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SUPPLEMENTARY OIL AND NATURAL GAS INFORMATION (UNAUDITED)
 12 Months Ended
Sep. 30, 2024
Oil and Gas Disclosure [Abstract]  
SUPPLEMENTARY OIL AND NATURAL GAS INFORMATION (UNAUDITED) SUPPLEMENTARY OIL AND NATURAL GAS INFORMATION (UNAUDITED)
 
The following tables summarize information relative to Barnwell’s oil and natural gas operations, which are conducted in Canada and in the U.S. states of Oklahoma and Texas. Proved reserves are the estimated quantities of oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. Proved producing oil and natural gas reserves are reserves that can be expected to be recovered through existing wells with existing equipment and operating methods. The estimated net interests in total proved and proved producing reserves are based upon subjective engineering judgments and may be affected by the limitations inherent in such estimations. The process of estimating reserves is subject to continual revision as additional information becomes available as a result of drilling, testing, reservoir studies and production history. There can be no assurance that such estimates will not be materially revised in subsequent periods.

(A)                           Oil and Natural Gas Reserves
 
The following tables summarizes changes in the estimates of Barnwell’s net interests in total proved reserves of oil and natural gas liquids and natural gas, which are located in Canada and the U.S. states of Oklahoma and Texas. All of the information regarding Canadian reserves in this Form 10-K is derived from the report of our independent petroleum reserve engineers, InSite, and is included as an Exhibit to this Form 10-K. All of the information regarding U.S. reserves in this Form 10-K is derived from the report of our independent petroleum reserve engineers, Ryder Scott, and is included as an Exhibit to this Form 10-K. The Company emphasizes that reserve estimates are inherently imprecise and that estimates of new discoveries and undeveloped locations are more imprecise than estimates of established proved producing oil and natural gas properties. Accordingly, these estimates are expected to change as future information becomes available.

Proved oil and natural gas reserves are the estimated quantities of oil and natural gas that geological and engineering data demonstrate, with reasonable certainty, to be recoverable in future years from known reservoirs under economic and operating conditions (i.e., prices and costs) existing at the time the estimate is made.
Oil
(Bbls)
CanadaUnited StatesTotal
Proved reserves:   
Balance at September 30, 2022846,000 29,000 875,000 
Revisions of previous estimates(43,000)19,000 (24,000)
Extensions, discoveries and other additions167,000 85,000 252,000 
Less production(183,000)(21,000)(204,000)
Balance at September 30, 2023787,000 112,000 899,000 
Revisions of previous estimates222,000 (3,000)219,000 
Extensions, discoveries and other additions117,000 — 117,000 
Acquisitions of reserves4,000 — 4,000 
Less sales of reserves(54,000)— (54,000)
Less production(184,000)(19,000)(203,000)
Proved Reserves, September 30, 2024892,000 90,000 982,000 
NGL
(Bbls)
CanadaUnited StatesTotal
Proved reserves:   
Balance at September 30, 2022144,000 61,000 205,000 
Revisions of previous estimates1,000 29,000 30,000 
Extensions, discoveries and other additions32,000 112,000 144,000 
Less production(27,000)(25,000)(52,000)
Balance at September 30, 2023150,000 177,000 327,000 
Revisions of previous estimates70,000 15,000 85,000 
Extensions, discoveries and other additions15,000 — 15,000 
Acquisitions of reserves2,000 — 2,000 
Less sales of reserves(2,000)— (2,000)
Less production(36,000)(28,000)(64,000)
Proved Reserves, September 30, 2024199,000 164,000 363,000 

Natural Gas
(Mcf)
CanadaUnited StatesTotal
Proved reserves:   
Balance at September 30, 20224,519,000 466,000 4,985,000 
Revisions of previous estimates435,000 387,000 822,000 
Extensions, discoveries and other additions1,079,000 1,078,000 2,157,000 
Less production(1,023,000)(240,000)(1,263,000)
Balance at September 30, 20235,010,000 1,691,000 6,701,000 
Revisions of previous estimates826,000 82,000 908,000 
Extensions, discoveries and other additions313,000 — 313,000 
Acquisitions of reserves16,000 — 16,000 
Less sales of reserves(139,000)— (139,000)
Less production(1,085,000)(259,000)(1,344,000)
Proved Reserves, September 30, 20244,941,000 1,514,000 6,455,000 
Total Equivalent Reserves
(Boe)
CanadaUnited StatesTotal
Proved reserves:   
Balance at September 30, 20221,769,000 170,000 1,939,000 
Revisions of previous estimates5,000 110,000 115,000 
Extensions, discoveries and other additions379,000 377,000 756,000 
Less production(381,000)(86,000)(467,000)
Balance at September 30, 20231,772,000 571,000 2,343,000 
Revisions of previous estimates430,000 27,000 457,000 
Extensions, discoveries and other additions184,000 — 184,000 
Acquisitions of reserves9,000 — 9,000 
Less sales of reserves(79,000)— (79,000)
Less production(401,000)(90,000)(491,000)
Proved Reserves, September 30, 20241,915,000 508,000 2,423,000 

