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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
☒ Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
For the quarterly period ended December 31, 2024
or
☐ Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
Commission File Number 1-5103
BARNWELL INDUSTRIES, INC.
(Exact name of registrant as specified in its charter)

Delaware |  | 72-0496921
(State or other jurisdiction of incorporation or organization) |  | (I.R.S. Employer Identification No.)
1100 Alakea Street, Suite 500, Honolulu, Hawaii |  | 96813
(Address of principal executive offices) |  | (Zip code)
(808) 531-8400
(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class | Trading Symbol(s) | Name of each exchange on which registered
Common Stock, $0.50 par value | BRN | NYSE American
Common Stock Purchase Rights | N/A | NYSE American

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. ☒ Yes ☐ No
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). ☒ Yes ☐ No
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

| Large accelerated filer | ☐ |  | Accelerated filer | ☐
| Non-accelerated filer | ☒ |  | Smaller reporting company | ☒
|  |  | Emerging growth company | ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). ☐ Yes ☒ No
As of February 10, 2025 there were 10,053,534 shares of common stock, par value $0.50, outstanding.

BARNWELL INDUSTRIES, INC.
AND SUBSIDIARIES
INDEX

PART I. | FINANCIAL INFORMATION: |
Item 1. | Financial Statements (Unaudited) |
| Condensed Consolidated Balance Sheets - December 31, 2024 and September 30, 2024 | 3
| Condensed Consolidated Statements of Operations - three months ended December 31, 2024 and 2023 | 4
| Condensed Consolidated Statements of Comprehensive Loss - three months ended December 31, 2024 and 2023 | 5
| Condensed Consolidated Statements of Equity - three months ended December 31, 2024 and 2023 | 6
| Condensed Consolidated Statements of Cash Flows - three months ended December 31, 2024 and 2023 | 7
| Notes to Condensed Consolidated Financial Statements | 8
Item 2. | Management’s Discussion and Analysis of Financial Condition and Results of Operations | 23
Item 4. | Controls and Procedures | 32
PART II. | OTHER INFORMATION: |
Item 1A. | Risk Factors | 33
Item 5. | Other Information | 34
Item 6. | Exhibits | 34
| Signature | 35
| Index to Exhibits | 36

PART I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)

| December 31, 2024 |  | September 30, 2024
ASSETS |  |  |
Current assets: |  |  |
Cash and cash equivalents | $ | 1,957,000 |  |  | $ | 4,505,000 |
Accounts and other receivables, net of allowance for credit losses of: $350,000 at December 31, 2024; $375,000 at September 30, 2024 | 2,403,000 |  |  | 2,770,000 |
Assets held for sale | 69,000 |  |  | 69,000 |
Other current assets | 1,547,000 |  |  | 1,539,000 |
Total current assets | 5,976,000 |  |  | 8,883,000 |
Asset for retirement benefits | 5,002,000 |  |  | 4,899,000 |
Operating lease right-of-use assets | 153,000 |  |  | 39,000 |
Property and equipment: |  |  |
Proved oil and natural gas properties (full cost method) | 79,081,000 |  |  | 83,557,000 |
Drilling rigs and other property and equipment | 3,660,000 |  |  | 3,679,000 |
Total property and equipment | 82,741,000 |  |  | 87,236,000 |
Accumulated depletion, impairment, depreciation, and amortization | (67,862,000) |  |  | (70,388,000) |
Total property and equipment, net | 14,879,000 |  |  | 16,848,000 |
Total assets | $ | 26,010,000 |  |  | $ | 30,669,000 |
LIABILITIES AND EQUITY |  |  |
Current liabilities: |  |  |
Accounts payable | $ | 1,319,000 |  |  | $ | 1,822,000 |
Accrued capital expenditures | 105,000 |  |  | 2,407,000 |
Accrued compensation | 609,000 |  |  | 650,000 |
Accrued operating and other expenses | 1,575,000 |  |  | 1,834,000 |
Current portion of asset retirement obligation | 938,000 |  |  | 798,000 |
Other current liabilities | 788,000 |  |  | 301,000 |
Total current liabilities | 5,334,000 |  |  | 7,812,000 |
Operating lease liabilities | 122,000 |  |  | 7,000 |
Liability for retirement benefits | 1,921,000 |  |  | 1,898,000 |
Asset retirement obligation | 7,237,000 |  |  | 7,790,000 |
Deferred income tax liabilities | 91,000 |  |  | 100,000 |
Total liabilities | 14,705,000 |  |  | 17,607,000 |
Commitments and contingencies |  |  |
Equity: |  |  |
Common stock, par value $0.50 per share; authorized, 40,000,000 shares: 10,221,434 issued at December 31, 2024; 10,195,990 issued at September 30, 2024 | 5,111,000 |  |  | 5,098,000 |
Additional paid-in capital | 7,746,000 |  |  | 7,690,000 |
(Accumulated deficit) retained earnings | (1,322,000) |  |  | 595,000 |
Accumulated other comprehensive income, net | 2,036,000 |  |  | 1,943,000 |
Treasury stock, at cost: 167,900 shares at December 31, 2024 and September 30, 2024 | (2,286,000) |  |  | (2,286,000) |
Total stockholders' equity | 11,285,000 |  |  | 13,040,000 |
Non-controlling interests | 20,000 |  |  | 22,000 |
Total equity | 11,305,000 |  |  | 13,062,000 |
Total liabilities and equity | $ | 26,010,000 |  |  | $ | 30,669,000 |

