Triangle Petroleum (TPLMQ) 10-Q 8 Sep 14 2015 Q2 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	6 Months Ended
	Jul. 31, 2014	Sep. 05, 2014
Document And Entity Information [Abstract]	'	'
Document Type	'10-Q	'
Amendment Flag	'false	'
Document Period End Date	31-Jul-14	'
Document Fiscal Period Focus	'Q2	'
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	'	86,250,905

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Jul. 31, 2014		Jan. 31, 2014
In Thousands, unless otherwise specified
CURRENT ASSETS	'		'
Cash and equivalents	$107,527		$81,750
Accounts receivable:	'		'
Oil, natural gas and natural gas liquids sales	28,505		20,450
Trade	122,382		86,074
Derivative asset	'		955
Deferred tax benefit	321		321
Inventory, deposits and prepaid expenses	5,916		5,331
Total current assets	264,651		194,881
Oil and natural gas properties at cost, using the full cost method of accounting:	'		'
Unproved properties and properties under development, not being amortized	144,023		121,393
Proved properties	924,419		629,051
Total oil and natural gas properties at cost	1,068,442		750,444
Less: accumulated amortization	-109,686		-67,657
Net oil and natural gas properties	958,756		682,787
Oilfield services equipment, net	64,379		46,586
Other property and equipment, net	28,718		24,507
Equity investment	72,337		68,536
Goodwill	1,680		1,680
Intangible assets, net	3,604		3,862
Derivative asset	136		1,192
Other long-term assets	14,193		3,553
Total assets	1,408,454	[1]	1,027,584
CURRENT LIABILITIES	'		'
Accounts payable	72,849		60,016
Accrued liabilities:	'		'
Exploration and development	54,532		34,131
Other	59,137		53,037
Debt	411		8,851
Derivative liability	994		'
Asset retirement obligations	3,400		3,333
Total current liabilities	191,323		159,368
LONG-TERM LIABILITIES	'		'
6.75% senior notes	450,000		'
5% convertible note	132,543		129,290
Borrowings on credit facilities	39,616		196,065
Other notes payable	9,854		9,002
Asset retirement obligations	2,374		1,296
Deferred tax liability	28,062		8,262
Other	1,195		1,139
Total liabilities	854,967		504,422
COMMITMENTS AND CONTINGENCIES (Note 10))	'		'
STOCKHOLDERS' EQUITY	'		'
Common stock, $0.00001 par value, 140,000,000 shares authorized; 86,231,719 and 85,735,827 shares issued and outstanding at July 31, 2014 and January 31, 2014, respectively	'		'
Additional paid-in capital	572,933		571,702
Accumulated deficit	-19,446		-48,540
Accumulated other comprehensive income	'		'
Total stockholders' equity	553,487		523,162
Total liabilities and stockholders' equity	$1,408,454		$1,027,584
[1]	Our Corporate and Other total assets consist primarily of cash and cash equivalents of $64.4 million and our investment in Caliber of $72.3 million, in addition to the Company’s investment in its subsidiaries which are subsequently eliminated.

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Jul. 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	86,231,719	85,735,827
Common stock, shares outstanding	86,231,719	85,735,827
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 and Comprehensive Income (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jul. 31, 2014	Jul. 31, 2013	Jul. 31, 2014	Jul. 31, 2013
REVENUES	'	'	'	'
Oil, natural gas and natural gas liquids sales	$80,506	$34,639	$141,340	$55,699
Oilfield services	61,483	15,755	100,431	28,989
Total revenues	141,989	50,394	241,771	84,688
EXPENSES:	'	'	'	'
Production taxes	8,677	3,919	15,025	6,363
Lease operating expenses	6,698	2,830	11,424	5,046
Gathering, transportation and processing	3,733	69	7,535	106
Depreciation and amortization	26,706	10,918	47,884	18,391
Accretion of asset retirement obligations	41	9	175	17
Oilfield services	43,554	12,692	71,264	23,878
General and administrative:	'	'	'	'
Stock-based compensation	1,807	1,438	3,815	3,033
Salaries and benefits	5,677	4,133	12,794	7,258
Other general and administrative	6,607	1,413	10,883	3,295
Total operating expenses	103,500	37,421	180,799	67,387
INCOME FROM OPERATIONS	38,489	12,973	60,972	17,301
OTHER INCOME (EXPENSE):	'	'	'	'
Gain (loss) on equity investment derivatives	-7,534	'	2,920	'
Loss from commodity derivative activities	-921	-4,399	-6,377	-3,187
Interest expense	-5,385	-1,969	-8,249	-3,441
Income (loss) from equity investment	190	-596	64	'
Interest income	47	43	107	80
Other income	5	747	7	1,257
Total other income (expense)	-13,598	-6,174	-11,528	-5,291
NET INCOME BEFORE INCOME TAXES	24,891	6,799	49,444	12,010
Income tax provision	-10,339	'	-20,350	'
NET INCOME	14,552	6,799	29,094	12,010
Net income per common share outstanding:	'	'	'	'
Basic	$0.17	$0.12	$0.34	$0.22
Diluted	$0.15	$0.12	$0.30	$0.22
Weighted average common shares outstanding:	'	'	'	'
Basic	86,172	56,451	86,064	54,561
Diluted	103,774	57,012	103,511	55,089
COMPREHENSIVE INCOME:	'	'	'	'
Net income attributable to common stockholders	14,552	6,799	29,094	12,010
Total comprehensive income	$14,552	$6,799	$29,094	$12,010

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements Of Cash Flows (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jul. 31, 2014	Jul. 31, 2013
CASH FLOWS FROM OPERATING ACTIVITIES:	'	'
Net income	$29,094	$12,010
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation and amortization	47,884	18,391
Stock-based compensation	3,815	3,033
Interest expense not paid in cash	3,532	2,545
Accretion of asset retirement obligations	175	17
Loss on commodity derivative activities	6,377	3,187
Gain on equity investment derivatives	-2,919	'
Settlements of commodity derivative instruments	-3,372	'
Income from equity investment	64	'
Unrealized income on securities held for investment	'	-990
Deferred income taxes	19,800	'
Accounts receivable:	'	'
Oil and natural gas sales	-8,055	-10,059
Trade	-36,308	-10,329
Inventory, deposits and prepaid expenses	-581	-1,025
Accounts payable and accrued liabilities	2,994	15,101
Asset retirement expenditures	-136	-484
Other	-390	36
Cash provided by operating activities	61,846	31,433
CASH FLOWS FROM INVESTING ACTIVITIES:	'	'
Oil and natural gas property expenditures and acquisitions	-280,847	-130,132
Purchases of oilfield services equipment	-24,579	-15,953
Purchases of other property and equipment	-3,080	-4,318
Equity investment in Caliber Midstream Partners, L.P.	'	-9,000
Other	58	'
Cash used in investing activities	-308,448	-159,403
CASH FLOWS FROM FINANCING ACTIVITIES:	'	'
Proceeds from issuance of common stock	'	55,800
Proceeds from credit facilities	245,116	90,320
Repayments of credit facilities	-410,015	-5,000
Proceeds from notes payable	450,000	5,876
Repayments of notes payable	-199	-1,538
Debt issuance costs	-10,331	'
Cash paid to settle tax on vested restricted stock units	-2,192	-1,225
Cash provided by financing activities	272,379	144,233
NET INCREASE IN CASH AND EQUIVALENTS	25,777	16,263
CASH AND EQUIVALENTS, BEGINNING OF PERIOD	81,750	33,117
CASH AND EQUIVALENTS, END OF PERIOD	$107,527	$49,380

Condensed_Consolidated_Stateme2

Condensed Consolidated Statement Of Stockholders' Equity (USD $)	Common Stock [Member]	Additional Paid-In Capital [Member]	Accumulated Deficit [Member]	Total
In Thousands, except Share data		USD ($)	USD ($)	USD ($)
Balance at Jan. 31, 2014	'	$571,702	($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)	'	-2,192	'	-2,192
Vesting of restricted stock units (net of shares surrendered for taxes), shares	495,892	'	'	'
Redeemed RockPile B-Units	'	-1,041	'	-1,041
Stock-based compensation	'	4,464	'	4,464
Net income for the period	'	'	29,094	29,094
Balance at Jul. 31, 2014	'	$572,933	($19,446)	$553,487
Balance, shares at Jul. 31, 2014	86,231,719	'	'	86,231,719

Description_Of_Business

Description Of Business	6 Months Ended
	Jul. 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 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.
	The Company also holds leasehold interests in acreage in the Maritimes Basin of Nova Scotia.

Basis_Of_Presentation

Basis Of Presentation	6 Months Ended
	Jul. 31, 2014
Basis Of Presentation [Abstract]	'
Basis Of Presentation	'
	2.  BASIS OF PRESENTATION
	These unaudited condensed consolidated financial statements as of July 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.  Note 3 – Summary of Significant Accounting Policies describes our significant accounting policies.
	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, filed with the SEC on April 17, 2014 (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 six months ended
	July 31, 2014, are not necessarily indicative of the operating results for the entire fiscal year ending January 31, 2015.
	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.  See Note 6 - Equity Investment for further discussion.
	Reclassifications
	Certain amounts in the condensed consolidated balance sheet as of January 31, 2014, and in our condensed consolidated statement of operations and comprehensive income for the quarter ended July 31, 2013, have been reclassified to conform to the financial statement presentation for the quarter ended July 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	6 Months Ended
	Jul. 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 May 2014, the Financial Accounting Standards Board issued Accounting Standards Update (“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.
	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 standard discussed above, there are no significant accounting standards applicable to Triangle which have not been adopted.

