Significant Changes In Proved Reserve Estimates	9 Months Ended
Oct. 31, 2011
Significant Changes in Proved Reserve Estimates [Abstract]
Significant Changes in Proved Reserve Estimates	7. Significant Changes in Proved Reserve Estimates Changes in proved reserves under SEC rules and guidelines The Company's senior reservoir engineer prepared internal estimates (using SEC rules and guidelines) of the Company's total proved and total proved undeveloped oil and gas reserves as of October 31, 2011. Those estimates are approximately 80% to 90% greater than the Company's total proved reserves of 1,235 MBoe and total proved undeveloped reserves of 1,021 MBoe as of January 31, 2011, as disclosed on page F-17 of the Company's Annual Report filed on Form 10-K for the fiscal year ended January 31, 2011. The January 31, 2011 estimated proved reserves were prepared by MHA Petroleum Consultants, whose report is filed as an exhibit to the Annual Report. The Company has engaged Ryder Scott Company L.P., an independent petroleum consulting company, to estimate the Company's proved oil and gas reserves as of January 11, 2012 for the Company's Annual Report on Form 10-K. The increases in proved reserves are primarily attributable to (a) Company exploration and development activities in North Dakota since January 31, 2011 and (b) the Company's ability to recognize additional proved undeveloped locations, as a result of (i) more producing wells offsetting some of the Company's undeveloped acreage, (ii) the Company's ability to fund development of the proved undeveloped locations after receiving $142 million in proceeds from the sale of common stock in March 2011 and (iii) the Company's acquisitions after January 31, 2011 of additional undeveloped properties in North Dakota. The proved reserves at January 31, 2011 and October 31, 2011 are in the Bakken formation or the Three Forks formation in areas within McKenzie County, Williams County or Dunn County, North Dakota. The Company's senior reservoir engineer has been a Registered Professional Engineer in Colorado since 1984, and has over 15 years' experience as a petroleum engineer. The internal estimates of proved reserves are based on available geoscience and engineering data including North Dakota online files of monthly production for wells in which the Company has an interest and wells adjacent to drill spacing units in which the Company has an interest. The internal reserve schedules and certain supporting schedules are reviewed by various members of management before the senior reservoir engineer prepares a final internal summary of proved reserves and a final listing (by well and drilling location) of proved reserves. Changes in proved reserves under Canadian rules and guidelines On April 19, 2011, the Company filed with Canada the Company's Form 51-101F1 (Statements of Reserves Data and Other Oil and Gas Information). The filing is viewable under the Company's profile on SEDAR at www.sedar.com. As explained more fully on page 8 of the Company's Annual Report on Form 10-K for the fiscal year ended January 31, 2011, the Canadian rules and guidelines for calculation of proved and probable reserves at January 31, 2011 reported in Form 51-101F1 differ from SEC rules and guidelines. The reserve estimates at January 31, 2011 under Canadian rules and guidelines were also prepared by MHA Petroleum Consultants. The Company's senior reservoir engineer prepared internal estimates of the Company's total proved oil and gas reserves as of October 31, 2011, using Canadian rules and guidelines. Those estimates also are approximately 80% to 90% greater than the Company's total proved oil and gas reserves at January 31, 2011 disclosed in the Form 51-101F1 of April 19, 2011. The Form 51-101F1 showed no probable reserves. The Company did not prepare any internal estimates of probable reserves as of October 31, 2011 under Canadian rules and guidelines. In computing barrels of oil equivalent ("boes"), gas was converted into oil in the ratio of 6 mcf to 1 barrel of oil. A boe conversion ratio of 6 mcf to 1 barrel is based on an energy equivalency conversion method and does not represent a value equivalency.

7. Significant Changes in Proved Reserve Estimates

Changes in proved reserves under SEC rules and guidelines

The Company's senior reservoir engineer prepared internal estimates (using SEC rules and guidelines) of the Company's total proved and total proved undeveloped oil and gas reserves as of October 31, 2011. Those estimates are approximately 80% to 90% greater than the Company's total proved reserves of 1,235 MBoe and total proved undeveloped reserves of 1,021 MBoe as of January 31, 2011, as disclosed on page F-17 of the Company's Annual Report filed on Form 10-K for the fiscal year ended January 31, 2011. The January 31, 2011 estimated proved reserves were prepared by MHA Petroleum Consultants, whose report is filed as an exhibit to the Annual Report. The Company has engaged Ryder Scott Company L.P., an independent petroleum consulting company, to estimate the Company's proved oil and gas reserves as of January 11, 2012 for the Company's Annual Report on Form 10-K.

The increases in proved reserves are primarily attributable to (a) Company exploration and development activities in North Dakota since January 31, 2011 and (b) the Company's ability to recognize additional proved undeveloped locations, as a result of (i) more producing wells offsetting some of the Company's undeveloped acreage, (ii) the Company's ability to fund development of the proved undeveloped locations after receiving $142 million in proceeds from the sale of common stock in March 2011 and (iii) the Company's acquisitions after January 31, 2011 of additional undeveloped properties in North Dakota.

The proved reserves at January 31, 2011 and October 31, 2011 are in the Bakken formation or the Three Forks formation in areas within McKenzie County, Williams County or Dunn County, North Dakota.

The Company's senior reservoir engineer has been a Registered Professional Engineer in Colorado since 1984, and has over 15 years' experience as a petroleum engineer. The internal estimates of proved reserves are based on available geoscience and engineering data including North Dakota online files of monthly production for wells in which the Company has an interest and wells adjacent to drill spacing units in which the Company has an interest. The internal reserve schedules and certain supporting schedules are reviewed by various members of management before the senior reservoir engineer prepares a final internal summary of proved reserves and a final listing (by well and drilling location) of proved reserves.

Changes in proved reserves under Canadian rules and guidelines

On April 19, 2011, the Company filed with Canada the Company's Form 51-101F1 (Statements of Reserves Data and Other Oil and Gas Information). The filing is viewable under the Company's profile on SEDAR at www.sedar.com. As explained more fully on page 8 of the Company's Annual Report on Form 10-K for the fiscal year ended January 31, 2011, the Canadian rules and guidelines for calculation of proved and probable reserves at January 31, 2011 reported in Form 51-101F1 differ from SEC rules and guidelines. The reserve estimates at January 31, 2011 under Canadian rules and guidelines were also prepared by MHA Petroleum Consultants.

The Company's senior reservoir engineer prepared internal estimates of the Company's total proved oil and gas reserves as of October 31, 2011, using Canadian rules and guidelines. Those estimates also are approximately 80% to 90% greater than the Company's total proved oil and gas reserves at January 31, 2011 disclosed in the Form 51-101F1 of April 19, 2011. The Form 51-101F1 showed no probable reserves. The Company did not prepare any internal estimates of probable reserves as of October 31, 2011 under Canadian rules and guidelines. In computing barrels of oil equivalent ("boes"), gas was converted into oil in the ratio of 6 mcf to 1 barrel of oil. A boe conversion ratio of 6 mcf to 1 barrel is based on an energy equivalency conversion method and does not represent a value equivalency.