See Notes to Condensed Consolidated Financial Statements
3

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)

| Three months ended December 31,
| 2024 |  | 2023
Revenues: |  |  |
Oil and natural gas | $ | 3,897,000 |  |  | $ | 5,130,000 |
Contract drilling | 543,000 |  |  | 993,000 |
Gas processing and other | 37,000 |  |  | 32,000 |
| 4,477,000 |  |  | 6,155,000 |
Costs and expenses: |  |  |
Oil and natural gas operating | 2,496,000 |  |  | 2,791,000 |
Contract drilling operating | 720,000 |  |  | 1,169,000 |
General and administrative | 1,281,000 |  |  | 1,404,000 |
Depletion, depreciation, and amortization | 928,000 |  |  | 1,511,000 |
Impairment of assets | 613,000 |  |  | — |
Foreign currency loss (gain) | 351,000 |  |  | (126,000) |
Interest expense | — |  |  | 2,000 |
| 6,389,000 |  |  | 6,751,000 |
Loss before equity in income of affiliates and income taxes | (1,912,000) |  |  | (596,000) |
Equity in income of affiliates | — |  |  | — |
Loss before income taxes | (1,912,000) |  |  | (596,000) |
Income tax provision | 7,000 |  |  | 66,000 |
Net loss | (1,919,000) |  |  | (662,000) |
Less: Net (loss) earnings attributable to non-controlling interests | (2,000) |  |  | 2,000 |
Net loss attributable to Barnwell Industries, Inc. | $ | (1,917,000) |  |  | $ | (664,000) |
Basic and diluted net loss per common share attributable to Barnwell Industries, Inc. stockholders | $ | (0.19) |  |  | $ | (0.07) |
Weighted-average number of common shares outstanding: |  |  |
Basic and diluted | 10,047,173 |  |  | 9,996,760 |

See Notes to Condensed Consolidated Financial Statements
4

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS
(Unaudited)

| Three months ended December 31,
| 2024 |  | 2023
Net loss | $ | (1,919,000) |  |  | $ | (662,000) |
Other comprehensive income (loss): |  |  |
Foreign currency translation adjustments, net of taxes of $0 | 93,000 |  |  | 30,000 |
Retirement plans: |  |  |
Amortization of accumulated other comprehensive gain into net periodic benefit cost, net of taxes of $0 | — |  |  | (21,000) |
Total other comprehensive income | 93,000 |  |  | 9,000 |
Total comprehensive loss | (1,826,000) |  |  | (653,000) |
Less: Comprehensive loss (income) attributable to non-controlling interests | 2,000 |  |  | (2,000) |
Comprehensive loss attributable to Barnwell Industries, Inc. | $ | (1,824,000) |  |  | $ | (655,000) |

See Notes to Condensed Consolidated Financial Statements
5

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF EQUITY
Three months ended December 31, 2024 and 2023
(Unaudited)

| Shares Outstanding |  | Common Stock |  | Additional Paid-In Capital |  | Retained Earnings (Accumulated Deficit) |  | Accumulated Other Comprehensive Income |  | Treasury Stock |  | Non-controlling Interests |  | Total Equity
Balance at September 30, 2023 | 9,990,778 |  |  | $ | 5,079,000 |  |  | $ | 7,687,000 |  |  | $ | 6,160,000 |  |  | $ | 2,104,000 |  |  | $ | (2,286,000) |  |  | $ | 13,000 |  |  | $ | 18,757,000 |
Net (loss) earnings | — |  |  | — |  |  | — |  |  | (664,000) |  |  | — |  |  | — |  |  | 2,000 |  |  | (662,000) |
Foreign currency translation adjustments, net of taxes of $0 | — |  |  | — |  |  | — |  |  | — |  |  | 30,000 |  |  | — |  |  | — |  |  | 30,000 |
Distributions to non-controlling interests | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (4,000) |  |  | (4,000) |
Share-based compensation | — |  |  | — |  |  | 65,000 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 65,000 |
Issuance of common stock for restricted stock units vested | 9,328 |  |  | 5,000 |  |  | (5,000) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Retirement plans: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Amortization of accumulated other comprehensive gain into net periodic benefit cost, net of taxes of $0 | — |  |  | — |  |  | — |  |  | — |  |  | (21,000) |  |  | — |  |  | — |  |  | (21,000) |
Balance at December 31, 2023 | 10,000,106 |  |  | $ | 5,084,000 |  |  | $ | 7,747,000 |  |  | $ | 5,496,000 |  |  | $ | 2,113,000 |  |  | $ | (2,286,000) |  |  | $ | 11,000 |  |  | $ | 18,165,000 |
Balance at September 30, 2024 | 10,028,090 |  |  | $ | 5,098,000 |  |  | $ | 7,690,000 |  |  | $ | 595,000 |  |  | $ | 1,943,000 |  |  | $ | (2,286,000) |  |  | $ | 22,000 |  |  | $ | 13,062,000 |
Net loss | — |  |  | — |  |  | — |  |  | (1,917,000) |  |  | — |  |  | — |  |  | (2,000) |  |  | (1,919,000) |
Foreign currency translation adjustments, net of taxes of $0 | — |  |  | — |  |  | — |  |  | — |  |  | 93,000 |  |  | — |  |  | — |  |  | 93,000 |
Share-based compensation | — |  |  | — |  |  | 69,000 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 69,000
Issuance of common stock for restricted stock units vested | 25,444 |  |  | 13,000 |  |  | (13,000) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Balance at December 31, 2024 | 10,053,534 |  |  | $ | 5,111,000 |  |  | $ | 7,746,000 |  |  | $ | (1,322,000) |  |  | $ | 2,036,000 |  |  | $ | (2,286,000) |  |  | $ | 20,000 |  |  | $ | 11,305,000 |

See Notes to Condensed Consolidated Financial Statements
6

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)

| Three months ended December 31,
| 2024 |  | 2023
Cash flows from operating activities: |  |  |
Net loss | $ | (1,919,000) |  |  | $ | (662,000) |
Adjustments to reconcile net loss to net cash |  |  |
(used in) provided by operating activities: |  |  |
Depletion, depreciation, and amortization | 928,000 |  |  | 1,511,000 |
Impairment of assets | 613,000 |  |  | — |
Retirement benefits income | (79,000) |  |  | (86,000) |
Accretion of asset retirement obligation | 196,000 |  |  | 200,000 |
Non-cash rent income | — |  |  | (7,000) |
Deferred income tax benefit | (9,000) |  |  | (2,000) |
Asset retirement obligation payments | (101,000) |  |  | (160,000) |
Share-based compensation expense | 69,000 |  |  | 65,000 |
Retirement plan contributions and payments | (1,000) |  |  | (1,000) |
Credit loss (reversal) expense | (14,000) |  |  | 37,000 |
Foreign currency loss (gain) | 351,000 |  |  | (126,000) |
(Decrease) increase from changes in current assets and liabilities | (793,000) |  |  | 606,000 |
Net cash (used in) provided by operating activities | (759,000) |  |  | 1,375,000 |
Cash flows from investing activities: |  |  |
Proceeds from sale of oil and natural gas assets | 282,000 |  |  | — |
Deposit for sale of contract drilling assets | 585,000 |  |  | — |
Capital expenditures - oil and natural gas | (2,529,000) |  |  | (1,018,000) |
Capital expenditures - all other | — |  |  | (1,000) |
Net cash used in investing activities | (1,662,000) |  |  | (1,019,000) |
Cash flows from financing activities: |  |  |
Distributions to non-controlling interests | — |  |  | (4,000) |
Net cash used in financing activities | — |  |  | (4,000) |
Effect of exchange rate changes on cash and cash equivalents | (127,000) |  |  | 41,000 |
Net (decrease) increase in cash and cash equivalents | (2,548,000) |  |  | 393,000 |
Cash and cash equivalents at beginning of period | 4,505,000 |  |  | 2,830,000 |
Cash and cash equivalents at end of period | $ | 1,957,000 |  |  | $ | 3,223,000 |

