Annual report pursuant to Section 13 and 15(d)

Supplemental Oil and Gas Information - Changes in Standardized Measure of Discounted Future Net Cash Flows (Details)

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Supplemental Oil and Gas Information - Changes in Standardized Measure of Discounted Future Net Cash Flows (Details) (USD $)
In Thousands, unless otherwise specified
 12 Months Ended
Jun. 30, 2013
Jun. 30, 2012
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]    
Standardized measure of discounted future net cash flows for Fiscal year ended $ 130,075 $ 110,280
Net change in prices and production costs (8,579) 18,517
Extensions and discoveries   6,785
Acquisitions of reserves   31,456
Revisions of previous quantity estimates (26,311) (31,702)
Changes in estimated future development costs 3,478 (2,830)
Sales and transfers of oil and gas produced (19,622) (1,205)
Previously estimated development cost incurred during the period 3,426 5,841
Accretion of discount 20,285 [1] 0
Net change in income taxes 23,835 (3,233)
Net change in timing and other (18,911) (3,834)
Standardized measure of discounted future net cash flows for Fiscal year ended 107,676 130,075
United States
    
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]    
Standardized measure of discounted future net cash flows for Fiscal year ended 121,496 110,016
Net change in prices and production costs (7,955) 18,517
Extensions and discoveries   6,785
Acquisitions of reserves   26,584
Revisions of previous quantity estimates (26,503) (37,846)
Changes in estimated future development costs 3,473 (2,275)
Sales and transfers of oil and gas produced (20,178) (941)
Previously estimated development cost incurred during the period 3,419 5,841
Accretion of discount 19,269 [1] 0
Net change in income taxes 22,258 (1,657)
Net change in timing and other (17,888) (3,528)
Standardized measure of discounted future net cash flows for Fiscal year ended 97,391 121,496
Australia
    
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]    
Standardized measure of discounted future net cash flows for Fiscal year ended 8,579 264
Net change in prices and production costs (624) 0
Extensions and discoveries   0
Acquisitions of reserves   4,872
Revisions of previous quantity estimates 192 6,144
Changes in estimated future development costs 5 (555)
Sales and transfers of oil and gas produced 556 (264)
Previously estimated development cost incurred during the period 7 0
Accretion of discount 1,016 [1] 0
Net change in income taxes 1,577 (1,576)
Net change in timing and other (1,023) (306)
Standardized measure of discounted future net cash flows for Fiscal year ended $ 10,285 $ 8,579
[1] For fiscal year 2012, the Company assumed no accretion in value of proved oil reserves in the US and Australia. Accretion, with respect to measuring the changes in the standardized measure of reserves values, represents the value benefit of being closer in time, relative to the prior fiscal year's standardized measure, to future cash flows in the reserve projections. During fiscal year 2012, in the US, the Company did not develop its US proved oil reserves in accordance with the reserve plans in place at the beginning of the year, but instead postponed such plans by one year. Therefore, the benefit of accretion of the prior fiscal year's reserves should not have factored into the value of the standardized measure for fiscal year 2012. During fiscal year 2012, in Australia, the reserves at the beginning of the year had been sold entirely during the fiscal year as the long term gas sales contract in place at Palm Valley expired by its term in January 2012. As such, accretion of prior year reserves was not relevant in this case.(2) For fiscal year 2013, in the US, there was a $17,888 downward revision in reserves value due to changes in timing and other. This revision primarily relates to the change, relative to the prior year reserves projections, in the expected timing of drilling and completing PUD wells and the attendant cash flow expected from these wells. During fiscal year 2013, the Company focused its activities at Poplar on executing water shutoff treatments due to their potential attractive economics. As a result, PUDs previously estimated to be drilled during fiscal year 2013 were postponed, resulting in a change in the annual quantity and timing of PUD wells to be drilled in the current reserves projections.