Segment_Reporting

Segment Reporting	6 Months Ended
	Jul. 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 all operations are in the Williston Basin of the United States.  The Exploration and Production operating segment, consisting of TUSA and several insignificant oil and 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 July 31, 2014 and 2013:
			For the Three Months Ended July 31, 2014
	(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
	Revenues:
	Oil, natural gas and natural gas liquids sales		$	80,506	$	-	$	-	$	-	$	80,506
	Oilfield services for third parties			-		64,093		-		-2,610		61,483
	Intersegment revenues			-		37,962		-		-37,962		-
	Other			-		-		272		-272		-
	Total revenues			80,506		102,055		272		-40,844		141,989
	Expenses:
	Production taxes and other lease operating			15,375		-		-		-		15,375
	Gathering, transportation and processing			3,733		-		-		-		3,733
	Depreciation and amortization			23,439		4,690		186		-1,609		26,706
	Accretion of asset retirement obligations			41		-		-		-		41
	Cost of oilfield services			-		68,867		-		-25,313		43,554
	General and administrative:
	Stock-based compensation			344		127		1,336		-		1,807
	Other general and administrative			4,442		5,251		2,591		-		12,284
	Total operating expenses			47,374		78,935		4,113		-26,922		103,500
	Income (loss) from operations			33,132		23,120		-3,841		-13,922		38,489
	Other income (expense), net			-4,267		-667		-7,580		-1,084		-13,598
	Net income (loss) before income taxes		$	28,865	$	22,453	$	-11,421	$	-15,006	$	24,891
			For the Three Months Ended July 31, 2013
	(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
	Revenues:
	Oil, natural gas and natural gas liquids sales		$	34,639	$	-	$	-	$	-	$	34,639
	Oilfield services for third parties			-		17,137		-		-1,382		15,755
	Intersegment revenues			-		27,148		-		-27,148		-
	Other			-		-		272		-272		-
	Total revenues			34,639		44,285		272		-28,802		50,394
	Expenses:
	Production taxes and other lease operating			6,749		-		-		-		6,749
	Gathering, transportation and processing			69		-		-		-		69
	Depreciation and amortization			10,111		1,600		135		-928		10,918
	Accretion of asset retirement obligations			9		-		-		-		9
	Cost of oilfield services			-		30,370		-		-17,678		12,692
	General and administrative:
	Stock-based compensation			247		99		1,092		-		1,438
	Other general and administrative			1,683		2,446		1,417		-		5,546
	Total operating expenses			18,868		34,515		2,644		-18,606		37,421
	Income (loss) from operations			15,771		9,770		-2,372		-10,196		12,973
	Other income (expense), net			-4,087		-216		-578		-1,293		-6,174
	Net income (loss) before income taxes		$	11,684	$	9,554	$	-2,950	$	-11,489	$	6,799
	The following tables present selected financial information for our operating segments for the six months ended July 31, 2014 and 2013:
			For the Six Months Ended July 31, 2014
	(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
	Revenues:
	Oil, natural gas and natural gas liquids sales		$	141,340	$	-	$	-	$	-	$	141,340
	Oilfield services for third parties			-		103,650		-		-3,219		100,431
	Intersegment revenues			-		59,837		-		-59,837		-
	Other			-		-		449		-449		-
	Total revenues			141,340		163,487		449		-63,505		241,771
	Expenses
	Production taxes and other lease operating			26,449		-		-		-		26,449
	Gathering, transportation and processing			7,535		-		-		-		7,535
	Depreciation and amortization			42,051		8,280		362		-2,809		47,884
	Accretion of asset retirement obligations			175		-		-		-		175
	Cost of oilfield services			-		112,578		-		-41,314		71,264
	General and administrative:
	Stock-based compensation			739		217		2,859		-		3,815
	Other general and administrative			7,220		10,348		6,109		-		23,677
Total operating expenses			84,169		131,423		9,330		-44,123		180,799
Income (loss) from operations			57,171		32,064		-8,881		-19,382		60,972
Other income (expense), net			-10,834		-1,174		1,741		-1,261		-11,528
Net income (loss) before income taxes		$	46,337	$	30,890	$	-7,140	$	-20,643	$	49,444
		As of July 31, 2014
Net oil and natural gas properties		$	1,027,074	$	-	$	-	$	-68,318	$	958,756
Oilfield services equipment - net		$	-	$	64,379	$	-	$	-	$	64,379
Other property and equipment - net		$	1,562	$	20,372	$	6,784	$	-	$	28,718
Total assets (1)		$	1,188,878	$	171,550	$	168,143	$	-120,117	$	1,408,454
Total liabilities		$	659,922	$	89,387	$	136,137	$	-30,479	$	854,967
	-1		Our Corporate and Other total assets consist primarily of cash and cash equivalents of $64.4 million and our investment in Caliber of $72.3 million, in addition to the Company’s investment in its subsidiaries which are subsequently eliminated.
		For the Six Months Ended July 31, 2013
(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
Revenues:
Oil, natural gas and natural gas liquids sales		$	55,699	$	-	$	-	$	-	$	55,699
Oilfield services for third parties			-		32,281		-		-3,292		28,989
Intersegment revenues			-		38,887		-		-38,887		-
Other			-		-		548		-548		-
Total revenues			55,699		71,168		548		-42,727		84,688
Expenses:
Production taxes and other lease operating			11,409		-		-		-		11,409
Gathering, transportation and processing			106		-		-		-		106
Depreciation and amortization			16,729		2,839		258		-1,435		18,391
Accretion of asset retirement obligations			17		-		-		-		17
Cost of oilfield services			-		49,491		-		-25,613		23,878
General and administrative:
Stock-based compensation			569		310		2,154		-		3,033
Other general and administrative			3,250		4,425		2,878		-		10,553
Total operating expenses			32,080		57,065		5,290		-27,048		67,387
Income (loss) from operations			23,619		14,103		-4,742		-15,679		17,301
Other income (expense), net			-2,636		-369		-993		-1,293		-5,291
Net income (loss) before income taxes		$	20,983	$	13,734	$	-5,735	$	-16,972	$	12,010
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 $2.6 million and $1.4 million in oilfield service income for the three month periods ended July 31, 2014 and 2013, respectively, and approximately $3.2 million and $3.3 million in oilfield service income for the six month periods ended July 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 service income against oilfield service revenue and crediting capitalized oil and natural gas properties.
In addition, we deferred approximately $0.6 million and $0.7 million of Caliber gross profit from our share of its income for the three months ended July 31, 2014 and 2013, respectively and approximately $0.8 million and $1.3 million for the six months ended July 31, 2014 and 2013, respectively, associated with services it provided which were capitalized by TUSA, by charging such gross profit against income (loss) from equity investment and crediting capitalized oil and natural gas properties.  See Note 6 - Equity Investment for further discussion.
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	6 Months Ended
	Jul. 31, 2014
Property And Equipment [Abstract]	'
Property And Equipment	'
	5.  PROPERTY AND EQUIPMENT
	Acquisitions
	Kodiak Oil & Gas Property Acquisition
	On August 28, 2013, we acquired from Kodiak Oil & Gas Corporation (“Kodiak”) interests in approximately 5,600 net acres of Williston Basin leaseholds, and related producing properties along with various other related rights, permits, contracts, equipment and other assets located in  McKenzie County, North Dakota for approximately $83.0 million in cash.  Transaction costs related to the acquisition incurred during fiscal year 2014 were approximately $0.2 million and are recorded in the statement of operations within the general and administrative expenses line item.
	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 August 28, 2013.  The following table summarizes the final purchase price and the values of assets acquired and liabilities assumed:
	(in thousands)
	Final purchase price:
	Consideration given
	Cash			$	83,044
	Total consideration given			$	83,044
	Final fair value allocation of purchase price:
	Accounts receivable			$	5,503
	Oil and natural gas properties:
	Proved properties	$	50,332
	Unproved properties		30,235
	Total oil and natural gas properties				80,567
	Accounts payable				-2,894
	Asset retirement obligations assumed				-132
	Fair value of net assets acquired			$	83,044
	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 for the three months ended July 31, 2014 were approximately $1.3 million and are recorded in the statement of operations within the general and administrative expenses line item.
	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:
	(in thousands)
	Preliminary purchase price:
	Consideration given
	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 and Marathon for the three month and six months ended July 31, 2013, and for the properties acquired from Marathon for the three and six months ended July 31, 2014, as if the acquisitions had occurred on February 1, 2012 and
	February 1, 2013, respectively.
		For the Three Months Ended				For the Six Months Ended
		July 31,				July 31,
	(in thousands, except per share data)	2014		2013		2014		2013
	Operating revenues	$	146,559	$	66,401	$	253,206	$	119,072
	Net income	$	15,217	$	11,453	$	31,122	$	23,709
	Earnings per common share
	Basic	$	0.18	$	0.20	$	0.36	$	0.43
	Diluted	$	0.16	$	0.20	$	0.32	$	0.43
	Weighted average common shares outstanding:
	Basic		86,172		56,451		86,064		54,561
	Diluted		103,774		57,012		103,511		55,089
	The pro forma information includes the effects of adjustments for depreciation, amortization and accretion expense of $1.3 million and $5.0 million for the three months ended July 31, 2014 and 2013, respectively, and $3.3 million and $10.9 million for the six months ended July 31, 2014 and 2013, respectively.  The pro forma results do not include any cost savings or other synergies 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 six months ended July 31, 2014, the Company realized $2.0 million of revenue and $0.5 million of net earnings 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 six months ended July 31, 2014, we acquired oil and natural gas properties, and participated in the drilling and/or completion of wells, for total consideration of approximately $318.0 million.
	During the three and six months ended July 31, 2014, we capitalized $1.2 million and $2.4 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 six months ended July 31, 2013, we capitalized $0.9 million and $1.7 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 $24.6 million during the six months ended July 31, 2014, consist primarily of the costs for two hydraulic fracturing spreads and other complementary well completion and workover equipment, $21.9 million of which was in service and $2.7 million of which was not yet placed in service at July 31, 2014.

Equity_Investment

Equity Investment	6 Months Ended
	Jul. 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 comprehensive 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 July 31, 2014.  We do not guarantee or otherwise support Caliber’s $200.0 million credit facility, and, as such, we would not have additional exposure associated with any borrowings on Caliber’s credit facility.  On June 30, 2014, the Company vested in the 4,000,000 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 July 31, 2014, the balance of the Company’s investment in Caliber was $72.3 million, which consisted of the following:
	(in thousands, except units)	Units	Change In Value		Investment
	Balance - January 31, 2014				$	68,536
	Change in fair value of:
	Class A Trigger Units	4,000,000	$	1,746		1,746
	Class A Trigger Unit Warrant	1,600,000	$	532		532
	Series 1 Warrants	4,000,000	$	994		994
	Series 2 Warrants	2,400,000	$	-182		-182
	Series 3 Warrants	3,000,000	$	-117		-117
	Series 4 Warrants	2,000,000	$	-53		-53
	Equity investment share of net income for the period before intra-company profit elimination					881
	Balance - July 31, 2014				$	72,337
	See Note 8 – Derivative Instruments for a discussion of the change in fair value of the Company’s equity derivative instruments noted above.