See Notes to Condensed Consolidated Financial Statements
7

BARNWELL INDUSTRIES, INC.
AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Principles of Consolidation
The condensed consolidated financial statements include the accounts of Barnwell Industries, Inc. and all majority-owned subsidiaries (collectively referred to herein as “Barnwell,” “we,” “our,” “us,” or the “Company”), including a 77.6%-owned land investment general partnership (Kaupulehu Developments) and a 75%-owned land investment partnership (KD Kona 2013 LLLP). All significant intercompany accounts and transactions have been eliminated.
Undivided interests in oil and natural gas exploration and production joint ventures are consolidated on a proportionate basis. Barnwell’s investments in both unconsolidated entities in which a significant, but less than controlling, interest is held and in variable interest entities in which the Company is not deemed to be the primary beneficiary are accounted for by the equity method.
Unless otherwise indicated, all references to “dollars” in this Form 10-Q are to U.S. dollars.
Unaudited Interim Financial Information
The accompanying unaudited condensed consolidated financial statements and notes have been prepared by Barnwell in accordance with the rules and regulations of the United States (“U.S.”) Securities and Exchange Commission. Accordingly, certain information and footnote disclosures normally included in the annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to those rules and regulations, although the Company believes that the disclosures made are adequate to make the information not misleading. These condensed consolidated financial statements and notes should be read in conjunction with the consolidated financial statements and notes thereto included in Barnwell’s September 30, 2024 Annual Report on Form 10-K, as amended by our Form 10-K/A Amendment No. 1 (our “2024 Annual Report”). The Condensed Consolidated Balance Sheet as of September 30, 2024 has been derived from audited consolidated financial statements.
In the opinion of management, all adjustments (which include only normal recurring adjustments) necessary to present fairly the financial position at December 31, 2024, results of operations, comprehensive loss, equity and cash flows for the three months ended December 31, 2024 and 2023, have been made. The results of operations for the period ended December 31, 2024 are not necessarily indicative of the operating results for the full year.
Use of Estimates in the Preparation of Condensed Consolidated Financial Statements
The preparation of the condensed consolidated financial statements in conformity with U.S. GAAP requires management of Barnwell to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Actual results could differ significantly from those estimates. Significant assumptions are required in the valuation of deferred tax assets, asset retirement obligations, contract drilling estimated costs to complete,
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proved oil and natural gas reserves, and such assumptions may impact the amount at which such items are recorded.
Significant Accounting Policies
There have been no changes to Barnwell's significant accounting policies as described in the Notes to Consolidated Financial Statements included in Item 8 of the Company's 2024 Annual Report.
2. LOSS PER COMMON SHARE
Basic loss per share is computed using the weighted-average number of common shares outstanding for the period. Diluted loss per share is calculated using the treasury stock method to reflect the assumed issuance of common shares for all potentially dilutive securities, which consist of outstanding stock options and nonvested restricted stock units. Potentially dilutive shares are excluded from the computation of diluted loss per share if their effect is anti-dilutive.
Options to purchase 465,000 shares of common stock and 216,712 restricted stock units were excluded from the computation of diluted shares for the three months ended December 31, 2024, as their inclusion would have been anti-dilutive. Options to purchase 465,000 shares of common stock and 76,336 restricted stock units were excluded from the computation of diluted shares for the three months ended December 31, 2023, as their inclusion would have been anti-dilutive.
Reconciliations between net loss attributable to Barnwell stockholders and common shares outstanding of the basic and diluted net loss per share computations are detailed in the following tables:

| Three months ended December 31, 2024
| Net Loss (Numerator) |  | Shares (Denominator) |  | Per-Share Amount
Basic | $ | (1,917,000) |  |  | 10,047,173 |  |  | $ | (0.19) |
Effect of dilutive securities - |  |  |  |  |
common stock options and restricted stock units | — |  |  | — |  |  |
Diluted | $ | (1,917,000) |  |  | 10,047,173 |  |  | $ | (0.19) |

| Three months ended December 31, 2023
| Net Loss (Numerator) |  | Shares (Denominator) |  | Per-Share Amount
Basic | $ | (664,000) |  |  | 9,996,760 |  |  | $ | (0.07) |
Effect of dilutive securities - |  |  |  |  |
common stock options and restricted stock units | — |  |  | — |  |  |
Diluted | $ | (664,000) |  |  | 9,996,760 |  |  | $ | (0.07) |

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3. ALLOWANCE FOR CREDIT LOSSES
The following table summarizes the activity in the balance of allowance for credit losses related to accounts and other receivables:

| Three months ended December 31,
| 2024 |  | 2023
Allowance for credit losses at beginning of period | $ | 375,000 |  |  | $ | 284,000 |
(Reversal of) provision for expected credit losses | (14,000) |  |  | 37,000 |
Write-offs charged against the allowance | (2,000) |  |  | (4,000) |
Recoveries of amounts previously written off | — |  |  | 15,000 |
Foreign currency translation adjustment | (9,000) |  |  | 2,000 |
Allowance for credit losses at end of period | $ | 350,000 |  |  | $ | 334,000 |

