	5.00%	5.00%
TUSA Senior Notes [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Debt instrument, interest rate	6.75%	'

Commitments_and_Contingencies_

Commitments and Contingencies (Narrative) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Oct. 31, 2014
Commitments and Contingencies [Line Items]	'
Contingent liability for bonus payout to CEO	0
Environmental or other regulatory matters liabilities	0
Caliber Midstream Partners, L.P. [Member]	'
Commitments and Contingencies [Line Items]	'
Percentage bonus payout of gain on sale of subsidiary	5.00%
Rockpile [Member]	'
Commitments and Contingencies [Line Items]	'
Percentage bonus payout of gain on sale of subsidiary	3.50%

Capital_Stock_Narrative_Detail

Capital Stock (Narrative) (Details) (USD $)	9 Months Ended
In Millions, except Share data, unless otherwise specified	Oct. 31, 2014	Feb. 20, 2013
Restricted Stock Units (RSUs) [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Number of shares per vesting unit	1	'
Units granted, number of units	1,380,200	'
Unrecognized compensation	$20.80	'
Unrecognized compensation, recognition period	'2 years 4 months 24 days	'
Employee Stock Option [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Options granted	700,000	'
Unrecognized compensation, recognition period	'3 years 7 months 6 days	'
Unrecognized compensation cost related to stock options	19.3	'
RockPile [Member] | Series B Units [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Maximum shares reserved under Plan	'	6,000,000
Share-based awards vesting period	'5 years	'
Units issued during period	1,412,000	'
Unrecognized compensation cost related to stock options	$2.70	'
RockPile [Member] | Series B-1 Unit [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Redeemed RockPile B-Units	180,000	'
2014 Plan [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Maximum shares reserved under Plan	6,000,000	'
2014 Plan [Member] | Employee Stock Option [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Options granted	700,000	'
Number of vesting installments	3	'
2014 Plan [Member] | Employee Stock Option [Member] | $12.00 [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Options granted	233,333	'
Exercise price per share	$12	'
2014 Plan [Member] | Employee Stock Option [Member] | $14.00 [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Options granted	233,333	'
Exercise price per share	$14	'
2014 Plan [Member] | Employee Stock Option [Member] | $16.00 [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Options granted	233,334	'
Exercise price per share	$16	'
Minimum [Member] | Restricted Stock Units (RSUs) [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Share-based awards vesting period	'1 year	'
Maximum [Member] | Restricted Stock Units (RSUs) [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Share-based awards vesting period	'5 years	'
Common Stock [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Common stock issued, net of shares surrendered for related employee payroll tax withholding for restricted stock units vested	635,999	'
Shares repurchased and retired, shares	4,931,744	'
Average cost per share	$9.07	'

Capital_Stock_NonCash_StockBas

Capital Stock (Non-Cash Stock-Based Compensation Cost) (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Oct. 31, 2014	Oct. 31, 2013	Oct. 31, 2014	Oct. 31, 2013
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'	'	'
Compensation expense before capitalized amount	$2,071	$2,855	$6,535	$6,525
Less amounts capitalized to oil and natural gas properties	-244	-398	-893	-1,036
Stock-based compensation	1,827	2,457	5,642	5,489
Restricted Stock Units (RSUs) [Member]	'	'	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'	'	'
Compensation expense before capitalized amount	1,298	2,059	4,572	5,419
Employee Stock Option [Member]	'	'	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'	'	'
Compensation expense before capitalized amount	627	648	1,600	648
RockPile Stock Based Compensation Related to Series [Member]	'	'	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'	'	'
Compensation expense before capitalized amount	$146	$148	$363	$458

Capital_Stock_Restricted_Stock

Capital Stock (Restricted Stock Units Outstanding) (Details) (Restricted Stock Units (RSUs) [Member], USD $)	9 Months Ended
	Oct. 31, 2014
Restricted Stock Units (RSUs) [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Outstanding, Unvested Beginning Balance	2,875,624
Outstanding, Weighted-Average Award Date Fair Value, Beginning Balance	$6.75
Units granted, number of units	1,380,200
Units granted, Weighted Average Award Date Fair Value	$9.67
Units forfeited	-330,171
Units forfeited, Weighted Average Award Date Fair Value	$7.15
Units that vested, Number of Shares	-922,393
Units that vested, Weighted Average Award Date Fair Value	$7.18
Outstanding, Unvested Ending Balance	3,003,260
Outstanding, Weighted-Average Grant Date Fair Value, Ending Balance	$7.84

Capital_Stock_Stock_Options_Va

Capital Stock (Stock Options Valuation Assumptions) (Details)	9 Months Ended
	Oct. 31, 2014
Capital Stock [Abstract]	'
Risk free rate	1.06%
Expected volatility	54.00%
Weighted average expected stock option life (years)	'3 years