The following tables summarize changes in the estimates of Barnwell’s net interests in total proved undeveloped reserves and presents the balances of total proved developed reserves of oil and natural gas liquids and natural gas, which are located in Canada and the U.S. states of Oklahoma and Texas. Proved developed oil and natural gas reserves are proved reserves that can be expected to be recovered through existing wells and equipment in place and under operating methods being utilized at the time the estimates were made.
Oil
(Bbls)
CanadaUnited StatesTotal
Proved undeveloped reserves:   
Balance at September 30, 202392,000 — 92,000 
Conversion to proved developed reserves(98,000)— (98,000)
Revisions of previous estimates6,000 — 6,000 
Additions due to a new well109,000 — 109,000 
Proved Undeveloped Reserves, September 30, 2024109,000 — 109,000 
Proved Developed Reserves, September 30, 2023695,000 112,000 807,000 
Proved Developed Reserves, September 30, 2024783,000 90,000 873,000 
NGL
(Bbls)
CanadaUnited StatesTotal
Proved undeveloped reserves:   
Balance at September 30, 202318,000 — 18,000 
Conversion to proved developed reserves(10,000)— (10,000)
Revisions of previous estimates(8,000)— (8,000)
Additions due to a new well23,000 — 23,000 
Proved Undeveloped Reserves, September 30, 202423,000 — 23,000 
Proved Developed Reserves, September 30, 2023132,000 177,000 309,000 
Proved Developed Reserves, September 30, 2024176,000 164,000 340,000 

Natural Gas
(Mcf)
CanadaUnited StatesTotal
Proved undeveloped reserves:   
Balance at September 30, 2023608,000 — 608,000 
Conversion to proved developed reserves(279,000)— (279,000)
Revisions of previous estimates(330,000)— (330,000)
Additions due to a new well641,000 — 641,000 
Proved Undeveloped Reserves, September 30, 2024640,000 — 640,000 
Proved Developed Reserves, September 30, 20234,402,000 1,691,000 6,093,000 
Proved Developed Reserves, September 30, 20244,301,000 1,514,000 5,815,000 

Total Equivalent Reserves
(Boe)
CanadaUnited StatesTotal
Proved undeveloped reserves:   
Balance at September 30, 2023211,000 — 211,000 
Conversion to proved developed reserves(155,000)— (155,000)
Revisions of previous estimates(56,000)— (56,000)
Additions due to a new well239,000 — 239,000 
Proved Undeveloped Reserves, September 30, 2024239,000 — 239,000 
Proved Developed Reserves, September 30, 20231,561,000 571,000 2,132,000 
Proved Developed Reserves, September 30, 20241,676,000 508,000 2,184,000 
(B)                           Capitalized Costs Relating to Oil and Natural Gas Producing Activities
 
All capitalized costs relating to oil and natural gas producing activities in Canada and the U.S. are summarized as follows:
 September 30, 2024
 CanadaUnited StatesTotal
Proved properties$76,963,000 $6,594,000 $83,557,000 
Unproved properties— — — 
Total capitalized costs76,963,000 6,594,000 83,557,000 
Accumulated depletion, depreciation, and impairment64,402,000 2,601,000 67,003,000 
Net capitalized costs$12,561,000 $3,993,000 $16,554,000 

 September 30, 2023
 CanadaUnited StatesTotal
Proved properties$74,440,000 $6,411,000 $80,851,000 
Unproved properties— — — 
Total capitalized costs74,440,000 6,411,000 80,851,000 
Accumulated depletion, depreciation, and impairment58,477,000 1,072,000 59,549,000 
Net capitalized costs$15,963,000 $5,339,000 $21,302,000 

(C)                          Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development
 Year ended September 30, 2024
 CanadaUnited StatesTotal
Acquisition of properties:  
Proved$146,000 $— $146,000 
Unproved— — — 
Exploration costs34,000 — 34,000 
Development costs3,865,000 183,000 4,048,000 
Total$4,045,000 $183,000 $4,228,000 

 Year ended September 30, 2023
 CanadaUnited StatesTotal
Acquisition of properties:  
Proved$66,000 $— $66,000 
Unproved— — — 
Exploration costs461,000 255,000 716,000 
Development costs6,331,000 5,099,000 11,430,000 
Total$6,858,000 $5,354,000 $12,212,000 


 
(D)                        Results of Operations for Oil and Natural Gas Producing Activities
 Year ended September 30, 2024
 CanadaUnited StatesTotal
Net revenues$15,093,000 $2,303,000 $17,396,000 
Production costs(9,230,000)(619,000)(9,849,000)
Depletion(4,139,000)(808,000)(4,947,000)
Impairment of assets(2,164,000)(721,000)(2,885,000)
Pre-tax results of operations (1)
(440,000)155,000 (285,000)
Estimated income tax expense (2)
320,000 20,000 340,000 
Results of operations (1)
$(760,000)$135,000 $(625,000)