4. INVESTMENTS
Investment in Kukio Resort Land Development Partnerships
On November 27, 2013, Barnwell, through a wholly-owned subsidiary, entered into two limited liability limited partnerships, KD Kona 2013 LLLP (“KD Kona”) and KKM Makai, LLLP (“KKM”), and indirectly acquired a 19.6% non-controlling ownership interest in each of KD Kukio Resorts, LLLP, KD Maniniowali, LLLP and KD Kaupulehu, LLLP (“KDK”) for $5,140,000. These entities, collectively referred to hereinafter as the “Kukio Resort Land Development Partnerships,” own certain real estate and development rights interests in the Kukio, Maniniowali and Kaupulehu portions of Kukio Resort, a private residential community on the Kona coast of the island of Hawaii, as well as Kukio Resort’s real estate sales office operations. KDK holds interests in KD Acquisition, LLLP (“KD I”) and KD Acquisition II, LP, formerly KD Acquisition II, LLLP (“KD II”). KD I is the developer of Kaupulehu Lot 4A Increment I (“Increment I”), and KD II is the developer of Kaupulehu Lot 4A Increment II (“Increment II”). Barnwell's ownership interests in the Kukio Resort Land Development Partnerships is accounted for using the equity method of accounting.
In March 2019, KD II admitted a new development partner, Replay Kaupulehu Development, LLC (“Replay”), a party unrelated to Barnwell, in an effort to move forward with development of the remainder of Increment II at Kaupulehu. KDK and Replay hold ownership interests of 55% and 45%, respectively, of KD II and Barnwell has a 10.8% indirect non-controlling ownership interest in KD II through KDK, which is accounted for using the equity method of accounting. Barnwell continues to have an indirect 19.6% non-controlling ownership interest in KD Kukio Resorts, LLLP, KD Maniniowali, LLLP, and KD I.
The partnerships derive income from the sale of residential parcels in Increment I, which is now completely sold, as well as from commissions on real estate resales by the real estate sales office and revenues resulting from the sale of a few remaining private club memberships. The last two single-family lots of the 80 lots developed within Increment I were sold in the quarter ended March 31, 2024.
Increment II is not yet under development, and there is no assurance that development of such acreage will in fact occur. No definitive development plans have been made by KD II, the developer of Increment II, as of the date of this report.
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Barnwell has the right to receive distributions from the Kukio Resort Land Development Partnerships via its non-controlling interests in KD Kona and KKM, based on its respective partnership sharing ratios of 75% and 34.45%, respectively. No cash distributions were received during the three months ended December 31, 2024 and 2023.
Summarized financial information for the Kukio Resort Land Development Partnerships is as follows:

| Three months ended December 31,
| 2024 |  | 2023
Revenue | $ | 1,299,000 |  |  | $ | 1,886,000 |
Gross profit | $ | 479,000 |  |  | $ | 817,000 |
Net (loss) earnings | $ | (48,000) |  |  | $ | 354,000 |

In the quarter ended June 30, 2021, the Company received cumulative distributions from the Kukio Resort Land Development Partnerships in excess of our investment balance and in accordance with applicable accounting guidance, the Company suspended its equity method earnings recognition and the Kukio Resort Land Development Partnership investment balance was reduced to zero with the distributions received in excess of our investment balance recorded as equity in income of affiliates because the distributions are not refundable by agreement or by law and the Company is not liable for the obligations of or otherwise committed to provide financial support to the Kukio Resort Land Development Partnerships. The Company will record future equity method earnings only after our share of the Kukio Resort Land Development Partnership’s cumulative earnings in excess of distributions during the suspended period exceeds our share of the Kukio Resort Land Development Partnership’s income recognized for the excess distributions, and during this suspended period any distributions received will be recorded as equity in income of affiliates. Accordingly, no equity in income of affiliates was recognized during the three months ended December 31, 2024.
Cumulative distributions received from the Kukio Resort Land Development Partnerships in excess of our investment balance was $382,000 at December 31, 2024 and $373,000 at September 30, 2024.
Sale of Interest in Leasehold Land
Kaupulehu Developments holds rights to receive payments from KD I and KD II resulting from the sale of lots and/or residential units within Increment I, which is now fully sold, and within Increment II, which is not yet developed (see Note 16).
With respect to Increment I, Kaupulehu Developments was entitled to receive payments from KD I based on 10% of the gross receipts from KD I’s sales of single-family residential lots in Increment I. The last two single-family lots of the 80 lots developed within Increment I were sold in the quarter ended March 31, 2024. There is no assurance with regards to the amounts of future payments from Increment II to be received or that the remaining acreage within Increment II will be developed. No definitive development plans have been made by KD II, the developer of Increment II, as of the date of this report.
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Investment in Leasehold Land Interest - Lot 4C
Kaupulehu Developments holds an interest in an area of approximately 1,000 acres of vacant leasehold land zoned conservation located adjacent to Lot 4A, which currently has no development potential without both a development agreement with the lessor and zoning reclassification. The lease terminates in December 2025.
5. ASSETS HELD FOR SALE
In the quarter ended March 31, 2024, the Company commenced the marketing of a portion of the contract drilling segment's property and equipment, the majority of which was already fully depreciated. There was no impairment related to the classification change from held and used to held for sale as the fair value, less estimated selling costs, of the disposal group exceeded its carrying value. The carrying value of these assets was recorded as “Assets held for sale” in the accompanying Condensed Consolidated Balance Sheets. The property and equipment deemed necessary to complete the contract drilling segment's contracts in backlog continue to be classified as held and used as of December 31, 2024. At December 31, 2024, a sale of the remainder of the contract drilling segment's property and equipment or the contract drilling segment as a whole was not estimated to be probable due to the lack of any definitive sale opportunities at that date.
In December 2024, the Company entered into an agreement with an independent third party for the sale of a contract drilling segment drilling rig and related ancillary equipment and received a payment of $585,000 from the buyer. At December 31, 2024, the delivery of the drilling rig and the transfer of the legal title to the buyer had not yet occurred, and therefore, the Company did not record a sale during the three months ended December 31, 2024. The payment received from the buyer was recognized as a deposit and recorded in “Other current liabilities” on the Company's Condensed Consolidated Balance Sheet at December 31, 2024. This drilling rig and related ancillary equipment was included in assets held for sale at December 31, 2024, and had a net book value of zero as the assets were already fully depreciated.
In February 2025, the drilling rig and ancillary equipment was delivered and the legal title was transferred to the buyer, and as a result, the Company will recognize a gain, net of costs, on the sale of the drilling rig and ancillary equipment in the quarter ending March 31, 2025.
6. OIL AND NATURAL GAS PROPERTIES
Oil and Natural Gas Property Dispositions
There were no significant oil and natural gas property dispositions during the three months ended December 31, 2024 and 2023. The $282,000 of proceeds from sale of oil and natural gas properties included in the Condensed Consolidated Statement of Cash Flows for the three months ended December 31, 2024 represents proceeds that were credited to our cash in October 2024 from a sale of properties that closed in late September 2024.
Impairment of Oil and Natural Gas Properties
Under the full cost method of accounting, the Company performs quarterly oil and natural gas ceiling test calculations. Changes in the 12-month rolling average first-day-of-the-month prices for oil, natural gas and natural gas liquids prices (except where prices are defined by contractual arrangements),
12

