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Supplemental Disclosures about Oil and Natural Gas Producing Properties (unaudited) (Tables)
 12 Months Ended
Jun. 30, 2014
Oil and Gas Exploration and Production Industries Disclosures [Abstract]  
Schedule of costs incurred and capitalized in oil and natural gas property acquisition, exploration and development activities
Exploration and development costs also include amounts incurred due to the recognition of asset retirement obligations, of $66,976, $65,575, and $93,522, during the years ended June 30, 2014, 2013, and 2012 , respectively.
 
For the Years Ended June 30,
 
2014
 
2013
 
2012
Oil and natural gas activities
 
 
 
 
 
Property acquisition costs:
 
 
 
 
 
Proved property
$
—

 
$
26,449

 
$
115,637

Unproved property
47,344

 
195,599

 
5,544,217

Exploration costs
757,423

 
4,356,640

 
3,016,924

Development costs
18,566

 
79,035

 
238,463

Total costs incurred for oil and natural gas activities
$
823,333

 
$
4,657,723

 
$
8,915,241
Schedule of estimated quantities of proved oil and natural gas reserves and changes in quantities of proved developed and undeveloped reserves
Estimated quantities of proved oil and natural gas reserves and changes in quantities of proved developed and undeveloped reserves for each of the periods indicated were as follows:
 
Crude Oil
(Bbls)
 
Natural Gas
Liquids
(Bbls)
 
Natural Gas
(Mcf)
 
BOE
Proved developed and undeveloped reserves:
 
 
 
 
 
 
 
June 30, 2011
11,567,846

 
712,300

 
9,403,899

 
13,847,462

Revisions of previous estimates
84,219

 
(212,677
)
 
(1,295,893
)
 
(344,440
)
Improved recovery, extensions and discoveries
137,634

 
5,461

 
18,925

 
146,249

Production (sales volumes)
(151,081
)
 
(12,611
)
 
(266,775
)
 
(208,155
)
June 30, 2012
11,638,618

 
492,473

 
7,860,156

 
13,441,116

Revisions of previous estimates (a)
1,826,053

 
975,515

 
27,679

 
2,806,181

Sales of minerals in place
(485,536
)
 
(480,832
)
 
(7,726,032
)
 
(2,254,038
)
Production (sales volumes)
(196,380
)
 
(7,271
)
 
(139,006
)
 
(226,819
)
June 30, 2013
12,782,755

 
979,885

 
22,797

 
13,766,440

Revisions of previous estimates (b)
(1,919,052
)
 
1,269,588

 
2,412,677

 
(247,350
)
Improved recovery, extensions and discoveries
17,146

 
32,731

 
498,044

 
132,884

Sales of minerals in place
(184,722
)
 
—

 
—

 
(184,722
)
Production (sales volumes)
(169,783
)
 
(3,516
)
 
(26,655
)
 
(177,742
)
June 30, 2014
10,526,344

 
2,278,688

 
2,906,863

 
13,289,510

Proved developed reserves:
 
 
 
 
 
 
 
June 30, 2011
4,986,337

 
100,900

 
1,543,401

 
5,344,471

June 30, 2012
7,670,934

 
111,978

 
1,499,382

 
8,032,809

June 30, 2013
10,077,522

 
8,539

 
22,797

 
10,089,861

June 30, 2014
7,858,224

 
32,164

 
481,042

 
7,970,562



(a) A significant upward reserve revision occurred in the Delhi Field during fiscal 2013 as a result of (1) revised geological maps based on production results and acquired seismic data, (2) inclusion of an additional reservoir with similar features, production history and suitability for EOR, and (3) inclusion of natural gas processing at Delhi.

(b) Significant reserve revisions occurred in the Delhi Field during fiscal 2014. As a result of an adverse fluid release event in the Field, certain oil reserves were reclassified from proved to an unproved category based on the operator's decision to defer CO2 injections in certain parts of the Field. There was a positive revision to estimated proved reserves of natural gas liquids and natural gas as a result of an improved design for the gas plant in the Delhi Field. The plant is expected to significantly increase recoveries of these products
Schedule of standardized measure of discounted future net cash flows related to proved oil and natural gas reserves
The standardized measure of discounted future net cash flows related to proved oil and natural gas reserves as of June 30, 2014, 2013, and 2012 are as follows:
 
For the Years Ended June 30,
 
2014
 
2013
 
2012
Future cash inflows
$
1,193,515,075

 
$
1,436,980,607

 
$
1,355,686,188

Future production costs and severance taxes
(475,387,931
)
 
(510,902,614
)
 
(458,716,938
)
Future development costs
(46,154,178
)
 
(60,742,406
)
 
(38,458,724
)
Future income tax expenses
(195,581,510
)
 
(275,113,560
)
 
(296,703,838
)
Future net cash flows
476,391,456

 
590,222,027

 
561,806,688

10% annual discount for estimated timing of cash flows
(250,313,784
)
 
(283,001,328
)
 
(278,209,195
)
Standardized measure of discounted future net cash flows
$
226,077,672

 
$
307,220,699

 
$
283,597,493
Schedule of NYMEX prices used in determining future cash flows
Future cash inflows represent expected revenues from production of period-end quantities of proved reserves based on the previous 12 months unweighted arithmetic average first-day-of-the-month commodity prices for each year and reflect adjustments for lease quality, transportation fees, energy content and regional price differentials.
 
Year Ended June 30,
 
2014
 
2013
 
2012
 
Oil
(Bbl)
 
Gas
(MMBtu)
 
Oil
(Bbl)
 
Gas
(MMBtu)
 
Oil
(Bbl)
 
Gas
(MMBtu)
NYMEX prices used in determining future cash flows
$
100.37

 
$
4.10

 
$
91.51

 
$
3.44

 
$
95.67

 
$
3.15
Schedule of changes in the standardized measure of discounted future net cash flows applicable to proved crude oil, natural gas liquids, and natural gas reserves
A summary of the changes in the standardized measure of discounted future net cash flows applicable to proved crude oil, natural gas liquids, and natural gas reserves is as follows:
 
For the Years Ended June 30,
 
2014
 
2013
 
2012
Balance, beginning of year
$
307,220,699

 
$
283,597,493

 
$
228,447,954

Net changes in sales prices and production costs related to future production
(73,439,526
)
 
(35,184,725
)
 
76,942,613

Changes in estimated future development costs
9,848,614

 
(566,125
)
 
6,340,123

Sales of oil and gas produced during the period, net of production costs
(16,479,934
)
 
(19,569,182
)
 
(16,187,039
)
Net change due to extensions, discoveries, and improved recovery
775,574

 
—

 
1,606,122

Net change due to revisions in quantity estimates
(23,757,788
)
 
64,817,544

 
(11,975,496
)
Net change due to sales of minerals in place
(3,150,277
)
 
(34,119,027
)
 
—

Development costs incurred during the period
—

 
747,656

 
(2,639,398
)
Accretion of discount
45,896,187

 
41,678,733

 
22,568,868

Net change in discounted income taxes
58,073,450

 
10,175,957

 
(15,026,628
)
Net changes in timing of production and other (a)
(78,909,327
)
 
(4,357,625
)
 
(6,479,626
)
Balance, end of year
$
226,077,672

 
$
307,220,699

 
$
283,597,493


(a) The operator has expressed current plans to produce the Delhi Field at lower production rates. The decision to produce these reserves at lower rates over a longer period of time did not materially change the total quantities expected to be recovered, but resulted in a significant reduction in the discounted value of these reserves as of