LongTerm_Debt

Long-Term Debt	6 Months Ended
	Jul. 31, 2014
Long-Term Debt [Abstract]	'
Long-term Debt	'
	7.    LONG-TERM DEBT
	As of the dates indicated in the table below, the Company’s debt consisted of the following:
	(in thousands)	31-Jul-14		31-Jan-14
	6.75% Senior Notes	$	450,000	$	-
	5% Convertible Note		132,543		129,290
	TUSA credit facility		-		183,000
	RockPile credit facility		39,616		21,515
	RockPile notes and mortgages payable		10,265		9,403
	Total debt		632,424		343,208
	Less current portion of debt:
	RockPile credit facility		-		-8,450
	RockPile notes and mortgages payable		-411		-401
	Total long-term debt	$	632,013	$	334,357
	6.75% Senior 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 $450,000,000 aggregate principal amount of 6.75% Senior Notes due 2022 (the “6.75% Senior Notes”).
	The 6.75% Senior 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 6.75% Senior Notes are senior unsecured obligations of TUSA and are guaranteed on a senior unsecured basis by the Guarantor.  The 6.75% Senior 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 6.75% Senior Notes bear interest at a rate of 6.75% per year, accruing from July 18, 2014.  Interest on the 6.75% Senior Notes is payable semiannually in arrears on January 15 and July 15 of each year, beginning on January 15, 2015.  The 6.75% Senior Notes will mature on July 15, 2022, subject to earlier repurchase or redemption in accordance with the terms of the Indenture.  The Company incurred $10.0 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 6.75% Senior 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 6.75% Senior 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 6.75% Senior 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 July 31, 2014, TUSA was in compliance with all covenants under the 6.75% Senior Notes.
	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 (see Note 13 – Long-Term Debt in our audited financial statements included in our Fiscal 2014 Form 10-K).
	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 July 31, 2017, the Company has the option to make such interest payments in cash.  As of July 31, 2014, $12.5 million of accrued interest has been added to the principal balance of the 5% Convertible Note.
	TUSA Credit Facility
	On January 13, 2014, TUSA entered into Amendment No. 3 to the Amended and Restated Credit Agreement and Master Assignment ("Amendment No. 3") with Wells Fargo Bank, National Association (“Wells Fargo”), as administrative agent and issuing lender, and the other lenders named therein, as lenders.  Amendment No. 3 amended that certain Amended and Restated Credit Agreement (the "A&R Credit Agreement"), dated April 11, 2013, as amended by that certain Amendment No. 1 to Amended and Restated Credit Agreement and Master Assignment, dated July 30, 2013, and that certain Amendment No. 2 to Amendment and Restated Master Assignment, dated October 16, 2013, to (i) broaden the definition of "Independent Engineering Report" to include a report prepared by or under the supervision of TUSA's engineers if certain requirements are satisfied, and (ii) increase the borrowing base under the TUSA Credit Facility from $275.0 million to $320.0 million.  The amendments in Amendment No. 1 remaining in force were (i) provisions permitting TUSA to hedge up to 85.0% of the anticipated production of (x) oil, (y) gas, and (z) natural gas liquid volumes, respectively, attributable to TUSA's total proved reserves, and (ii) revisions enabling TUSA to enter into a second lien credit facility at a future date.  The amendments in Amendment No. 2 remaining in force were (i) the addition of three new lenders under the facility, (ii) the extension of the maturity date to October 16, 2018, and (iii) the decrease of the applicable margins for ABR and Eurodollar advances by 0.25% at all utilization levels.  Further, the existing lenders assigned a portion of their lending commitments to the three new lenders.
	On May 9, 2014, TUSA entered into Amendment No. 4 to the A&R Credit Agreement (“Amendment No. 4”) with Wells Fargo as administrative agent and issuing lender, and the other lenders named therein, as lenders.  Amendment No. 4 amended the A&R Credit Agreement to (i) increase the borrowing base under the facility from $320.0 million to $355.0 million, (ii) add three new lenders to the facility, (iii) add a borrowing base redetermination by August 1, 2014, (iv) cause the borrowing base to increase by up to an additional $10.0 million upon closing the June 6, 2014 Acquisition, (v) permit a one-time distribution to the Company of any funds contributed by the Company to TUSA in connection with closing the June 6, 2014 Acquisition (the “Permitted Distribution”), and (vi) permit TUSA to enter into a second lien credit facility of up to $100.0 million.
	On May 14, 2014, TUSA entered into Amendment No. 5 to the A&R Credit Agreement (“Amendment No. 5”) with Wells Fargo, as administrative agent and issuing lender, and the other lenders named therein, as lenders.  Amendment No. 5 amended the A&R Credit Agreement, as amended by Amendment No. 4, to (i) cause the borrowing base to increase by up to an additional $40.0 million upon closing the Marathon acquisition, and (ii) amend the Permitted Distribution provision to include funds contributed by the Company to TUSA in connection with closing the Marathon acquisition.
	On June 6, 2014, TUSA entered into Amendment No. 6 to the A&R Credit Agreement (“Amendment No. 6”) with Wells Fargo, as administrative agent and issuing lender, and the other lenders named therein, as lenders.  Amendment No. 6 amended the A&R Credit Agreement, as amended by Amendment No. 4 and Amendment No. 5, to expressly permit the prepayment of the second lien credit facility using proceeds from the issuance of Permitted Notes (as defined in the A&R Credit Agreement), including the 6.75% Senior Notes. As of July 31, 2014, TUSA, as borrower, had no borrowings outstanding under the A&R Credit Agreement, as amended through Amendment No. 6 (the “TUSA Credit Facility”).
	The borrowing base under the TUSA Credit Facility is subject to redetermination by the beginning of November 2014 and thereafter on a semi-annual basis by the beginning of each May and November.  In addition, TUSA has the option to request two additional redeterminations during any calendar year.    Upon issuance of the 6.75% Senior Notes, the borrowing base was automatically reduced to $305.5 million.  On August 21, 2014, in accordance with the redetermination provided for in Amendment No. 4, the borrowing base was increased to $415.0 million.
	Borrowings under the TUSA Credit Facility 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 Credit Agreement) 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. TUSA may prepay borrowings under the TUSA Credit Facility at any time without premium or penalty (other than customary LIBOR breakage costs), subject to certain notice requirements.  All borrowings under the TUSA Credit Facility mature on October 16, 2018.
	TUSA will pay a per annum fee on all letters of credit issued under the TUSA 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.  TUSA will pay a commitment fee that ranges between 0.375% and 0.50% per annum on the unused availability under the TUSA Credit Facility, depending on TUSA’s utilization percentage of the then effective borrowing base.
	The TUSA Credit Facility contains representations, warranties and covenants that are customary for similar credit arrangements, including, among other things, covenants relating to (i) financial reporting and notification, (ii) payment of obligations, (iii) compliance with applicable laws, and (iv) notification of certain events.  The TUSA Credit Facility also contains various covenants and restrictive provisions which may, among other things, limit TUSA's ability to sell assets, incur additional indebtedness, make investments or loans, and create liens.
	The TUSA Credit Facility contains financial covenants requiring TUSA to comply with the following: (i) TUSA must 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) the ratio of TUSA's 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) may not be greater than 4.0 to 1.0.  As of July 31, 2014, TUSA was in compliance with all covenants under the TUSA Credit Facility.
	Second Lien Credit Facility
	On June 27, 2014, TUSA entered into a Second Lien Credit Agreement (the “Second Lien Credit Facility”) with Wells Fargo, as administrative agent, and the lenders named therein.  This credit agreement 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 (six 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 6.75% Senior 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 "FY2015 RockPile Credit Agreement") by and among RockPile, as borrower, Citibank, N.A. ("Citi"), as administrative agent and collateral agent, Wells Fargo, as joint lead arranger and joint book runner with Citi, and the other lenders party thereto.  The FY2015 RockPile Credit Agreement is 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 FY2015 RockPile Credit Agreement 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 FY2015 RockPile Credit Agreement) plus 1.0%), plus an applicable margin that ranges between 1.5% and 2.25%, depending on RockPile's leverage ratio as of the last day of RockPile's most recent 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 recent fiscal quarter.  RockPile may prepay borrowings under the FY2015 RockPile Credit Agreement at any time without premium or penalty (other than customary LIBOR breakage costs), subject to certain notice requirements.  All borrowings under the FY2015 RockPile Credit Agreement 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 FY2015 RockPile Credit Agreement.  RockPile will also pay a per annum fee on all letters of credit issued under the FY2015 RockPile Credit Agreement, 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.  In connection with entering into the FY2015 RockPile Credit Agreement, RockPile paid certain upfront fees to the lenders thereunder, and RockPile paid certain arrangement and other fees to Citi and Wells Fargo.  Triangle is not a guarantor under the FY2015 RockPile Credit Agreement.  Upon entering into the FY2015 RockPile Credit Agreement, funds were drawn to pay off all outstanding borrowings under RockPile’s then outstanding credit agreement with Wells Fargo, and for working capital.  As of July 31, 2014, the weighted-average interest rate on the loan was 3.22% and $39.6 million was outstanding on the loan.
	The FY2015 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 FY2015 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 FY2015 RockPile Credit Facility) of at least 1.25 to 1.00 quarterly.  As of July 31, 2014, RockPile was in compliance with all financial covenants under the FY2015 RockPile Credit Facility.
	RockPile Mortgages Payable to Dacotah Bank
	Bakken Real Estate Development, LLC, a wholly-owned subsidiary, has two mortgage loan agreements with Dacotah Bank in the amounts of $2.5 million for its residential units and $4.4 million for its administrative and maintenance facility, all located in Dickinson, North Dakota.  The mortgage loans have a term of 15 years, bear interest at a variable rate equal to the Federal Home Loan Bank of Des Moines Five-Year Fixed-Rate Advance Rate plus 2.80%, and have a maturity date of
	December 15, 2028.
	RockPile Notes Payable to Sellers of Team Well Service, Inc.
	On October 16, 2013, RockPile issued two identical unsecured subordinated promissory notes to the sellers of Team Well Service, Inc. (“Team Well”) in connection with its acquisition of Team Well.  The notes each have a face value of $0.5 million and bear interest at a fixed rate of 1.0%.  The loans have a maturity date of October 16, 2016, at which time the principal and accrued interest is due and payable.  The aggregate carrying value of the loans at July 31, 2014 was $0.9 million.  Over the term of the loans, the discount will be accreted on a monthly basis by increasing the carrying value of both notes and recording interest expense.
	RockPile Hauck Apartments Mortgage
	On November 20, 2013, RockPile closed on the purchase of a 12 unit apartment building in Dickinson, ND for a total purchase price of $1.8 million.  The purchase was funded by cash on hand and a mortgage from Dacotah Bank in the amount of $1.5 million.  The mortgage has a term of 15 years and bears interest at a variable rate equal to the Federal Home Loan Bank of Des Moines Five-Year Fixed-Rate Advance Rate plus 2.70%.  At July 31, 2014, the interest on the mortgage was 4.75% and the outstanding balance on the mortgage was $1.4 million.
	RockPile Promissory Notes
	RockPile redeemed 180,000 B-1 Units from three parties during the six months ended July 31, 2014, in exchange for promissory notes totaling approximately $1.0 million.  The notes mature in the second quarter of the Company’s 2018 fiscal year.  The notes accrue interest at a rate of LIBOR plus 3.0% per annum, payable at maturity.

Derivative_Instruments

Derivative Instruments	6 Months Ended
	Jul. 31, 2014
Derivative Instruments [Abstract]	'
Derivative Instruments	'
	8.  DERIVATIVE INSTRUMENTS
	The following tables detail the fair value of the derivatives recorded in the applicable condensed consolidated balance sheets, by category (in thousands):
					As of July 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		Long-term assets		$	605		$	-469	$	136
	Crude oil derivative contracts		Current liabilities		$	-1,972		$	978	$	-994
	Equity investment derivatives		Equity investment		$	2,870		$	-	$	2,870
					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
	In regards to our commodity derivatives, the Company recorded a loss of $0.9 million and $6.4 million, respectively for the three and six months ended July 31, 2014.   The Company recorded a loss on commodity derivative activities of $4.4 million and $3.2 million, respectively, for the three and six months ended July 31, 2013.  In regards to our equity investment derivatives, we recorded a loss of $7.5 million and a gain of $2.9 million, respectively, for the three and six months ended July 31, 2014.  The Company had no equity investment derivative activity during the six months ended July 31, 2013.
	Commodity Derivative Instruments
	Through TUSA, the Company has entered into commodity derivative instruments, as described below.  The Company has utilized costless collars and swaps to reduce the effect of price changes on a portion of our future oil production.  A collar requires us to pay the counterparty if the settlement price is above the ceiling price, and requires the counterparty to pay us if the settlement price is below the floor price.  The objective of the Company's use of derivative financial instruments is to achieve more predictable cash flows in an environment of volatile oil and natural gas prices and to manage its exposure to commodity price risk.  While the use of these derivative instruments limits the downside risk of adverse price movements, such use may also limit the Company's ability to benefit from favorable price movements.  The Company may, from time to time, add incremental derivatives to hedge additional production, restructure existing derivative contracts, or enter into new transactions to modify the terms of current contracts in order to realize the current value of the Company's existing positions.  The Company does not enter into derivative contracts for speculative purposes.
	The use of derivatives involves the risk that the counterparties to such instruments will be unable to meet the financial terms of such contracts.  The Company's derivative contracts are currently with four counterparties.  The Company has netting arrangements with each counterparty that provide for the offset of payables against receivables from separate derivative arrangements with the same underlier with the counterparty in the event of contract termination.  The derivative contracts may be terminated by a non-defaulting party in the event of default by one of the parties to the agreement.
	The Company's commodity derivative instruments are measured at fair value 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 and comprehensive income.  The Company’s cash flow is only impacted when the actual settlements under the commodity derivative contracts result in making or receiving 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 market place 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 July 31, 2014 are summarized below:
	Term End Date		Contract Type		Basis (1)		Quantity (Bbl/d)		Weighted Average Put Strike	Weighted Average Call Strike		Weighted Average Price
	Fiscal Year 2015		Collar		NYMEX		5,767		$87.33	$100.71
	Fiscal Year 2015		Swap		NYMEX		166					$94.50
	Fiscal Year 2016		Collar		NYMEX		4,356		$86.85	$98.06
		-1		NYMEX refers to prices of West Texas Intermediate crude oil at Cushing, Oklahoma as quoted on the New York Mercantile Exchange.
	Equity Investment Derivatives
	At July 31, 2014, the Company held Class A Trigger Unit Warrants and Class A Warrants (Series 1 through Series 4) to acquire additional ownership in Caliber.  These instruments are valued using the following valuation techniques that are generally less observable from objective sources.  As such, the Company has classified these instruments as Level 3.
	The fair value of the Class A Trigger Unit Warrant and the Class A (Series 1 through Series 4) Warrants as of July 31, 2014, were estimated using a Monte Carlo Simulation (“MCS”) model.  A 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 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 $10.20 at July 31, 2014, a decrease of $1.08 per unit from April 30, 2014, but an increase of $0.20 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 months ended July 31, 2014, resulted in a $2.3 million decrease, and the change in fair value during the six months ended July 31, 2014 resulted in a $1.2 million increase, in our equity investment account in the accompanying unaudited condensed consolidated balance sheet as of July 31, 2014, and as the gain (loss) on equity investment derivatives reflected in the accompanying unaudited condensed consolidated statement of operations and comprehensive income.
	Also included in the gain (loss) on equity investment derivatives during the three and six months ended July 31, 2014, was a loss of $5.2 million and a gain of $1.7 million, respectively, 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	6 Months Ended
	Jul. 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 July 31, 2014 and January 31, 2014 by level within the fair value hierarchy:
			As of July 31, 2014
	(in thousands)		Level 1		Level 2		Level 3		Total
	Assets:
	Equity investment derivative assets		$	-	$	-	$	2,870	$	2,870
	Commodity derivative assets		$	-	$	136	$	-	$	136
	Liabilities:
	Commodity derivative liabilities		$	-	$	-994	$	-	$	-994
	RockPile earn-out liability		$	-	$	-1,791	$	-	$	-1,791
			As of January 31, 2014
	(in thousands)		Level 1		Level 2		Level 3		Total
	Assets:
	Equity investment 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 such counterparties have the financial resources and willingness to meet their potential repayment obligations associated with the derivative transactions.  At July 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 Trigger Unit Warrant and Class A (Series 1 through Series 4) Warrants
	At July 31, 2014, the Caliber Class A Trigger Unit Warrant and 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.  See Note 8 - Derivative Instruments for further discussion.
	RockPile Earn-out Liability
	The Company determined the estimated fair value of the earn-out liability relating to RockPile’s acquisition of Team Well 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.
	6.75% Senior Notes
	The fair value of the 6.75% Senior Notes approximated their fair value due to their recent issuance.
	5% Convertible Note
	The 5% Convertible Note had an estimated fair value at July 31, 2014 of $245.3 million, based on discounted cash flow analysis and option pricing (Level 3).  The increase in fair value from $169.2 million at January 31, 2014 is largely due to a greater option value for Triangle’s common stock based on an increase in the closing price of the stock to $10.80 per share at July 31, 2014 compared with $7.61 per share at January 31, 2014.
	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)		5% Convertible Note		Class A Trigger Units		Warrants (1)
	Beginning balance, January 31, 2014		$	-169,170		38,091	$	1,696
	Interest paid in-kind			-3,252		-		-
	Net unrecognized loss			-72,876		-		-
	Net unrealized gain			-		1,746		1,174
	Conversion to Class A units			-		-39,837		-
	Ending balance, July 31, 2014		$	-245,298	$	-	$	2,870
	Includes Caliber Class A Trigger Unit Warrant and Class A (Series 1 through Series 4) Warrants

Commitments_And_Contingencies

Commitments And Contingencies	6 Months Ended
	Jul. 31, 2014
Commitments And Contingencies [Abstract]	'
Commitments And Contingencies	'
	10.   COMMITMENTS AND CONTINGENCIES
	As of July 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.
	As of July 31, 2014, the Company was subject to commitments on four drilling rig contracts.  The contracts expire between July 2014 and July 2015.  In the event of early termination of the contracts, the Company would be obligated to pay an aggregate amount of approximately $14.0 million as of July 31, 2014 as required under the terms of the contracts.
	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 initial 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 July 31, 2014, and, therefore, no amounts have been recorded in the accompanying condensed consolidated balance sheets.