the value of reserve additions as compared to the amount of capital expenditures to obtain them, and changes in production rates and estimated levels of reserves, future development costs and the market value of unproved properties, impact the determination of the maximum carrying value of oil and natural gas properties.
During the three months ended December 31, 2024, the Company incurred a non-cash ceiling test impairment for our U.S. oil and natural gas properties of $613,000. There was no ceiling test impairment during the three months ended December 31, 2023.
As discussed above, the ceiling test uses a 12-month historical rolling average first-day-of-the-month prices. As such, declines in the 12-month historical rolling average first-day-of-the-month prices used in our ceiling test calculation in future periods could result in impairment write-downs in future periods in the absence of any offsetting factors that are not currently known or projected.
7. RETIREMENT PLANS
Barnwell sponsors a noncontributory defined benefit pension plan (“Pension Plan”) covering substantially all of its U.S. employees and a noncontributory Supplemental Executive Retirement Plan (“SERP”), which covers certain current and former employees of Barnwell for amounts exceeding the limits allowed under the Pension Plan. Effective December 31, 2019, the accrual of benefits for all participants in the Pension Plan and SERP was frozen and the plans were closed to new participants from that point forward.
The following table details the components of net periodic benefit (income) cost for Barnwell’s retirement plans:

| Pension Plan |  | SERP
| Three months ended December 31,
| 2024 |  | 2023 |  | 2024 |  | 2023
Interest cost | $ | 98,000 |  |  | $ | 103,000 |  |  | $ | 23,000 |  |  | $ | 24,000 |
Expected return on plan assets | (200,000) |  |  | (192,000) |  |  | — |  |  | — |
Amortization of net actuarial gain | — |  |  | — |  |  | — |  |  | (21,000) |
Net periodic benefit (income) cost | $ | (102,000) |  |  | $ | (89,000) |  |  | $ | 23,000 |  |  | $ | 3,000 |

The net periodic benefit (income) cost is included in “General and administrative” expenses in the Company's Condensed Consolidated Statements of Operations.
Currently, no contributions are planned to be made to the Pension Plan during fiscal 2025. The SERP plan is unfunded and Barnwell funds benefits when payments are made. Expected payments under the SERP for fiscal 2025 are expected to be $76,000. Fluctuations in actual equity market returns as well as changes in general interest rates will result in changes in the market value of plan assets and may result in increased or decreased retirement benefits costs and contributions in future periods.
13

8. INCOME TAXES
The components of loss before income taxes, after adjusting the loss for non-controlling interests, are as follows:

|  | Three months ended December 31,
|  | 2024 |  | 2023
United States |  | $ | (1,466,000) |  |  | $ | (689,000) |
Canada |  | (444,000) |  |  | 91,000 |
|  | $ | (1,910,000) |  |  | $ | (598,000) |

The components of the income tax provision are as follows:

| Three months ended December 31,
| 2024 |  | 2023
Current | $ | 16,000 |  |  | $ | 68,000 |
Deferred | (9,000) |  |  | (2,000) |
| $ | 7,000 |  |  | $ | 66,000 |

Consolidated taxes do not bear a customary relationship to pretax results due primarily to the fact that the Company is taxed separately in Canada based on Canadian source operations and in the U.S. based on consolidated operations, and essentially all deferred tax assets, net of relevant offsetting deferred tax liabilities, are not estimated to have a future benefit as tax credits or deductions. The Company operates two subsidiaries in Canada, one of which is a U.S. corporation operating as a branch in Canada that is treated as a non-resident for Canadian tax purposes and thus has operating results that cannot be offset against or combined with the other Canadian subsidiary that files as a resident for Canadian tax purposes. Income from our non-controlling interest in the Kukio Resort Land Development Partnerships is treated as non-unitary for state of Hawaii unitary filing purposes, thus unitary Hawaii losses provide limited sheltering of such non-unitary income. Income from our investment in the Oklahoma oil venture is 100% allocable to Oklahoma. As such, Barnwell receives no benefit from consolidated or unitary losses and, therefore, is subject to Oklahoma state taxes. Our operations in Texas are subject to a franchise tax assessed by the state of Texas, however no significant amounts have been incurred to date.
14

9. REVENUE FROM CONTRACTS WITH CUSTOMERS
Disaggregation of Revenue
The following tables provides information about disaggregated revenue by revenue streams, reportable segments, geographical region, and timing of revenue recognition for the three months ended December 31, 2024 and 2023.

|  | Three months ended December 31, 2024
|  | Oil and natural gas |  | Contract drilling |  | Land investment |  | Other |  | Total
Revenue streams: |  |  |  |  |  |  |  |  |
| Oil | $ | 3,143,000 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 3,143,000 |
| Natural gas | 349,000 |  |  | — |  |  | — |  |  | — |  |  | 349,000 |
| Natural gas liquids | 405,000 |  |  | — |  |  | — |  |  | — |  |  | 405,000 |
| Drilling and pump | — |  |  | 543,000 |  |  | — |  |  | — |  |  | 543,000 |
| Other | — |  |  | — |  |  | — |  |  | 11,000 |  |  | 11,000 |
| Total revenues before interest income | $ | 3,897,000 |  |  | $ | 543,000 |  |  | $ | — |  |  | $ | 11,000 |  |  | $ | 4,451,000 |
Geographical regions: |  |  |  |  |  |  |  |  |
| United States | $ | 355,000 |  |  | $ | 543,000 |  |  | $ | — |  |  | $ | — |  |  | $ | 898,000 |
| Canada | 3,542,000 |  |  | — |  |  | — |  |  | 11,000 |  |  | 3,553,000 |
| Total revenues before interest income | $ | 3,897,000 |  |  | $ | 543,000 |  |  | $ | — |  |  | $ | 11,000 |  |  | $ | 4,451,000 |
Timing of revenue recognition: |  |  |  |  |  |  |  |  |
| Goods transferred at a point in time | $ | 3,897,000 |  |  | $ | — |  |  | $ | — |  |  | $ | 11,000 |  |  | $ | 3,908,000 |
| Services transferred over time | — |  |  | 543,000 |  |  | — |  |  | — |  |  | 543,000 |
| Total revenues before interest income | $ | 3,897,000 |  |  | $ | 543,000 |  |  | $ | — |  |  | $ | 11,000 |  |  | $ | 4,451,000 |