Capital_Stock_Stock_Options_Ou

Capital Stock (Stock Options Outstanding) (Details) (Employee Stock Option [Member], USD $)	9 Months Ended
	Oct. 31, 2014
Employee Stock Option [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Options outstanding, beginning balance	6,108,333
Options forfeited	'
Options exercised	'
Options granted	700,000
Options outstanding, ending balance	6,808,333
Weighted average exercise price, options outstanding beginning balance	$11.07
Weighted average exercise price, options forfeited	'
Weighted average exercise price, options exercised	'
Weighted average exercise price, options granted	$14
Weighted average exercise price, options outstanding ending balance	$11.37
Options exercisable, beginning	108,333
Options exercisable, ending	708,333

Capital_Stock_Stock_Options_Ou1

Capital Stock (Stock Options Outstanding By Exercise Price) (Details) (Employee Stock Option [Member], USD $)	9 Months Ended
	Oct. 31, 2014	Jan. 31, 2014
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'	'
Outstanding options	6,808,333	6,108,333
Number of shares exercisable	708,333	'
Weighted average exercise price per share	$11.37	$11.07
Weighted average remaining contractual life (years)	'8 years 5 months 16 days	'
Weighted average exercise price per share (exercisable)	$9.72	'
Weighted average remaining contractual life (years) (exercisable)	'7 years 4 months 10 days	'
$1.25 [Member]	'	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'	'
Exercise price per share	$1.25	'
Remaining contractual life	'29 days	'
Outstanding options	108,333	'
Number of shares exercisable	108,333	'
$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 8 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 8 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 8 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 8 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 10 months 10 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 10 months 10 days	'
Outstanding options	233,333	'
$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 8 months 5 days	'
Outstanding options	1,500,000	'
Number of shares exercisable	150,000	'
$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 10 months 13 days	'
Outstanding options	233,334	'

Capital_Stock_Summary_Of_Serie

Capital Stock (Summary Of Series B Unit Vesting Status) (Details)	9 Months Ended
	Oct. 31, 2014
Series B Units [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Units outstanding, beginning balance	4,070,000
Units redeemed	-180,000
Units granted	1,412,000
Units outstanding, ending balance	5,302,000
Grants, Number of Vested Units	2,604,667
Grants, Number of Unvested Units	2,697,333
Series B-1 Unit [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Units outstanding, beginning balance	3,100,000
Units redeemed	-180,000
Units outstanding, ending balance	2,920,000
Grants, Number of Vested Units	2,386,667
Grants, Number of Unvested Units	533,333
Series B-2 Unit [Member]	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Units outstanding, beginning balance	60,000
Units outstanding, 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]	'
Units outstanding, beginning balance	910,000
Units outstanding, 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]	'
Units granted	1,412,000
Units outstanding, ending balance	1,412,000
Grants, Number of Unvested Units	1,412,000

Earnings_Per_Share_Narrative_D

Earnings Per Share (Narrative) (Details)	Oct. 31, 2014	Jan. 31, 2014	Oct. 31, 2014	Oct. 31, 2014	Oct. 31, 2014	Oct. 31, 2014
In Millions, unless otherwise specified	Convertible Note [Member]	Convertible Note [Member]	Stock Options [Member]	Stock Options [Member]	Restricted Stock [Member]	Restricted Stock [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'	'	'	'	'
Anitdilutive securities excluded from calculation of diluted net income	'	'	6.7	6.7	0.04	0.08
Debt instrument, interest rate	5.00%	5.00%	'	'	'	'

Earnings_Per_Share_Computation

Earnings Per Share (Computations Of Basic And Diluted Net Loss Per Share) (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Oct. 31, 2014	Oct. 31, 2013	Oct. 31, 2014	Oct. 31, 2013
Earnings Per Share [Abstract]	'	'	'	'
Net income	$25,398	$47,221	$54,492	$59,232
Effect of 5% Convertible Note conversion	919	881	2,852	2,503
Net income attributable to common stockholders after effect of debt conversion	$26,317	$48,102	$57,344	$61,735
Basic weighted average common shares outstanding	85,242	79,059	85,769	62,817
Effect of dilutive securities	17,712	16,983	17,652	16,048
Diluted weighted average common shares outstanding	102,954	96,042	103,421	78,865
Basic net income per share	$0.30	$0.60	$0.64	$0.94
Diluted net income per share	$0.26	$0.50	$0.55	$0.78

Income_Taxes_Narrative_Details

Income Taxes (Narrative) (Details) (USD $)	9 Months Ended
	Oct. 31, 2014
Income Taxes [Abstract]	'
Effective income tax rate	42.10%
Unrecognized tax benefits	$0