Capital_Stock

Capital Stock	6 Months Ended
	Jul. 31, 2014
Capital Stock [Abstract]	'
Capital Stock	'
	11.  CAPITAL STOCK
	Common Stock
	During the six months ended July 31, 2014, the Company issued 495,892 shares of its common stock (net of shares surrendered for related employee payroll tax withholding) for restricted stock units that vested during the period.
	Share-Based Compensation
	Effective January 28, 2009, the Company's Board of Directors approved a Stock Option Plan (the "Rolling Plan") whereby the number of authorized but unissued shares of common stock that may be issued upon the exercise of stock options granted under the Rolling Plan at any time could not exceed 10% of the issued and outstanding shares of common stock on a non-diluted basis at any time, and such aggregate number of shares of common stock available for issuance automatically increased or decreased as the number of issued and outstanding shares of common stock changed. Pursuant to the Rolling Plan, stock options became exercisable ratably in one-third increments on each of the first, second and third anniversaries of the date of the grant, and could be granted at an exercise price of not less than the fair value of the common stock at the time of grant and for a term not to exceed ten years.
	Upon approval of the 2011 Omnibus Incentive Plan (the "2011 Plan") by the Company's stockholders on July 22, 2011, the Rolling Plan was terminated and no additional awards may be granted under the Rolling Plan. All outstanding awards under the Rolling Plan shall continue in accordance with their applicable terms and conditions.
	The 2011 Plan authorizes the Company to issue stock options, stock appreciation rights (“SARs”), restricted stock and restricted stock units, performance awards, stock or property, stock awards and other stock-based awards to any employee, consultant, independent contractor, director or officer of the Company or its subsidiaries.  The maximum number of shares of common stock reserved for issuance under the 2011 Plan is 5,900,000 shares, subject to adjustment for certain transactions.
	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.
	On July 4, 2013, the Company entered into a CEO Stand-Alone Stock Option Agreement with the Company's President and Chief Executive Officer (the “CEO Option Grant”).  The CEO Option Grant is a stand-alone stock option agreement unrelated to the 2011 Plan.  As such, the CEO Option Grant required separate stockholder approval before any shares of the Company's common stock could be issued thereunder.  At the Company's Annual Meeting of Stockholders held on August 30, 2013, the CEO Option Grant was approved.
	On May 27, 2014, the Company’s Board of Directors approved the 2014 Equity Incentive Plan (the “2014 Plan”).  Upon approval of the 2014 Plan by the Company’s stockholders on July 17, 2014, the 2011 Plan was terminated and no additional awards may be granted under the 2011 Plan.  All outstanding awards under the 2011 Plan 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 6,000,000 shares, subject to adjustment for certain transactions.
	For the three and six months ended July 31, 2014 and 2013, the Company recorded stock based compensation related to restricted stock units, the CEO Option Grant and RockPile Series B Units as follows:
			Three Months Ended July 31,
			2014			2013
	(in thousands)
	Restricted stock units		$	1,503		$	1,695
	Stock options			487			-
	RockPile stock based compensation related to Series B Units			127			99
				2,117			1,794
	Less amounts capitalized to oil and natural gas properties			-310			-356
	Compensation expense		$	1,807		$	1,438
			Six Months Ended July 31,
			2014			2013
	(in thousands)
	Restricted stock units		$	3,274		$	3,360
	Stock options			973			-
	RockPile stock based compensation related to Series B Units			217			310
				4,464			3,670
	Less amounts capitalized to oil and natural gas properties			-649			-637
	Compensation expense		$	3,815		$	3,033
	Restricted Stock Units
	During the six months ended July 31, 2014, the Company granted 859,600 restricted stock units as compensation to employees, officers and directors.  The restricted stock units vest over one to five years.  As of July 31, 2014, there was approximately $16.8 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 2.9 years.  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		859,600		$	8.73
	Units forfeited		-302,085		$	7.13
	Units that vested		-739,710		$	7.20
	Restricted stock units outstanding - July 31, 2014		2,693,429		$	7.09
	Stock Options
	The Company did not issue stock options during the six months ended July 31, 2014.
	As of July 31, 2014, there was approximately $17.3 million of total unrecognized compensation expense related to stock options (including those issued under the CEO Option Grant and the Rolling Plan).  This compensation expense is expected to be recognized over the remaining vesting period of the related awards of approximately 3.9 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		-		$	-
	Options outstanding - July 31, 2014 (708,333 exercisable)		6,108,333		$	11.07
	The following table presents additional information related to the stock options outstanding at July 31, 2014:
					Remaining
	Exercise Price				Contractual Life		Number of shares
	per Share				(years)		Outstanding		Exercisable
	$	1.25			0.59			108,333		108,333
	$	7.50			9.18			750,000		75,000
	$	8.50			9.18			750,000		75,000
	$	10.00			9.18			1,500,000		150,000
	$	12.00			9.18			1,500,000		150,000
	$	15.00			9.18			1,500,000		150,000
								6,108,333		708,333
	Weighted average exercise price per share						$	11.07	$	9.72
	Weighted average remaining contractual life							8.78		7.62
	RockPile Share-Based Compensation
	RockPile issued 1,412,000 Series B units to 32 parties during the six months ended July 31, 2014.
RockPile redeemed 180,000 B-1 Units from three parties during the six months ended July 31, 2014 in exchange for promissory notes totaling approximately $1.0 million.  The notes mature in the second quarter of fiscal year 2018.
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 - July 31, 2014	2,920,000		60,000		910,000		1,412,000	5,302,000
Vested	2,386,667		15,000		188,000		-	2,589,667
Unvested	533,333		45,000		722,000		1,412,000	2,712,333
As of July 31, 2014, there was approximately $2.9 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 three fiscal years.

Earnings_Per_Share

Earnings Per Share	6 Months Ended
	Jul. 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 for securities outstanding at the end of a period.  Also, the treasury stock method for calculating dilution assumes that the increase in the number of shares is reduced by the number of shares which could have been repurchased by the Company at the quarter's average stock price using assumed proceeds from (a) the exercise cost of the options, and (b) the foregone future compensation expense of hypothetical early vesting of the outstanding restricted stock units.  The assumed proceeds are adjusted for income tax effects.
	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 six months ended July 31, 2014 and 2013:
		For the Three Months Ended				For the Six Months Ended
		July 31,				July 31,
	(in thousands, except per share data)	2014		2013		2014		2013
	Net income attributable to common stockholders	$	14,552	$	6,799	$	29,094	$	12,010
	Effect of 5% Convertible Note conversion		996		-		1,983		-
	Net income attributable to common stockholders after effect of debt conversion		15,548		6,799		31,077		12,010
	Basic weighted average common shares outstanding		86,172		56,451		86,064		54,561
	Effect of dilutive securities		17,602		561		17,447		528
	Diluted weighted average common shares outstanding		103,774		57,012		103,511		55,089
	Basic net income per share	$	0.17	$	0.12	$	0.34	$	0.22
	Diluted net income per share	$	0.15	$	0.12	$	0.30	$	0.22
	Of the stock options, restricted stock units and convertible debt outstanding at July 31, 2014, only 4.5 million of outstanding options in the CEO Option Grant were anti-dilutive for the three and six month periods ended July 31, 2014, and the shares of common stock issuable upon exercise of those options were excluded from the calculation of the diluted net income per share for those three and six month periods.  These awards could be potentially dilutive in future periods.

Income_Taxes

Income Taxes	6 Months Ended
	Jul. 31, 2014
Income Taxes [Abstract]	'
Income Taxes	'
	13.  INCOME TAXES
	The effective tax rate for the six months ended July 31, 2014 was 41.2%, which differs from the statutory income tax rate due primarily to permanent book to tax differences and state income taxes.  Neither a tax expense nor a tax benefit was recognized for the three or six months ended July 31, 2013, as the Company had provided a 100% valuation allowance against its net deferred tax assets which exceeded its deferred tax liabilities at that time.
	As of July 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 half 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	6 Months Ended
	Jul. 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 $387.6 million remained at July 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", owned 51% by Caliber Fresh Water LLC (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, 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 all necessary regulatory approvals.  As of July 31, 2014, the necessary regulatory approvals had not yet been received, however the Company expects to receive all such approvals and finalize the transaction during its fiscal 2015 third quarter.
	For the three and six months ended July 31, 2014, Caliber North Dakota had $9.6 million and $13.7 million of revenue, respectively, of which, $8.4 million and $12.2 million, respectively, were from TUSA, and mainly comprised of fresh water and salt water disposal revenues.  See Note 6 – Equity Investment.
	For the three and six month period ended July 31, 2014, Triangle received $0.3 million and $0.6 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	6 Months Ended
	Jul. 31, 2014
Supplemental Disclosures of Cash Flow Information [Abstract]	'
Supplemental Disclosures of Cash Flow Information	'
	15.  SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
		For the Six Months Ended
		July 31,
	(in thousands)	2014		2013
	Cash paid during the period for:
	Interest expense	$	4,717	$	1,042
	Income taxes	$	550	$	-
	Non-cash investing activities:
	Additions (reductions) to oil and natural gas properties through:
	Increased (decreased) accrued liabilities and prepaid well costs	$	37,151	$	6,700
	Capitalized stock based compensation	$	649	$	637
	Change in asset retirement obligations	$	1,106	$	92
	Capitalized interest	$	1,808	$	1,100
	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	6 Months Ended
	Jul. 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 July 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 July 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 $88.97 per barrel of oil, $44.82 per barrel of natural gas liquids and $5.72 per Mcf of natural gas for the reserves presented as of July 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-Jul-14				January 31,
		Reserves	Oil	Gas	NGL		2014
	Reserve Category	(Mboe)	(Mbbls)	(MMcf)	(Mbbls)	Mboe	Mboe
	Proved Developed	58%	24,213	20,000	2,484	30,030	16,995
	Proved Undeveloped	42%	16,849	14,371	2,386	21,630	23,319
	Total Proved	100%	41,062	34,371	4,870	51,660	40,314
	The primary reason for the increase in proved reserves is the drilling and completion of wells in the first six months of fiscal year 2015 and the Marathon acquisition and the June 6, 2014 Acquisition that both closed during the three months ended July 31, 2014.  Our net interest in proved developed wells increased 96% from 50.0 net wells at January 31, 2014 to 98.0 net wells at July 31, 2014, and our net interest in proved undeveloped locations decreased 8% from 52.5 net future development wells at January 31, 2014 to 48.4 net future development wells at July 31, 2014.