|  | Three months ended December 31, 2023
|  | Oil and natural gas |  | Contract drilling |  | Land investment |  | Other |  | Total
Revenue streams: |  |  |  |  |  |  |  |  |
| Oil | $ | 3,892,000 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 3,892,000 |
| Natural gas | 712,000 |  |  | — |  |  | — |  |  | — |  |  | 712,000 |
| Natural gas liquids | 526,000 |  |  | — |  |  | — |  |  | — |  |  | 526,000 |
| Drilling and pump | — |  |  | 993,000 |  |  | — |  |  | — |  |  | 993,000 |
| Other | — |  |  | — |  |  | — |  |  | 17,000 |  |  | 17,000 |
| Total revenues before interest income | $ | 5,130,000 |  |  | $ | 993,000 |  |  | $ | — |  |  | $ | 17,000 |  |  | $ | 6,140,000 |
Geographical regions: |  |  |  |  |  |  |  |  |
| United States | $ | 754,000 |  |  | $ | 993,000 |  |  | $ | — |  |  | $ | 1,000 |  |  | $ | 1,748,000 |
| Canada | 4,376,000 |  |  | — |  |  | — |  |  | 16,000 |  |  | 4,392,000 |
| Total revenues before interest income | $ | 5,130,000 |  |  | $ | 993,000 |  |  | $ | — |  |  | $ | 17,000 |  |  | $ | 6,140,000 |
Timing of revenue recognition: |  |  |  |  |  |  |  |  |
| Goods transferred at a point in time | $ | 5,130,000 |  |  | $ | — |  |  | $ | — |  |  | $ | 17,000 |  |  | $ | 5,147,000 |
| Services transferred over time | — |  |  | 993,000 |  |  | — |  |  | — |  |  | 993,000 |
| Total revenues before interest income | $ | 5,130,000 |  |  | $ | 993,000 |  |  | $ | — |  |  | $ | 17,000 |  |  | $ | 6,140,000 |

15

Contract Balances
The following table provides information about accounts receivables, contract assets and contract liabilities from contracts with customers:

| December 31, 2024 |  | September 30, 2024 |  | September 30, 2023
Accounts receivables from contracts with customers | $ | 1,930,000 |  |  | $ | 2,031,000 |  |  | $ | 2,931,000 |
Contract assets | 333,000 |  |  | 267,000 |  |  | 958,000 |
Contract liabilities | — |  |  | — |  |  | 377,000 |

Accounts receivables from contracts with customers are included in "Accounts and other receivables, net of allowance for credit losses," in the accompanying Condensed Consolidated Balance Sheets and contract assets, which includes costs and estimated earnings in excess of billings and retainage, are included in “Other current assets” in the accompanying Condensed Consolidated Balance Sheets. Contract liabilities, which includes billings in excess of costs and estimated earnings are included in “Other current liabilities” in the accompanying Condensed Consolidated Balance Sheets.
Retainage, included in contract assets, represents amounts due from customers, but where payments are withheld contractually until certain construction milestones are met. Amounts retained typically range from 5% to 10% of the total invoice, up to contractually-specified maximums. The Company classifies as a current asset those retainages that are expected to be collected in the next twelve months.
Contract assets represent the Company’s rights to consideration in exchange for services transferred to a customer that have not been billed as of the reporting date. The Company’s rights are generally unconditional at the time its performance obligations are satisfied. When the Company receives consideration, or such consideration is unconditionally due, from a customer prior to transferring goods or services to the customer under the terms of a sales contract, the Company records deferred revenue, which represents a contract liability. Such deferred revenue typically results from billings in excess of costs and estimated earnings on uncompleted contracts.
During the three months ended December 31, 2024 and 2023, the amount of revenue recognized that was previously included in contract liabilities as of the beginning of the respective period was nil and $229,000, respectively.
Contracts are sometimes modified for a change in scope or other requirements. The Company considers contract modifications to exist when the modification either creates new or changes the existing enforceable rights and obligations. Most of the Company’s contract modifications are for goods and services that are not distinct from the existing performance obligations. The effect of a contract modification on the transaction price, and the measure of progress for the performance obligation to which it relates, is recognized as an adjustment to revenue (either as an increase or decrease) on a cumulative catchup basis.
Performance Obligations
The Company’s remaining performance obligations for drilling and pump installation contracts (hereafter referred to as “backlog”) represent the unrecognized revenue value of the Company’s contract commitments. The Company’s backlog may vary significantly each reporting period based on the timing
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of major new contract commitments. In addition, our customers have the right, under some infrequent circumstances, to terminate contracts or defer the timing of the Company’s services and their payments to us. Nearly all of the Company's contract drilling segment contracts have original expected durations of one year or less. At December 31, 2024, the Company had three contract drilling jobs with original expected durations of greater than one year, for which 100% of the remaining performance obligation of $208,000 is expected to be recognized as revenue in the next twelve months.
Contract Fulfillment Costs
Preconstruction costs, which include costs such as set-up and mobilization, are capitalized and allocated across all performance obligations and deferred and amortized over the contract term on a progress towards completion basis. As of December 31, 2024 and September 30, 2024, the Company had $92,000 and $173,000, respectively, in unamortized preconstruction costs related to contracts that were not completed. During the three months ended December 31, 2024 and 2023, the amortization of preconstruction costs related to contracts were not material and were included in the accompanying Condensed Consolidated Statements of Operations. Additionally, no impairment charges in connection with the Company’s preconstruction costs were recorded during the three months ended December 31, 2024 and 2023.
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10. SEGMENT INFORMATION
Barnwell operates the following segments: 1) acquiring, developing, producing and selling oil and natural gas in Canada and the U.S. (oil and natural gas); 2) leasehold land interests in Hawaii (land investment); and 3) drilling wells and installing and repairing water pumping systems in Hawaii (contract drilling).
The following table presents certain financial information related to Barnwell’s reporting segments. All revenues reported are from external customers with no intersegment sales or transfers.