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	3 Months Ended		9 Months Ended			3 Months Ended	9 Months Ended
	Oct. 31, 2014	Oct. 31, 2013	Oct. 31, 2014	Oct. 31, 2013	14-May-14	Oct. 31, 2014	Oct. 31, 2014	Oct. 31, 2014	14-May-14
			item		Caliber Fresh Water [Member]	Caliber North Dakota LLC [Member]	Caliber North Dakota LLC [Member]	Caliber North Dakota LLC [Member]	Caliber Midstream Fresh Water Partners LLC [Member]
								Scenario, Forecast [Member]	Caliber Fresh Water [Member]
								item
Related Party Transaction [Line Items]	'	'	'	'	'	'	'	'	'
Number of midstream agreements with Caliber North Dakota LLC	'	'	2	'	'	'	'	'	'
Term of midstream agreements with Caliber	'	'	'	'	'	'	'15 years	'	'
Minimum commitment over term of agreements	'	'	'	'	'	$405,000,000	$405,000,000	'	'
Remaining commitment	'	'	'	'	'	375,300,000	375,300,000	'	'
Revenues from related parties	'	'	'	'	'	11,600,000	23,800,000	'	'
Revenues	174,196,000	88,549,000	415,967,000	173,237,000	'	14,400,000	28,000,000	'	'
Reimbursed administrative services from Caliber	'	'	'	'	'	100,000	700,000	'	'
Consideration to purchase oil and gas properties	'	'	'	'	'	'	'	7,500,000	'
Ownership interest	'	'	'	'	'	'	'	'	51.00%
Ownership interest by third party	'	'	'	'	49.00%	'	'	'	'
Number of salt water disposal wells	'	'	'	'	'	'	'	2	'
Proceeds from sale of salt water disposal wells	'	'	$1,500,000	'	'	'	$1,500,000	'	'

Supplemental_Disclosures_Of_Ca1

Supplemental Disclosures Of Cash Flow Information (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Oct. 31, 2014	Oct. 31, 2013	Oct. 31, 2014	Oct. 31, 2013
Supplemental Disclosures of Cash Flow Information [Abstract]	'	'	'	'
Interest expense	'	'	$5,672	$2,260
Income taxes	'	'	550	'
Increased accounts payable and accrued liabilities	'	'	103,415	28,874
Issuance of common stock	'	'	'	2,435
Capitalized stock-based compensation	244	398	893	1,036
Change in asset retirement obligations	'	'	1,519	608
Capitalized interest	'	'	3,422	1,956
Acquisition of oilfield services equipment through notes payable and liabilities	'	'	'	2,262
Notes payable issued for redemption of RockPile B units	'	'	$1,041	'

Significant_Changes_in_Proved_1

Significant Changes in Proved Oil And Natural Gas Reserves (Narrative) (Details)	9 Months Ended	12 Months Ended
	Oct. 31, 2014	Jan. 31, 2014
	item	item
Reserve Quantities [Line Items]	'	'
Productive oil wells, number of wells, net	110.3	50
Percentage of increase (decrease) in productive oil wells, net	121.00%	'
Percentage of increase (decrease) in future development oil wells, net	9.00%	'
Future development wells, number of wells, net	57.2	52.5
Crude Oil Reserves [Member]	'	'
Reserve Quantities [Line Items]	'	'
Industry average, sales price per unit	86.29	93.09
Natural Gas Reserves [Member]	'	'
Reserve Quantities [Line Items]	'	'
Industry average, sales price per unit	5.79	3.99
Natural Gas Liquids [Member]	'	'
Reserve Quantities [Line Items]	'	'
Industry average, sales price per unit	43.23	44.1

Significant_Changes_in_Proved_2

Significant Changes in Proved Oil And Natural Gas Reserves (Proved Oil And Gas Reserves) (Details)	Oct. 31, 2014	Jan. 31, 2014
	MBoe	MBoe
Reserve Quantities [Line Items]	'	'
Proved Developed, Percentage of Reserves	57.00%	'
Proved Developed, (Mboe)	32,595	16,995
Proved Undeveloped, Percentage of Reserves	43.00%	'
Proved Undeveloped, (Mboe)	24,525	23,319
Total Proved, Percentage of Reserves	100.00%	'
Total Proved, (Mboe)	57,120	40,314
Crude Oil Reserves [Member]	'	'
Reserve Quantities [Line Items]	'	'
Proved Developed, Volume	26,816	'
Proved Undeveloped, Volume	19,605	'
Total Proved, Volume	46,421	'
Natural Gas Reserves [Member]	'	'
Reserve Quantities [Line Items]	'	'
Proved Developed, Volume	22,242	'
Proved Undeveloped, Volume	16,407	'
Total Proved, Volume	38,649	'
Natural Gas Liquids [Member]	'	'
Reserve Quantities [Line Items]	'	'
Proved Developed, Volume	2,072	'
Proved Undeveloped, Volume	2,185	'
Total Proved, Volume	4,257	'