Basis_Of_Presentation_Policy

Basis Of Presentation (Policy)	6 Months Ended
	Jul. 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.  See Note 6 - Equity Investment for further discussion.
Reclassifications	'
	Reclassifications
	Certain amounts in the condensed consolidated balance sheet as of January 31, 2014, and in our condensed consolidated statement of operations and comprehensive income for the quarter ended July 31, 2013, have been reclassified to conform to the financial statement presentation for the quarter ended July 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)	6 Months Ended
	Jul. 31, 2014
Summary Of Significant Accounting Policies [Abstract]	'
New Pronouncements Issued But Not Yet Adopted	'
	New Pronouncements Issued But Not Yet Adopted
	In May 2014, the Financial Accounting Standards Board issued Accounting Standards Update (“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.
	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 standard discussed above, there are no significant accounting standards applicable to Triangle which have not been adopted.

Segment_Reporting_Tables

Segment Reporting (Tables)	6 Months Ended
	Jul. 31, 2014
Segment Reporting [Abstract]	'
Schedule Of Segment Reporting	'
			For the Three Months Ended July 31, 2014
	(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
	Revenues:
	Oil, natural gas and natural gas liquids sales		$	80,506	$	-	$	-	$	-	$	80,506
	Oilfield services for third parties			-		64,093		-		-2,610		61,483
	Intersegment revenues			-		37,962		-		-37,962		-
	Other			-		-		272		-272		-
	Total revenues			80,506		102,055		272		-40,844		141,989
	Expenses:
	Production taxes and other lease operating			15,375		-		-		-		15,375
	Gathering, transportation and processing			3,733		-		-		-		3,733
	Depreciation and amortization			23,439		4,690		186		-1,609		26,706
	Accretion of asset retirement obligations			41		-		-		-		41
	Cost of oilfield services			-		68,867		-		-25,313		43,554
	General and administrative:
	Stock-based compensation			344		127		1,336		-		1,807
	Other general and administrative			4,442		5,251		2,591		-		12,284
	Total operating expenses			47,374		78,935		4,113		-26,922		103,500
	Income (loss) from operations			33,132		23,120		-3,841		-13,922		38,489
	Other income (expense), net			-4,267		-667		-7,580		-1,084		-13,598
	Net income (loss) before income taxes		$	28,865	$	22,453	$	-11,421	$	-15,006	$	24,891
			For the Three Months Ended July 31, 2013
	(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
	Revenues:
	Oil, natural gas and natural gas liquids sales		$	34,639	$	-	$	-	$	-	$	34,639
	Oilfield services for third parties			-		17,137		-		-1,382		15,755
	Intersegment revenues			-		27,148		-		-27,148		-
	Other			-		-		272		-272		-
	Total revenues			34,639		44,285		272		-28,802		50,394
	Expenses:
	Production taxes and other lease operating			6,749		-		-		-		6,749
	Gathering, transportation and processing			69		-		-		-		69
	Depreciation and amortization			10,111		1,600		135		-928		10,918
	Accretion of asset retirement obligations			9		-		-		-		9
	Cost of oilfield services			-		30,370		-		-17,678		12,692
	General and administrative:
	Stock-based compensation			247		99		1,092		-		1,438
	Other general and administrative			1,683		2,446		1,417		-		5,546
	Total operating expenses			18,868		34,515		2,644		-18,606		37,421
	Income (loss) from operations			15,771		9,770		-2,372		-10,196		12,973
	Other income (expense), net			-4,087		-216		-578		-1,293		-6,174
	Net income (loss) before income taxes		$	11,684	$	9,554	$	-2,950	$	-11,489	$	6,799
	The following tables present selected financial information for our operating segments for the six months ended July 31, 2014 and 2013:
			For the Six Months Ended July 31, 2014
	(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
	Revenues:
	Oil, natural gas and natural gas liquids sales		$	141,340	$	-	$	-	$	-	$	141,340
	Oilfield services for third parties			-		103,650		-		-3,219		100,431
	Intersegment revenues			-		59,837		-		-59,837		-
	Other			-		-		449		-449		-
	Total revenues			141,340		163,487		449		-63,505		241,771
	Expenses
	Production taxes and other lease operating			26,449		-		-		-		26,449
	Gathering, transportation and processing			7,535		-		-		-		7,535
	Depreciation and amortization			42,051		8,280		362		-2,809		47,884
	Accretion of asset retirement obligations			175		-		-		-		175
	Cost of oilfield services			-		112,578		-		-41,314		71,264
	General and administrative:
	Stock-based compensation			739		217		2,859		-		3,815
	Other general and administrative			7,220		10,348		6,109		-		23,677
	Total operating expenses			84,169		131,423		9,330		-44,123		180,799
	Income (loss) from operations			57,171		32,064		-8,881		-19,382		60,972
	Other income (expense), net			-10,834		-1,174		1,741		-1,261		-11,528
Net income (loss) before income taxes		$	46,337	$	30,890	$	-7,140	$	-20,643	$	49,444
		As of July 31, 2014
Net oil and natural gas properties		$	1,027,074	$	-	$	-	$	-68,318	$	958,756
Oilfield services equipment - net		$	-	$	64,379	$	-	$	-	$	64,379
Other property and equipment - net		$	1,562	$	20,372	$	6,784	$	-	$	28,718
Total assets (1)		$	1,188,878	$	171,550	$	168,143	$	-120,117	$	1,408,454
Total liabilities		$	659,922	$	89,387	$	136,137	$	-30,479	$	854,967
	-1		Our Corporate and Other total assets consist primarily of cash and cash equivalents of $64.4 million and our investment in Caliber of $72.3 million, in addition to the Company’s investment in its subsidiaries which are subsequently eliminated.
		For the Six Months Ended July 31, 2013
(in thousands)		Exploration and Production		Oilfield Services		Corporate and Other		Eliminations		Consolidated Total
Revenues:
Oil, natural gas and natural gas liquids sales		$	55,699	$	-	$	-	$	-	$	55,699
Oilfield services for third parties			-		32,281		-		-3,292		28,989
Intersegment revenues			-		38,887		-		-38,887		-
Other			-		-		548		-548		-
Total revenues			55,699		71,168		548		-42,727		84,688
Expenses:
Production taxes and other lease operating			11,409		-		-		-		11,409
Gathering, transportation and processing			106		-		-		-		106
Depreciation and amortization			16,729		2,839		258		-1,435		18,391
Accretion of asset retirement obligations			17		-		-		-		17
Cost of oilfield services			-		49,491		-		-25,613		23,878
General and administrative:
Stock-based compensation			569		310		2,154		-		3,033
Other general and administrative			3,250		4,425		2,878		-		10,553
Total operating expenses			32,080		57,065		5,290		-27,048		67,387
Income (loss) from operations			23,619		14,103		-4,742		-15,679		17,301
Other income (expense), net			-2,636		-369		-993		-1,293		-5,291
Net income (loss) before income taxes		$	20,983	$	13,734	$	-5,735	$	-16,972	$	12,010

Property_And_Equipment_Tables

Property And Equipment (Tables)	6 Months Ended
	Jul. 31, 2014
Property, Plant and Equipment [Line Items]	'
Proforma Schedule For Oil And Natural Gas Acquisition	'
		For the Three Months Ended				For the Six Months Ended
		July 31,				July 31,
	(in thousands, except per share data)	2014		2013		2014		2013
	Operating revenues	$	146,559	$	66,401	$	253,206	$	119,072
	Net income	$	15,217	$	11,453	$	31,122	$	23,709
	Earnings per common share
	Basic	$	0.18	$	0.20	$	0.36	$	0.43
	Diluted	$	0.16	$	0.20	$	0.32	$	0.43
	Weighted average common shares outstanding:
	Basic		86,172		56,451		86,064		54,561
	Diluted		103,774		57,012		103,511		55,089
Kodiak Oil And Natural Gas Property [Member]	'
Property, Plant and Equipment [Line Items]	'
Schedule Of Purchase Price Allocation Of Oil And Natural Gas Acquisition	'
	(in thousands)
	Final purchase price:
	Consideration given
	Cash			$	83,044
	Total consideration given			$	83,044
	Final fair value allocation of purchase price:
	Accounts receivable			$	5,503
	Oil and natural gas properties:
	Proved properties	$	50,332
	Unproved properties		30,235
	Total oil and natural gas properties				80,567
	Accounts payable				-2,894
	Asset retirement obligations assumed				-132
	Fair value of net assets acquired			$	83,044
Marathon Oil And Gas [Member]	'
Property, Plant and Equipment [Line Items]	'
Schedule Of Purchase Price Allocation Of Oil And Natural Gas Acquisition	'
	(in thousands)
	Preliminary purchase price:
	Consideration given
	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)	6 Months Ended
	Jul. 31, 2014
Equity Investment [Abstract]	'
Schedule Of Equity Investment In Caliber	'
	(in thousands, except units)	Units	Change In Value		Investment
	Balance - January 31, 2014				$	68,536
	Change in fair value of:
	Class A Trigger Units	4,000,000	$	1,746		1,746
	Class A Trigger Unit Warrant	1,600,000	$	532		532
	Series 1 Warrants	4,000,000	$	994		994
	Series 2 Warrants	2,400,000	$	-182		-182
	Series 3 Warrants	3,000,000	$	-117		-117
	Series 4 Warrants	2,000,000	$	-53		-53
	Equity investment share of net income for the period before intra-company profit elimination					881
	Balance - July 31, 2014				$	72,337

LongTerm_Debt_Tables

Long-Term Debt (Tables)	6 Months Ended
	Jul. 31, 2014
Long-Term Debt [Abstract]	'
Schedule Of Debt	'
	(in thousands)	31-Jul-14		31-Jan-14
	6.75% Senior Notes	$	450,000	$	-
	5% Convertible Note		132,543		129,290
	TUSA credit facility		-		183,000
	RockPile credit facility		39,616		21,515
	RockPile notes and mortgages payable		10,265		9,403
	Total debt		632,424		343,208
	Less current portion of debt:
	RockPile credit facility		-		-8,450
	RockPile notes and mortgages payable		-411		-401
	Total long-term debt	$	632,013	$	334,357

Derivative_Instruments_Tables

Derivative Instruments (Tables)	6 Months Ended
	Jul. 31, 2014
Derivative Instruments [Abstract]	'
Schedule Of Derivative Instruments In Statement Of Financial Position, Fair Value	'
					As of July 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		Long-term assets		$	605		$	-469	$	136
	Crude oil derivative contracts		Current liabilities		$	-1,972		$	978	$	-994
	Equity investment derivatives		Equity investment		$	2,870		$	-	$	2,870
					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		Weighted Average Price
	Fiscal Year 2015		Collar		NYMEX		5,767		$87.33	$100.71
	Fiscal Year 2015		Swap		NYMEX		166					$94.50
	Fiscal Year 2016		Collar		NYMEX		4,356		$86.85	$98.06
		-1		NYMEX refers to prices of West Texas Intermediate crude oil at Cushing, Oklahoma as quoted on the New York Mercantile Exchange.