| Three months ended December 31,
| 2024 |  | 2023
Revenues: |  |  |
Oil and natural gas | $ | 3,897,000 |  |  | $ | 5,130,000 |
Contract drilling | 543,000 |  |  | 993,000 |
Other | 11,000 |  |  | 17,000 |
Total before interest income | 4,451,000 |  |  | 6,140,000 |
Interest income | 26,000 |  |  | 15,000 |
Total revenues | $ | 4,477,000 |  |  | $ | 6,155,000 |
Depletion, depreciation, and amortization: |  |  |
Oil and natural gas | $ | 904,000 |  |  | $ | 1,458,000 |
Contract drilling | 24,000 |  |  | 52,000 |
Other | — |  |  | 1,000 |
Total depletion, depreciation, and amortization | $ | 928,000 |  |  | $ | 1,511,000 |
Impairment: |  |  |
Oil and natural gas | $ | 613,000 |  |  | $ | — |
Total impairment | $ | 613,000 |  |  | $ | — |
Operating (loss) profit (before general and administrative expenses): |  |  |
Oil and natural gas | $ | (116,000) |  |  | $ | 881,000 |
Contract drilling | (201,000) |  |  | (228,000) |
Other | 11,000 |  |  | 16,000 |
Total operating (loss) profit | (306,000) |  |  | 669,000 |
General and administrative expenses | (1,281,000) |  |  | (1,404,000) |
Foreign currency (loss) gain | (351,000) |  |  | 126,000 |
Interest expense | — |  |  | (2,000) |
Interest income | 26,000 |  |  | 15,000 |
Loss before income taxes | $ | (1,912,000) |  |  | $ | (596,000) |

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11. ACCUMULATED OTHER COMPREHENSIVE INCOME
The changes in each component of accumulated other comprehensive income were as follows:

| Three months ended December 31,
| 2024 |  | 2023
Foreign currency translation: |  |  |
Beginning accumulated foreign currency translation | $ | 220,000 |  |  | $ | 220,000 |
Change in cumulative translation adjustment before reclassifications | 93,000 |  |  | 30,000 |
Income taxes | — |  |  | — |
Net current period other comprehensive income | 93,000 |  |  | 30,000 |
Ending accumulated foreign currency translation | 313,000 |  |  | 250,000 |
Retirement plans: |  |  |
Beginning accumulated retirement plans benefit income | 1,723,000 |  |  | 1,884,000 |
Amortization of net actuarial gain | — |  |  | (21,000) |
Income taxes | — |  |  | — |
Net current period other comprehensive loss | — |  |  | (21,000) |
Ending accumulated retirement plans benefit income | 1,723,000 |  |  | 1,863,000 |
Accumulated other comprehensive income, net of taxes | $ | 2,036,000 |  |  | $ | 2,113,000 |

The amortization of net actuarial gain for the retirement plans are included in the computation of net periodic benefit (income) cost which is a component of “General and administrative” expenses on the accompanying Condensed Consolidated Statements of Operations (see Note 7 for additional details).
12. FAIR VALUE MEASUREMENTS
The carrying values of cash and cash equivalents, accounts and other receivables, accounts payable and accrued current liabilities approximate their fair values due to the short-term nature of the instruments.
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
The estimated fair values of oil and natural gas properties and the asset retirement obligation incurred in the drilling of oil and natural gas wells or assumed in the acquisitions of additional oil and natural gas working interests are based on an estimated discounted cash flow model and market assumptions. The assumptions used in the calculation of estimated discounted cash flows were primarily Level 3 assumptions; assumptions included future commodity prices, projections of estimated quantities of oil and natural gas reserves, expectations for timing and amount of future development, operating and asset retirement costs, projections of future rates of production, expected recovery rates and risk adjusted discount rates.
Barnwell estimates the fair value of asset retirement obligations based on the projected discounted future cash outflows required to settle abandonment and restoration liabilities. Such an estimate requires assumptions and judgments regarding the existence of liabilities, the amount and timing of cash outflows required to settle the liability, what constitutes adequate restoration, inflation factors, credit adjusted discount rates, and consideration of changes in legal, regulatory, environmental and political environments. Abandonment and restoration cost estimates are determined in conjunction with Barnwell’s reserve engineers based on historical information regarding costs incurred to abandon and restore similar
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well sites, information regarding current market conditions and costs, and knowledge of subject well sites and properties. Asset retirement obligation fair value measurements in the current period were Level 3 fair value measurements.
13. STOCKHOLDERS' EQUITY
Restricted Stock Units
On October 24, 2024, the Board of Directors of the Company granted a total of 105,820 restricted stock units to the independent directors of the Board as partial payment of director fees for their service as members of the Board. The restricted stock units vest ratably over a three-year period, subject to the director’s continued service through the applicable vesting date.
The following table summarizes Barnwell’s restricted stock unit activity from October 1, 2024 through December 31, 2024:

Restricted Stock Units |  | Shares |  | Weighted-Average Grant Date Fair Value
Nonvested at October 1, 2024 |  | 110,892 |  |  | $ | 2.63 |
Granted |  | 105,820 |  |  | 1.89 |
Vested |  | — |  |  | — |
Forfeited |  | — |  |  | — |
Nonvested at December 31, 2024 |  | 216,712 |  |  | $ | 2.27 |