 Year ended September 30, 2023
 CanadaUnited StatesTotal
Net revenues$16,630,000 $2,746,000 $19,376,000 
Production costs(9,859,000)(575,000)(10,434,000)
Depletion(3,600,000)(669,000)(4,269,000)
Pre-tax results of operations (1)
3,171,000 1,502,000 4,673,000 
Estimated income tax expense (2)
107,000 44,000 151,000 
Results of operations (1)
$3,064,000 $1,458,000 $4,522,000 
_________________
(1)   Before general and administrative expenses, interest expense, and foreign exchange gains and losses.
(2) Estimated income tax expense includes changes to the deferred income tax valuation allowance necessary for the portion of Canadian and U.S. federal tax law deferred tax assets that may not be realizable.
 
(E)                           Standardized Measure, Including Year-to-Year Changes Therein, of Estimated Discounted Future Net Cash Flows
 
The following tables utilize reserve and production data estimated by independent petroleum reserve engineers. The information may be useful for certain comparison purposes but should not be solely relied upon in evaluating Barnwell or its performance. Moreover, the projections should not be construed as realistic estimates of future cash flows, nor should the standardized measure be viewed as representing current value.
 
The estimated future cash flows at September 30, 2024 and 2023 were based on average sales prices in effect on the first day of the month for the preceding twelve month period in accordance with SEC Release No. 33-8995. The future production and development costs represent the estimated future expenditures that we will incur to develop and produce the proved reserves, assuming continuation of existing economic conditions. The future income tax expenses were computed by applying statutory income tax rates in existence at September 30, 2024 and 2023 to the future pre-tax net cash flows relating to proved reserves, net of the tax basis of the properties involved.

Material revisions to reserve estimates may occur in the future, development and production of the oil and natural gas reserves may not occur in the periods assumed and actual prices realized and actual costs incurred are expected to vary significantly from those used. Management does not rely upon this information in making investment and operating decisions; rather, those decisions are based upon a wide range of factors, including estimates of probable reserves as well as proved reserves and price and cost assumptions different than those reflected herein.
Barnwell has included all abandonment, decommissioning and reclamation costs and inactive well costs in accordance with best practice recommendations into the Company’s reserve reports.

Standardized Measure of Discounted Future Net Cash Flows
 Year ended September 30, 2024
 CanadaUnited StatesTotal
Future cash inflows$75,293,000 $12,043,000 $87,336,000 
Future production costs(42,601,000)(5,080,000)(47,681,000)
Future development costs(2,795,000)— (2,795,000)
Future income tax expenses(2,666,000)(161,000)(2,827,000)
Future net cash flows excluding abandonment, decommissioning and reclamation27,231,000 6,802,000 34,033,000 
Future abandonment, decommissioning and reclamation(18,026,000)(50,000)(18,076,000)
Future net cash flows9,205,000 6,752,000 15,957,000 
10% annual discount for timing of cash flows2,697,000 (2,804,000)(107,000)
Standardized measure of discounted future net cash flows$11,902,000 $3,948,000 $15,850,000 

 Year ended September 30, 2023
 CanadaUnited StatesTotal
Future cash inflows$73,429,000 $15,995,000 $89,424,000 
Future production costs(41,935,000)(4,168,000)(46,103,000)
Future development costs(2,958,000)— (2,958,000)
Future income tax expenses(1,512,000)(264,000)(1,776,000)
Future net cash flows excluding abandonment, decommissioning and reclamation27,024,000 11,563,000 38,587,000 
Future abandonment, decommissioning and reclamation(18,585,000)(42,000)(18,627,000)
Future net cash flows8,439,000 11,521,000 19,960,000 
10% annual discount for timing of cash flows4,790,000 (4,837,000)(47,000)
Standardized measure of discounted future net cash flows$13,229,000 $6,684,000 $19,913,000 
 
Changes in the Standardized Measure of Discounted Future Net Cash Flows
 Year ended September 30,
 20242023
Beginning of year$19,913,000 $27,878,000 
Sales of oil and natural gas produced, net of production costs(7,547,000)(8,942,000)
Net changes in prices and production costs, net of royalties and wellhead taxes(12,201,000)(11,913,000)
Extensions and discoveries1,725,000 10,767,000 
Net change due to purchases and sales of minerals in place(895,000)— 
Changes in future development costs170,000 (2,959,000)
Revisions of previous quantity estimates9,478,000 2,227,000 
Net change in income taxes1,786,000 2,868,000 
Accretion of discount3,359,000 905,000 
Other - changes in the timing of future production and other76,000 (1,202,000)
Other - net change in Canadian dollar translation rate(14,000)284,000 
Net change(4,063,000)(7,965,000)
End of year$15,850,000 $19,913,000