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jul. 31, 2014
Fair Value Measurements [Abstract]	'
Schedule Of Fair Value, Assets And Liabilities Measured On Recurring Basis	'
		As of July 31, 2014
	(in thousands)	Level 1		Level 2		Level 3		Total
	Assets:
	Equity investment derivative assets	$	-	$	-	$	2,870	$	2,870
	Commodity derivative assets	$	-	$	136	$	-	$	136
	Liabilities:
	Commodity derivative liabilities	$	-	$	-994	$	-	$	-994
	RockPile earn-out liability	$	-	$	-1,791	$	-	$	-1,791
		As of January 31, 2014
	(in thousands)	Level 1		Level 2		Level 3		Total
	Assets:
	Equity investment 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)	5% Convertible Note		Class A Trigger Units		Warrants (1)
	Beginning balance, January 31, 2014	$	-169,170		38,091	$	1,696
	Interest paid in-kind		-3,252		-		-
	Net unrecognized loss		-72,876		-		-
	Net unrealized gain		-		1,746		1,174
	Conversion to Class A units		-		-39,837		-
	Ending balance, July 31, 2014	$	-245,298	$	-	$	2,870
	Includes Caliber Class A Trigger Unit Warrant and Class A (Series 1 through Series 4) Warrants

Capital_Stock_Tables

Capital Stock (Tables)	6 Months Ended
	Jul. 31, 2014
Capital Stock [Abstract]	'
Non-Cash Stock-Based Compensation Cost	'
			Three Months Ended July 31,
			2014			2013
	(in thousands)
	Restricted stock units		$	1,503		$	1,695
	Stock options			487			-
	RockPile stock based compensation related to Series B Units			127			99
				2,117			1,794
	Less amounts capitalized to oil and natural gas properties			-310			-356
	Compensation expense		$	1,807		$	1,438
			Six Months Ended July 31,
			2014			2013
	(in thousands)
	Restricted stock units		$	3,274		$	3,360
	Stock options			973			-
	RockPile stock based compensation related to Series B Units			217			310
				4,464			3,670
	Less amounts capitalized to oil and natural gas properties			-649			-637
	Compensation expense		$	3,815		$	3,033
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		859,600		$	8.73
	Units forfeited		-302,085		$	7.13
	Units that vested		-739,710		$	7.20
	Restricted stock units outstanding - July 31, 2014		2,693,429		$	7.09
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		-		$	-
	Options outstanding - July 31, 2014 (708,333 exercisable)		6,108,333		$	11.07
Stock Options Outstanding By Exercise Price	'
					Remaining
	Exercise Price				Contractual Life		Number of shares
	per Share				(years)		Outstanding		Exercisable
	$	1.25			0.59			108,333		108,333
	$	7.50			9.18			750,000		75,000
	$	8.50			9.18			750,000		75,000
	$	10.00			9.18			1,500,000		150,000
	$	12.00			9.18			1,500,000		150,000
	$	15.00			9.18			1,500,000		150,000
								6,108,333		708,333
	Weighted average exercise price per share						$	11.07	$	9.72
	Weighted average remaining contractual life							8.78		7.62
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 - July 31, 2014	2,920,000		60,000		910,000		1,412,000	5,302,000
	Vested	2,386,667		15,000		188,000		-	2,589,667
	Unvested	533,333		45,000		722,000		1,412,000	2,712,333

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	6 Months Ended
	Jul. 31, 2014
Earnings Per Share [Abstract]	'
Computations Of Basic And Diluted Net Loss Per Share	'
		For the Three Months Ended				For the Six Months Ended
		July 31,				July 31,
	(in thousands, except per share data)	2014		2013		2014		2013
	Net income attributable to common stockholders	$	14,552	$	6,799	$	29,094	$	12,010
	Effect of 5% Convertible Note conversion		996		-		1,983		-
	Net income attributable to common stockholders after effect of debt conversion		15,548		6,799		31,077		12,010
	Basic weighted average common shares outstanding		86,172		56,451		86,064		54,561
	Effect of dilutive securities		17,602		561		17,447		528
	Diluted weighted average common shares outstanding		103,774		57,012		103,511		55,089
	Basic net income per share	$	0.17	$	0.12	$	0.34	$	0.22
	Diluted net income per share	$	0.15	$	0.12	$	0.30	$	0.22

Recovered_Sheet1

Supplemental Disclosures of Cash Flow Information (Tables)	6 Months Ended
	Jul. 31, 2014
Supplemental Disclosures of Cash Flow Information [Abstract]	'
Schedule of Supplemental Cash Flow Disclosures	'
		For the Six Months Ended
		July 31,
	(in thousands)	2014		2013
	Cash paid during the period for:
	Interest expense	$	4,717	$	1,042
	Income taxes	$	550	$	-
	Non-cash investing activities:
	Additions (reductions) to oil and natural gas properties through:
	Increased (decreased) accrued liabilities and prepaid well costs	$	37,151	$	6,700
	Capitalized stock based compensation	$	649	$	637
	Change in asset retirement obligations	$	1,106	$	92
	Capitalized interest	$	1,808	$	1,100
	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)	6 Months Ended
	Jul. 31, 2014
Significant Changes In Proved Oil And Natural Gas Reserves (Abstract)	'
Proved Oil And Natural Gas Reserves	'
		% of	31-Jul-14				January 31,
		Reserves	Oil	Gas	NGL		2014
	Reserve Category	(Mboe)	(Mbbls)	(MMcf)	(Mbbls)	Mboe	Mboe
	Proved Developed	58%	24,213	20,000	2,484	30,030	16,995
	Proved Undeveloped	42%	16,849	14,371	2,386	21,630	23,319
	Total Proved	100%	41,062	34,371	4,870	51,660	40,314

Segment_Reporting_Narrative_De

Segment Reporting (Narrative) (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jul. 31, 2014	Jul. 31, 2013	Jul. 31, 2014	Jul. 31, 2013
			segment
Segment Reporting [Abstract]	'	'	'	'
Number of reportable segments	'	'	2	'
Deferred Revenue	$2.60	$1.40	$3.20	$3.30
Deferred gross profit	$0.60	$0.70	$0.80	$1.30

Segment_Reporting_Schedule_Of_

Segment Reporting (Schedule Of Segment Reporting) (Details) (USD $)	3 Months Ended			6 Months Ended
In Thousands, unless otherwise specified	Jul. 31, 2014		Jul. 31, 2013	Jul. 31, 2014		Jul. 31, 2013	Jan. 31, 2014
Revenues:	'		'	'		'	'
Oil, natural gas and natural gas liquids sales	$80,506		$34,639	$141,340		$55,699	'
Oilfield services for third parties	61,483		15,755	100,431		28,989	'
Total revenues	141,989		50,394	241,771		84,688	'
Expenses:	'		'	'		'	'
Production taxes and other lease operating	15,375		6,749	26,449		11,409	'
Gathering, transportation and processing	3,733		69	7,535		106	'
Depreciation and amortization	26,706		10,918	47,884		18,391	'
Accretion of asset retirement obligations	41		9	175		17	'
Cost of oilfield services	43,554		12,692	71,264		23,878	'
Stock-based compensation	1,807		1,438	3,815		3,033	'
Other general and administrative	12,284		5,546	23,677		10,553	'
Total operating expenses	103,500		37,421	180,799		67,387	'
Income (loss) from operations	38,489		12,973	60,972		17,301	'
Other income (expense), net	-13,598		-6,174	-11,528		-5,291	'
NET INCOME (LOSS) BEFORE INCOME TAXES	24,891		6,799	49,444		12,010	'
Net oil and natural gas properties	958,756		'	958,756		'	682,787
Oilfield services equipment - net	64,379		'	64,379		'	46,586
Other property and equipment - net	28,718		'	28,718		'	24,507
Total assets	1,408,454	[1]	'	1,408,454	[1]	'	1,027,584
Total liabilities	854,967		'	854,967		'	504,422
Cash and equivalents	107,527		'	107,527		'	81,750
Equity investment	72,337		'	72,337		'	68,536
Eliminations [Member]	'		'	'		'	'
Revenues:	'		'	'		'	'
Oilfield services for third parties	-2,610		-1,382	-3,219		-3,292	'
Other	-272		-272	-449		-548	'
Total revenues	-40,844		-28,802	-63,505		-42,727	'
Expenses:	'		'	'		'	'
Depreciation and amortization	-1,609		-928	-2,809		-1,435	'
Cost of oilfield services	-25,313		-17,678	-41,314		-25,613	'
Total operating expenses	-26,922		-18,606	-44,123		-27,048	'
Income (loss) from operations	-13,922		-10,196	-19,382		-15,679	'
Other income (expense), net	-1,084		-1,293	-1,261		-1,293	'
NET INCOME (LOSS) BEFORE INCOME TAXES	-15,006		-11,489	-20,643		-16,972	'
Net oil and natural gas properties	-68,318		'	-68,318		'	'
Total assets	-120,117	[1]	'	-120,117	[1]	'	'
Total liabilities	-30,479		'	-30,479		'	'
Intersegment Revenues [Member] | Eliminations [Member]	'		'	'		'	'
Revenues:	'		'	'		'	'
Total revenues	-37,962		-27,148	-59,837		-38,887	'
Exploration and Production [Member]	'		'	'		'	'
Revenues:	'		'	'		'	'
Oil, natural gas and natural gas liquids sales	80,506		34,639	141,340		55,699	'
Total revenues	80,506		34,639	141,340		55,699	'
Expenses:	'		'	'		'	'
Production taxes and other lease operating	15,375		6,749	26,449		11,409	'
Gathering, transportation and processing	3,733		69	7,535		106	'
Depreciation and amortization	23,439		10,111	42,051		16,729	'
Accretion of asset retirement obligations	41		9	175		17	'
Stock-based compensation	344		247	739		569	'
Other general and administrative	4,442		1,683	7,220		3,250	'
Total operating expenses	47,374		18,868	84,169		32,080	'
Income (loss) from operations	33,132		15,771	57,171		23,619	'
Other income (expense), net	-4,267		-4,087	-10,834		-2,636	'
NET INCOME (LOSS) BEFORE INCOME TAXES	28,865		11,684	46,337		20,983	'
Net oil and natural gas properties	1,027,074		'	1,027,074		'	'
Other property and equipment - net	1,562		'	1,562		'	'
Total assets	1,188,878	[1]	'	1,188,878	[1]	'	'
Total liabilities	659,922		'	659,922		'	'
Oilfield Services [Member]	'		'	'		'	'
Revenues:	'		'	'		'	'
Oilfield services for third parties	64,093		17,137	103,650		32,281	'
Total revenues	102,055		44,285	163,487		71,168	'
Expenses:	'		'	'		'	'
Depreciation and amortization	4,690		1,600	8,280		2,839	'
Cost of oilfield services	68,867		30,370	112,578		49,491	'
Stock-based compensation	127		99	217		310	'
Other general and administrative	5,251		2,446	10,348		4,425	'
Total operating expenses	78,935		34,515	131,423		57,065	'
Income (loss) from operations	23,120		9,770	32,064		14,103	'
Other income (expense), net	-667		-216	-1,174		-369	'
NET INCOME (LOSS) BEFORE INCOME TAXES	22,453		9,554	30,890		13,734	'
Oilfield services equipment - net	64,379		'	64,379		'	'
Other property and equipment - net	20,372		'	20,372		'	'
Total assets	171,550	[1]	'	171,550	[1]	'	'
Total liabilities	89,387		'	89,387		'	'
Oilfield Services [Member] | Intersegment Revenues [Member]	'		'	'		'	'
Revenues:	'		'	'		'	'
Total revenues	37,962		27,148	59,837		38,887	'
Corporate And Other [Member]	'		'	'		'	'
Revenues:	'		'	'		'	'
Other	272		272	449		548	'
Total revenues	272		272	449		548	'
Expenses:	'		'	'		'	'
Depreciation and amortization	186		135	362		258	'
Stock-based compensation	1,336		1,092	2,859		2,154	'
Other general and administrative	2,591		1,417	6,109		2,878	'
Total operating expenses	4,113		2,644	9,330		5,290	'
Income (loss) from operations	-3,841		-2,372	-8,881		-4,742	'
Other income (expense), net	-7,580		-578	1,741		-993	'
NET INCOME (LOSS) BEFORE INCOME TAXES	-11,421		-2,950	-7,140		-5,735	'
Other property and equipment - net	6,784		'	6,784		'	'
Total assets	168,143	[1]	'	168,143	[1]	'	'
Total liabilities	136,137		'	136,137		'	'
Cash and equivalents	$64,400		'	$64,400		'	'
[1]	Our Corporate and Other total assets consist primarily of cash and cash equivalents of $64.4 million and our investment in Caliber of $72.3 million, in addition to the Company’s investment in its subsidiaries which are subsequently eliminated.

