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Supplemental Disclosures about Oil and Natural Gas Producing Properties (unaudited) (Tables)
 12 Months Ended
Jun. 30, 2021
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
The following table summarizes costs incurred and capitalized in oil and natural gas property acquisition, exploration, and development activities. Property acquisition costs are those costs incurred to lease property, including both undeveloped leasehold, and the purchase of reserves in place. Exploration costs include costs of identifying areas that may warrant examination, examining specific areas that are considered to have prospects containing oil and natural gas reserves, costs of drilling exploratory wells, geologic and geophysical assessment costs, and carrying costs on undeveloped properties. Development costs are incurred to obtain access to proved reserves, including the cost of drilling. Development costs also include amounts incurred due to the recognition of asset retirement obligations of $2,883,426 and $918,137 during the years ended June 30, 2021 and 2020, respectively.
 For the Years Ended June 30,
 20212020
Oil and Natural Gas Activities  
Property acquisition costs:  
Proved property$18,297,013 $9,337,716 
Unproved property— — 
Exploration costs— — 
Development costs3,435,836 2,430,510 
Total costs incurred for oil and natural gas activities$21,732,849 $11,768,226 
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, natural gas, and natural gas liquids reserves and changes in quantities of proved developed and undeveloped reserves for each of the periods indicated are as follows:
Oil
(Bbls)		NGLs
(Bbls)		Natural Gas
(Mcf)		BOE
Proved developed and undeveloped reserves:    
June 30, 20197,615,731 1,364,761 — 8,980,492 
Revisions of previous estimates (a) (2,177,787)734,169 — (1,443,618)
Improved recovery, extensions and discoveries— — — — 
Sales of minerals in place— — — — 
Purchase of reserves in place (c)3,426,756 — 3,426,756 
Production (sales volumes)(638,464)(106,340)— (744,804)
June 30, 20208,226,236 1,992,590 — 10,218,826 
Revisions of previous estimates (b)661,711 93,139 330 754,905 
Improved recovery, extensions and discoveries— — — — 
Purchase of reserves in place (c)86,608 4,957,226 49,533,801 13,299,468 
Sales of minerals in place— — — — 
Production (sales volumes)(554,888)(171,451)(963,496)(886,922)
June 30, 20218,419,667 6,871,504 48,570,635 23,386,277 
Proved developed reserves:    
June 30, 20196,273,907 1,124,302 — 7,398,209 
June 30, 20206,577,731 1,777,236 — 8,354,967 
June 30, 20216,815,126 6,662,952 48,570,634 21,573,184 
Proved undeveloped reserves:
June 30, 20191,341,824 240,459 — 1,582,283 
June 30, 20201,648,505 215,354 — 1,863,859 
June 30, 20211,604,541 208,551 — 1,813,092 
(a) Revisions in fiscal year 2020 were primarily due to negative revisions at Hamilton Dome field reflecting the impact of pricing on future economic production. In March 2020 when the oil price decreased, the operator began to shut-in wells that were not economic at those lower prices to try and keep the field cash flow positive. The use of an SEC price deck for our reserves at June 30, 2020, precludes volumes that are uneconomic at such prices. Positive NGL revisions at Delhi field reflect adjusted methodology of forecasting NGLs independently from the oil production as forecasted by our independent reservoir engineering firm.
(b) Revisions in fiscal year 2021 were primarily due to positive revisions at Hamilton Dome reflecting the impact of increased oil pricing in the field on future production and extension of reserves economic limit. Positive NGL revisions at Delhi field reflect the impact of increased pricing on future production and the extension of reserves economic limit. Positive natural gas revisions in the Barnett Shale reflect the impact of increased natural gas prices from the date of the Barnett Shale Acquisition on May 7, 2021 to the end of the fiscal year on June 30, 2021.
(c) On May 7, 2021, the Company acquired the Barnett Shale assets from Tokyo Gas Americas for $18.3 million, net of preliminary purchase price adjustments. On November 1, 2019, the Company acquired certain mineral interests in the Hamilton Dome field from Merit, who owns the vast majority of the remaining working interest in the field.
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, 2021 and 2020 are as follows:
 As of June 30,
 20212020
Future cash inflows$632,620,246 $399,358,481 
Future production costs and severance taxes(398,021,728)(240,399,715)
Future development costs(29,339,399)(24,623,426)
Future income tax expenses(42,368,085)(21,982,469)
Future net cash flows162,891,034 112,352,871 
10% annual discount for estimated timing of cash flows(75,308,483)(49,862,035)
Standardized measure of discounted future net cash flows$87,582,551 $62,490,836 
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.
 For the Years Ended June 30,
 20212020
 Oil
(Bbl)		Gas
(MMBtu)		Oil
(Bbl)		Gas
(MMBtu)
NYMEX prices used in determining future cash flows$49.72 $2.46 $47.37 n/a
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 oil, natural gas, and natural gas liquids reserves is as follows:
For the Years Ended June 30,
20212020
Balance, beginning of the fiscal year$62,490,836 $126,732,042 
Net changes in sales prices and production costs related to future production11,538,209 (83,857,342)
Changes in estimated future development costs403,109 (4,099,792)
Sales of oil and gas produced during the period, net of production costs(16,115,302)(16,093,794)
Net change due to extensions, discoveries, and improved recovery— — 
Net change due to revisions in quantity estimates6,840,767 (6,746,316)
Net change due to purchase of minerals in place31,461,405 10,364,875 
Development costs incurred during the period— 1,431,444 
Accretion of discount7,529,289 16,266,663 
Net change in discounted income taxes(10,678,450)17,078,591 
Net changes in timing of production and other(5,887,312)1,414,465 
Balance, end of the fiscal year$87,582,551 $62,490,836