Property_And_Equipment_Narrati

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

3 Months Ended

6 Months Ended

1 Months Ended

6 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

6 Months Ended

1 Months Ended

3 Months Ended

6 Months Ended

Jul. 31, 2014

Jul. 31, 2013

Jul. 31, 2014

Jul. 31, 2013

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Aug. 28, 2013

Jul. 31, 2014

Jan. 31, 2014

Jun. 06, 2014

Jul. 31, 2014

Jul. 31, 2013

Jul. 31, 2014

Jun. 30, 2014

Jul. 31, 2014

Jul. 31, 2014

Oilfield Service Equipment [Member]

Oilfield Service Equipment In Service [Member]

Oilfield Service Equipment Not Yet Placed In Service [Member]

Kodiak Oil And Natural Gas Property [Member]

Kodiak Oil And Natural Gas Property [Member]

Kodiak Oil And Natural Gas Property [Member]

Oil And Gas Property [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

acre

Property, Plant and Equipment [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Date of acquisition

'

'

'

'

'

'

'

'

28-Aug-13

'

'

'

'

6-Jun-14

'

'

30-Jun-14

Number of acres purchased

'

'

'

'

'

'

'

5,600

'

'

4,600

'

'

'

41,100

'

'

Total consideration to purchase oil and gas properties

'

'

'

'

'

'

'

$83,000,000

'

'

$34,500,000

'

'

$318,000,000

$90,400,000

'

'

Pre-closing adjustment

'

'

'

'

'

'

'

'

'

'

500,000

'

'

'

9,600,000

'

'

Pro forma depreciation, amortization and accretion expense

1,300,000

5,000,000

3,300,000

10,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Capitalized internal costs for property acquisition

'

'

2,400,000

1,700,000

'

'

'

'

'

'

'

1,200,000

900,000

'

'

'

'

Depreciable asset, gross

'

'

'

'

24,600,000

21,900,000

2,700,000

'

'

'

'

'

'

'

'

'

'

Acquisition Costs

'

'

'

'

'

'

'

'

'

200,000

'

'

'

'

'

'

1,300,000

Revenues

141,989,000

50,394,000

241,771,000

84,688,000

'

'

'

'

'

'

'

'

'

'

'

2,000,000

2,000,000

Net earnings

$14,552,000

$6,799,000

$29,094,000

$12,010,000

'

'

'

'

'

'

'

'

'

'

'

$500,000

$500,000

Property_And_Equipment_Schedul

Property And Equipment (Schedule Of Purchase Price Allocation Of Oil And Natural Gas Property Acquisitions) (Details) (USD $)	1 Months Ended
In Thousands, unless otherwise specified	Aug. 28, 2013	Aug. 28, 2013	Jun. 30, 2014	Jun. 30, 2014
	Kodiak Oil And Natural Gas Property [Member]	Kodiak Oil And Natural Gas Property [Member]	Marathon Oil And Gas [Member]	Marathon Oil And Gas [Member]
		Final [Member]		Preliminary [Member]
Property, Plant and Equipment [Line Items]	'	'	'	'
Cash	'	$83,044	'	$90,352
Total consideration given	83,000	83,044	90,400	90,352
Accounts receivable	'	5,503	'	'
Proved properties	'	50,332	'	71,044
Unproved properties	'	30,235	'	20,262
Total oil and natural gas properties	'	80,567	'	91,306
Accounts payable	'	-2,894	'	-469
Asset retirement obligation assumed	'	-132	'	-485
Fair value of net assets acquired	'	$83,044	'	$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		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jul. 31, 2014	Jul. 31, 2013	Jul. 31, 2014	Jul. 31, 2013
Kodiak Oil And Gas, Marathon Oil And Gas [Member]	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'
Operating revenue	$146,559	$66,401	$253,206	$119,072
Net income (loss)	$15,217	$11,453	$31,122	$23,709
Earnings (loss) per common share, basic	$0.18	$0.20	$0.36	$0.43
Earnings (loss) per common share, diluted	$0.16	$0.20	$0.32	$0.43
Weighted average common shares outstanding, basic	86,172	56,451	86,064	54,561
Weighted average common shares outstanding, diluted	103,774	57,012	103,511	55,089

Equity_Investment_Narrative_De

Equity Investment (Narrative) (Details) (USD $)	Jul. 31, 2014	Jan. 31, 2014	Jul. 31, 2014	Jan. 31, 2014	Jun. 30, 2014	Jun. 29, 2014	Jul. 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 Credit Facility [Member]
					Class A Triggering Units [Member]	Class A Triggering Units [Member]
Schedule of Equity Method Investments [Line Items]	'	'	'	'	'	'	'
Credit facility	'	'	'	'	'	'	$200,000
Ownership interest	'	'	'	'	32.00%	30.00%	'
Equity investment, number of units vested	'	'	'	'	4,000,000	'	'
Equity investment	$72,337	$68,536	$72,337	$68,536	'	'	'

Equity_Investment_Schedule_Of_

Equity Investment (Schedule Of Equity Investment In Caliber) (Details) (USD $)	Jul. 31, 2014	Jan. 31, 2014	Jul. 31, 2014	Jul. 31, 2014	Jul. 31, 2014	Jul. 31, 2014	Jul. 31, 2014	Jul. 31, 2014	Jul. 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]	Caliber Midstream LP [Member]
				Class A Triggering Units [Member]	Class A Trigger Unit Warrant [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	$72,337	$68,536	$68,536	'	'	'	'	'	'
Equity method investments, Class A Units received	'	'	'	4,000,000	'	'	'	'	'
Equity method investments, Class A Trigger Units received	'	'	'	'	1,600,000	'	'	'	'
Equity method investments, warrants received	'	'	'	'	'	4,000,000	2,400,000	3,000,000	2,000,000
Increase (decrease) in equity method investment	'	'	'	1,746	532	994	-182	-117	-53
Equity investment share of net income for the period before intra-company profit elimination	'	'	881	'	'	'	'	'	'
Equity investment, Ending balance	$72,337	$68,536	$72,337	'	'	'	'	'	'

Longterm_Debt_Schedule_Of_Debt

Long-term Debt (Schedule Of Debt) (Details) (USD $)	Jul. 31, 2014	Jan. 31, 2014
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'	'
6.75% senior notes	$450,000	'
5% convertible note	132,543	129,290
Total debt	632,424	343,208
Total long-term debt	632,013	334,357
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	'	183,000
Rockpile [Member]	'	'
Debt Instrument [Line Items]	'	'
Credit facility	39,616	21,515
Notes and mortgage payable	10,265	9,403
Less current portion of credit facility	'	-8,450
Less current portion of notes and mortgages payable	($411)	($401)

Longterm_Debt_675_Senior_Notes

Long-term Debt (6.75% Senior Notes Narrative) (Details) (Senior Notes [Member], USD $)	6 Months Ended
	Jul. 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	$10,000,000
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%

Longterm_Debt_5_Convertible_No

Long-term Debt (5% Convertible Note Narrative) (Details) (Convertible Note [Member], USD $)	6 Months Ended
	Jul. 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	$12,500,000	'

Longterm_Debt_TUSA_Credit_Faci

Long-term Debt (TUSA Credit Facility Narrative) (Details) (USD $)

Jul. 31, 2014

Jul. 31, 2014

Jun. 27, 2014

Jan. 31, 2014

Jul. 31, 2014

Aug. 21, 2014

Jul. 18, 2014

14-May-14

9-May-14

Jan. 13, 2014

Jan. 12, 2014

9-May-14

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Senior Notes [Member]

Second Lien Credit Facility [Member]

Second Lien Credit Facility [Member]

TUSA [Member]

TUSA [Member]

TUSA [Member]

TUSA [Member]

TUSA [Member]

TUSA [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 [Member]

Eurodollar [Member]

Eurodollar [Member]

item

item

Second Lien Credit Facility [Member]

TUSA [Member]

TUSA [Member]

TUSA [Member]

Minimum [Member]

Maximum [Member]

TUSA [Member]

Minimum [Member]

Maximum [Member]

TUSA [Member]

TUSA [Member]

TUSA [Member]

TUSA [Member]

Line of Credit Facility [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility, maximum borrowing capacity

'

'

$60,000,000

'

'

$415,000,000

$305,500,000

'

$355,000,000

$320,000,000

$275,000,000

$100,000,000

'

'

'

'

'

'

'

'

Loan hedge percentage of anticipated production

'

'

'

85.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility, maturity date

'

16-Oct-19

'

'

16-Oct-18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility amendment increase

'

'

'

'

'

'

'

40,000,000

10,000,000

'

'

'

'

'

'

'

'

'

'

'

Credit facility, margin on dollar amount based on usage

'

'

'

'

'

'

'

'

'

0.25%

'

'

'

'

'

'

'

'

'

'

Number of new lenders under credit facility

'

'

'

'

'

'

'

'

3

3

'

'

'

'

'

'

'

'

'

'

Credit facility

'

'

'

$183,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility, basis spread on interest rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.50%

0.50%

1.50%

1.00%

1.50%

2.50%

Credit facility, fronting fee percentage

'

'

'

'

0.13%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument, interest rate

6.75%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Longterm_Debt_Second_Lien_Cred

Long-term Debt (Second Lien Credit Facility Narrative) (Details) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jul. 31, 2014	Jun. 27, 2014
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%	'

Longterm_Debt_Rockpile_Debt_Na

Long-term Debt (Rockpile Debt Narrative) (Details) (USD $)

Jul. 31, 2014

Jan. 31, 2014

Jul. 31, 2014

Mar. 25, 2014

Jan. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Mar. 25, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Nov. 20, 2013

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Jul. 31, 2014

Oct. 16, 2013

Jul. 31, 2014

Jul. 31, 2014

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]

RockPile Notes Payable to Sellers of Team Well Service, Inc. [Member]

RockPile Promissory Notes [Member]

Construction Loan Residential Units [Member]

Construction Loan Administrative And Maintenance Building [Member]

Mortgages [Member]

Mortgages [Member]

Mortgages [Member]

Unsecured Debt Loan One [Member]

Unsecured Debt Loan One [Member]

Unsecured Debt Loan Two [Member]

Unsecured Debt Loan Two [Member]

Notes Payable to Banks [Member]

RockPile Promissory Notes [Member]

Federal Funds Rate [Member]

Eurodollar Rate Plus 1% [Member]

Letter of Credit [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

Rockpile [Member]

RockPile Mortgage Payable to Dacotah Bank [Member]

RockPile Mortgage Payable to Dacotah Bank [Member]

RockPile Mortgage Payable to Dacotah Bank [Member]

RockPile Hauch Apartments Mortgage [Member]

RockPile Hauch Apartments Mortgage [Member]

Rockpile [Member]

RockPile Notes Payable to Sellers of Team Well Service, Inc. [Member]

Rockpile [Member]

Rockpile [Member]

RockPile Mortgage Payable to Dacotah Bank [Member]

RockPile Notes Payable to Sellers of Team Well Service, Inc. [Member]

Eurodollar Rate Plus 1% [Member]

Eurodollar [Member]

Eurodollar Rate Plus 1% [Member]

Eurodollar [Member]

item

item

item

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility, maximum borrowing capacity

'

'

'

$100,000,000

'

'

'

'

'

$150,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility, basis spread on interest rate

'

'

'

'

'

0.50%

1.00%

'

'

'

'

'

'

'

'

'

3.00%

'

'

2.80%

'

2.70%

'

'

'

'

'

'

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

'

'

3.22%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ratio of consolidated debt to EBITDA

'

'

2.75

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ratio of Adjusted EBITDA to Fixed Charges

'

'

1.25

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of secured loans

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

Number of unsecured loans

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

Carrying value of debt

632,424,000

343,208,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,500,000

4,400,000

'

'

'

'

'

'

'

'

'

Debt term

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'15 years

'

'15 years

'

'

'

'

'

'

Debt instrument, maturity date

'

'

'

'

'

'

'

25-Mar-19

'

'

'

'

'

'

'

'

'

'

'

15-Dec-28

'

'

'

16-Oct-16

16-Oct-16

'

'

'

Debt, interest rate at period end

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4.75%

'

'

'

'

'

'

Credit facility

'

'

39,616,000

'

21,515,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,400,000

'

'

'

'

'

900,000

Debt instrument, interest rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.00%

'

'

'

'

'

'

'

'

'

'

'

'

Number of units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12

'

'

'

'

'

'

Debt instrument, face amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

'

'

'

1,800,000

'

500,000

'

'

500,000

'

'

Purchase price of apartment building

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1,500,000

'

'

'

'

'

'

'

Redeemed RockPile B-Units

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

180,000

'

'

'

'

'

'

'

'

'

'

'

Derivative_Instruments_Narrati

Derivative Instruments (Narrative) (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Share data, unless otherwise specified	Jul. 31, 2014	Jul. 31, 2013	Jul. 31, 2014	Jul. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Loss from commodity derivative activities	$921	$4,399	$6,377	$3,187
Gain (loss) on equity investment derivative	'	'	2,919	'
Gain (loss) on equity investment derivative	-7,534	'	2,920	'
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	-5,200	'	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	-2,300	'	1,200	'
Caliber Midstream LP [Member] | Class A Units [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Equity method investments, Class A units exercise price	'	'	$10.20	'
Equity method investments, Class A units decrease in exercise price	$1.08	'	'	'
Equity method investments, Class A units increase in exercise price	'	'	$0.20	'
Caliber Midstream LP [Member] | Class A Trigger Unit Warrant [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Increase (decrease) in equity method investment	'	'	$532	'

Derivative_Instruments_Schedul

Derivative Instruments (Schedule Of Derivative Instruments In Statement Of Financial Position, Fair Value) (Details) (USD $)	Jul. 31, 2014	Jan. 31, 2014
In Thousands, unless otherwise specified
Crude Oil Derivative Contract [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Asset	$978	'
Derivative Liabilities	-994	'
Crude Oil Derivative Contract [Member] | Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	-1,972	'
Crude Oil Derivative Contract [Member] | Current Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	'	1,066
Derivative Asset, Fair Value, Gross Liability	'	-111
Derivative Assets	'	955
Crude Oil Derivative Contract [Member] | Long-Term Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	605	1,192
Derivative Asset, Fair Value, Gross Liability	-469	'
Derivative Assets	136	1,192
Equity Investment Derivative [Member] | Equity Investment [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	2,870	39,734
Derivative Assets	$2,870	$39,734

Derivative_Instruments_Summary

Derivative Instruments (Summary Of Derivative Instruments) (Details)	6 Months Ended
	Jul. 31, 2014
Fiscal 2015 Collar [Member]	'
Derivative [Line Items]	'
End date	'Fiscal Year 2015
Basis	'NYMEX	[1]
Quantity, (bopd)	5,767
Put strike price	87.33
Call strike price	100.71
Fiscal 2015 Swap [Member]	'
Derivative [Line Items]	'
End date	'Fiscal Year 2015
Basis	'NYMEX	[1]
Quantity, (bopd)	166
Weighted average price	94.5
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 prices of West Texas Intermediate crude oil at Cushing, Oklahoma as quoted on the New York Mercantile Exchange.

Fair_Value_Measurements_Narrat

Fair Value Measurements (Narrative) (Details) (USD $)	Jul. 31, 2014	Jan. 31, 2014
In Thousands, except Per Share data, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Common stock closing price	$10.80	$7.61
Convertible Note [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Fair value liability	$245,298	$169,170
Debt instrument, interest rate	5.00%	5.00%
Senior Notes [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Debt instrument, interest rate	6.75%	'

Fair_Value_Measurements_Schedu

Fair Value Measurements (Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis) (Details) (USD $)	6 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Jul. 31, 2014	Jan. 31, 2014
Crude Oil Derivative Contract [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative Liabilities	($994)	'
Fair Value, Measurements, Recurring [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative assets	2,870	39,734
Derivative Liabilities	-994	'
Earn-out liability	-1,791	-1,739
Fair Value, Measurements, Recurring [Member] | Crude Oil Derivative Contract [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative assets	136	2,147
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative Liabilities	-994	'
Earn-out liability	-1,791	-1,739
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Crude Oil Derivative Contract [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative assets	136	2,147
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Derivative assets	$2,870	$39,734

Fair_Value_Measurements_Rollfo

Fair Value Measurements (Rollforward Of Level 3 Financial Assets And Liabilities) (Details) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jul. 31, 2014		Jul. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Interest paid in-kind	$3,532		$2,545
Convertible Note [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Liabilities, Beginning balance	-169,170		'
Interest paid in-kind	-3,252		'
Net unrecognized loss	-72,876		'
Liabilities, Ending balance	-245,298		'
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	[1]	'
Net unrealized gain	1,174	[1]	'
Assets, Ending Balance	$2,870	[1]	'
[1]	Includes Caliber Class A Trigger Unit Warrant and Class A (Series 1 through Series 4) Warrants

Commitments_and_Contingencies_

Commitments and Contingencies (Narrative) (Details) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jul. 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%
Multiple Drilling Rig Contracts [Member]	'
Commitments and Contingencies [Line Items]	'
Number of drilling rigs subject to commitments	4
Early termination of contract commitments amount	14

Capital_Stock_Narrative_Detail

Capital Stock (Narrative) (Details) (USD $)	6 Months Ended
	Jul. 31, 2014	Feb. 20, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Maximum authorized shares may be issued as percent of issued and outstanding shares	10.00%	'
Expiration period	'10 years	'
Restricted Stock Units (RSUs) [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Units granted, number of units	859,600	'
Unrecognized compensation	16,800,000	'
Unrecognized compensation, recognition period	'2 years 10 months 24 days	'
Employee Stock Option [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Unrecognized compensation, recognition period	'3 years 10 months 24 days	'
Stock options issued during period	0	'
Unrecognized compensation cost related to stock options	17,300,000	'
Series B Units [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Share-based awards vesting period	'3 years	'
Unrecognized compensation cost related to stock options	2,900,000	'
2011 Omnibus Incentive Plan [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Maximum shares reserved under Plan	5,900,000	'
RockPile LLC Agreement [Member] | RockPile Promissory Notes [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Debt instrument, face amount	1,000,000	'
RockPile LLC Agreement [Member] | Series B Units [Member]	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Maximum shares reserved under Plan	'	6,000,000
Units granted, number of units	1,412,000	'
RockPile LLC Agreement [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	'
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	495,892	'

Capital_Stock_NonCash_StockBas

Capital Stock (Non-Cash Stock-Based Compensation Cost) (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jul. 31, 2014	Jul. 31, 2013	Jul. 31, 2014	Jul. 31, 2013
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'	'	'
Compensation expense before capitalized amount	$2,117	$1,794	$4,464	$3,670
Less amounts capitalized to oil and natural gas properties	-310	-356	-649	-637
Stock-based compensation	1,807	1,438	3,815	3,033
Restricted Stock Units (RSUs) [Member]	'	'	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'	'	'
Compensation expense before capitalized amount	1,503	1,695	3,274	3,360
Employee Stock Option [Member]	'	'	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'	'	'
Compensation expense before capitalized amount	487	'	973	'
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	$127	$99	$217	$310

Capital_Stock_Restricted_Stock

Capital Stock (Restricted Stock Units Outstanding) (Details) (Restricted Stock Units (RSUs) [Member], USD $)	6 Months Ended
	Jul. 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	859,600
Units granted, Weighted Average Award Date Fair Value	$8.73
Units forfeited	-302,085
Units forfeited, Weighted Average Award Date Fair Value	$7.13
Units that vested, Number of Shares	-739,710
Units that vested, Weighted Average Award Date Fair Value	$7.20
Outstanding, Unvested Ending Balance	2,693,429
Outstanding, Weighted-Average Grant Date Fair Value, Ending Balance	$7.09

Capital_Stock_Stock_Options_Ou

Capital Stock (Stock Options Outstanding) (Details) (USD $)	6 Months Ended
	Jul. 31, 2014	Jan. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'
Options outstanding, ending balance	6,108,333	'
Weighted average exercise price, options outstanding ending balance	$11.07	'
Rolling Plan And CEO Option Grant [Member] | 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	'	'
Options outstanding, ending balance	6,108,333	'
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	'	'
Weighted average exercise price, options outstanding ending balance	$11.07	'
Options exercisable	708,333	108,333

Capital_Stock_Stock_Options_Ou1

Capital Stock (Stock Options Outstanding By Exercise Price) (Details) (USD $)	6 Months Ended
	Jul. 31, 2014
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'
Outstanding options	6,108,333
Number of shares exercise	708,333
Weighted average exercise price per share	$11.07
Weighted average remaining contractual life (years)	'8 years 9 months 11 days
Weighted average exercise price per share (exercisable)	$9.72
Weighted average remaining contractual life (years) (exercisable)	'7 years 7 months 13 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	'7 months 2 days
Outstanding options	108,333
Number of shares exercise	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	'9 years 2 months 5 days
Outstanding options	750,000
Number of shares exercise	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	'9 years 2 months 5 days
Outstanding options	750,000
Number of shares exercise	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	'9 years 2 months 5 days
Outstanding options	1,500,000
Number of shares exercise	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	'9 years 2 months 5 days
Outstanding options	1,500,000
Number of shares exercise	150,000
$15.00 [Member]	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'
Exercise price per share	$15
Remaining contractual life	'9 years 2 months 5 days
Outstanding options	1,500,000
Number of shares exercise	150,000

Capital_Stock_Summary_Of_Serie

Capital Stock (Summary Of Series B Unit Vesting Status) (Details)	6 Months Ended
	Jul. 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	2,589,667
Grants, Number of Unvested Units	2,712,333
Remaining vesting period	'3 years
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	15,000
Grants, Number of Unvested Units	45,000
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)	Jul. 31, 2014	Jan. 31, 2014	Jul. 31, 2014
In Millions, unless otherwise specified	Convertible Note [Member]	Convertible Note [Member]	CEO Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'	'
Anitdilutive securities excluded from calculation of diluted net income	'	'	4.5
Debt Instrument, Interest Rate, Stated Percentage	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		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jul. 31, 2014	Jul. 31, 2013	Jul. 31, 2014	Jul. 31, 2013
Earnings Per Share [Abstract]	'	'	'	'
Net income attributable to common stockholders	$14,552	$6,799	$29,094	$12,010
Effect of 5% Convertible Note conversion	996	'	1,983	'
Net income attributable to common stockholders after effect of debt conversion	$15,548	$6,799	$31,077	$12,010
Basic weighted average common shares outstanding	86,172	56,451	86,064	54,561
Effect of dilutive securities	17,602	561	17,447	528
Diluted weighted average common shares outstanding	103,774	57,012	103,511	55,089
Basic net income per share	$0.17	$0.12	$0.34	$0.22
Diluted net income per share	$0.15	$0.12	$0.30	$0.22

Income_Taxes_Narrative_Details

Income Taxes (Narrative) (Details) (USD $)	6 Months Ended
	Jul. 31, 2014
Income Taxes [Abstract]	'
Effective income tax rate	41.20%
Unrecognized tax benefits	$0

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	3 Months Ended		6 Months Ended			3 Months Ended	6 Months Ended
	Jul. 31, 2014	Jul. 31, 2013	Jul. 31, 2014	Jul. 31, 2013	14-May-14	Jul. 31, 2014	Jul. 31, 2014	Jul. 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	'	'	'	'	'	387,600,000	387,600,000	'	'
Revenues from related parties	'	'	'	'	'	8,400,000	12,200,000	'	'
Revenues	141,989,000	50,394,000	241,771,000	84,688,000	'	9,600,000	13,700,000	'	'
Reimbursed administrative services from Caliber	'	'	'	'	'	300,000	600,000	'	'
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	'

Supplemental_Disclosures_Of_Ca1

Supplemental Disclosures Of Cash Flow Information (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jul. 31, 2014	Jul. 31, 2013	Jul. 31, 2014	Jul. 31, 2013
Supplemental Disclosures of Cash Flow Information [Abstract]	'	'	'	'
Interest expense	'	'	$4,717	$1,042
Income taxes	'	'	550	'
Increased (decreased) accrued liabilities and prepaid well costs	'	'	37,151	6,700
Capitalized stock-based compensation	310	356	649	637
Change in asset retirement obligations	'	'	1,106	92
Capitalized interest	'	'	1,808	1,100
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)	6 Months Ended	12 Months Ended
	Jul. 31, 2014	Jan. 31, 2014
	item	item
Reserve Quantities [Line Items]	'	'
Productive oil wells, number of wells, net	98	50
Percentage of increase (decrease) in productive oil wells, net	96.00%	'
Percentage of increase (decrease) in future development oil wells, net	8.00%	'
Future development wells, number of wells, net	48.4	52.5
Crude Oil Reserves [Member]	'	'
Reserve Quantities [Line Items]	'	'
Industry average, sales price per unit	88.97	93.09
Natural Gas Reserves [Member]	'	'
Reserve Quantities [Line Items]	'	'
Industry average, sales price per unit	5.72	3.99
Natural Gas Liquids [Member]	'	'
Reserve Quantities [Line Items]	'	'
Industry average, sales price per unit	44.82	44.1

Significant_Changes_in_Proved_2

Significant Changes in Proved Oil And Natural Gas Reserves (Proved Oil And Gas Reserves) (Details)	Jul. 31, 2014	Jan. 31, 2014
	MBoe	MBoe
Reserve Quantities [Line Items]	'	'
Proved Developed, Percentage of Reserves	58.00%	'
Proved Developed, (Mboe)	30,030	16,995
Proved Undeveloped, Percentage of Reserves	42.00%	'
Proved Undeveloped, (Mboe)	21,630	23,319
Total Proved, Percentage of Reserves	100.00%	'
Total Proved, (Mboe)	51,660	40,314
Crude Oil Reserves [Member]	'	'
Reserve Quantities [Line Items]	'	'
Proved Developed, Volume	24,213	'
Proved Undeveloped, Volume	16,849	'
Total Proved, Volume	41,062	'
Natural Gas Reserves [Member]	'	'
Reserve Quantities [Line Items]	'	'
Proved Developed, Volume	20,000	'
Proved Undeveloped, Volume	14,371	'
Total Proved, Volume	34,371	'
Natural Gas Liquids [Member]	'	'
Reserve Quantities [Line Items]	'	'
Proved Developed, Volume	2,484	'
Proved Undeveloped, Volume	2,386	'
Total Proved, Volume	4,870	'