Compensation cost for restricted stock unit awards is measured at fair value and is recognized as an expense over the requisite service period. During the three months ended December 31, 2024 and 2023, the Company recognized share-based compensation expense related to restricted stock units of $69,000 and $30,000, respectively. As of December 31, 2024, the total remaining unrecognized compensation cost related to nonvested restricted stock units was $331,000, which is expected to be recognized over the weighted-average remaining requisite service period of 1.7 years.
14. CONTINGENCIES
Legal and Regulatory Matters
Barnwell is routinely involved in disputes with third parties that occasionally require litigation. In addition, Barnwell is required to maintain compliance with all current governmental controls and regulations in the ordinary course of business. Barnwell’s management is not aware of any claims or litigation involving Barnwell that are likely to have a material adverse effect on its results of operations, financial position or liquidity.
In fiscal 2020, the Staff of the State of Hawaii’s Commission on Water Resource Management (“Commission”) circulated a draft of a proposed recommendation to the Commission under which the Company, the water utility, the water utility's independent hydrologist firm and the owner of the land on which two water wells were drilled would be assessed penalty fines because each of the wells were calculated to have been drilled beyond the depth permitted by the permit. The wells were drilled to a depth to penetrate certain layers of impermeable rock necessary to access the aquifer at the instructions and on the advice of the hydrologist hired by the owner of the well. Subsequently, the Staff of the Commission
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acknowledged that one well had not been drilled to a depth beyond its permitted depth and the fines on that well were eliminated. Additionally, the fines applicable to the depth of the second well were dropped in lieu of the parties entering into an agreement to perform a water quality study and repurpose a current well into a monitoring well. The liability related to this contingency was $200,000 at December 31, 2024 and September 30, 2024 and is included in “Accrued operating and other expenses” in the accompanying Condensed Consolidated Balance Sheets. It is unknown when this contingent liability related to the required drilling of the monitoring well in satisfaction of a regulatory assessment will be settled.
15. INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

| Three months ended December 31,
| 2024 |  | 2023
Supplemental disclosure of cash flow information: |  |  |
Cash paid during the year for: |  |  |
Income taxes paid | $ | 136,000 |  |  | $ | 44,000 |

Capital expenditure accruals related to oil and natural gas exploration and development decreased $2,215,000 and $523,000 during the three months ended December 31, 2024 and 2023, respectively. Additionally, capital expenditure accruals related to oil and natural gas asset retirement obligations increased $32,000 and $115,000 during the three months ended December 31, 2024 and 2023, respectively.
16. RELATED PARTY TRANSACTIONS
Kaupulehu Developments is entitled to receive payments from the sales of lots and/or residential units by KD I and KD II. KD I and KD II are part of the Kukio Resort Land Development Partnerships in which Barnwell holds indirect 19.6% and 10.8% non-controlling ownership interests, respectively, accounted for under the equity method of investment. The percentage of sales payments are part of transactions which took place in 2004 and 2006 where Kaupulehu Developments sold its leasehold interests in Increment I and Increment II to KD I's and KD II's predecessors in interest, respectively, which was prior to Barnwell’s affiliation with KD I and KD II which commenced on November 27, 2013, the acquisition date of our ownership interest in the Kukio Resort Land Development Partnerships. Changes to the arrangement above, effective March 7, 2019, are discussed in Note 4.
17. SUBSEQUENT EVENTS
Restricted Stock Units
In January 2025, the Company's Board of Directors (the “Board”) granted a total of 66,000 restricted stock units to the Company's President and Chief Executive Officer. The restricted stock units vest ratably over a three-year period, subject to the employee’s continued service through the applicable vesting dates.
Limited-Duration Shareholder Rights Plan
On January 26, 2025, the Board adopted a shareholder rights plan and declared a dividend of one
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right (a “Right”) in respect of each of the Company’s issued and outstanding shares of common stock, par value $0.50 per share (“Common Stock”). The dividend is payable to the shareholders of record at the close of business on February 7, 2025. Each Right initially entitles the registered holder, subject to the terms of the Rights Agreement (as defined below), to purchase from the Company one share of Common Stock, at a price equal to $9.00, subject to certain adjustments (as adjusted from time to time, the “Exercise Price”). The terms of the Rights are set forth in the Rights Agreement, dated as of January 26, 2025 (as it may be amended from time to time, the “Rights Agreement”), by and between the Company and Broadridge Corporate Issuer Solutions, LLC, as rights agent (or any successor rights agent, the “Rights Agent”).
In general terms, the Rights Agreement imposes significant dilution upon any person or group (other than the Company or certain related persons) that is or becomes the beneficial owner of 20% (the “Triggering Percentage”) or more of the Company’s outstanding Common Stock without the prior approval of the Board. A person or group that becomes the beneficial owner of the Triggering Percentage or more is called an “Acquiring Person.” Any Rights held by an Acquiring Person will be null and void and may not be exercised. Shareholders that beneficially own the Triggering Percentage or more of the Company’s outstanding Common Stock on the date the plan is adopted, are not considered Acquiring Persons; however, such Shareholders generally may not acquire, or obtain the right to acquire, beneficial ownership of 0.25% or more additional shares of the Company’s outstanding Common Stock. The term “beneficial ownership” is defined in the Rights Agreement and includes, among other things, certain securities that may be exercised or converted into shares of Common Stock and certain derivative arrangements.
The Rights will expire prior to the earliest of (i) the close of business on January 26, 2026 (subject to the shareholders of the Company approving an extension of the Rights Agreement through a date on or prior to January 26, 2028); (ii) the time at which the Rights are redeemed pursuant to the Rights Agreement; (iii) the time at which the Rights are exchanged pursuant to the Rights Agreement; and (iv) upon the occurrence of certain transactions.
This description of the Rights Agreement herein does not purport to be complete and is qualified in its entirety by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K, filed with the Securities and Exchange Commission on January 27, 2025.
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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Cautionary Statement Relevant to Forward-Looking Information
For the Purpose Of “Safe Harbor” Provisions Of The
Private Securities Litigation Reform Act of 1995
This Form 10-Q, and the documents incorporated herein by reference, contain “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995 ("PSLRA"). A forward-looking statement is one which is based on current expectations of future events or conditions and does not relate to historical or current facts. These statements include various estimates, forecasts, projections of Barnwell’s future performance, statements of Barnwell’s plans and objectives, and other similar statements. All such statements we make are forward-looking statements made under the safe harbor of the PSLRA, except to the extent such statements relate to the operations of a partnership or limited liability company. Forward-looking statements include phrases such as “expects,” “anticipates,” “intends,” “plans,” “believes,” “predicts,” “estimates,” “assumes,” “projects,” “may,” “will,” “will be,” “should,” or similar expressions. Although Barnwell believes that its current expectations are based on reasonable assumptions, it cannot assure that the expectations contained in such forward-looking statements will be achieved. Forward-looking statements involve risks, uncertainties and assumptions which could cause actual results to differ materially from those contained in such statements. The risks, uncertainties and other factors that might cause actual results to differ materially from Barnwell’s expectations are set forth in the “Forward-Looking Statements” and “Risk Factors” sections of Barnwell’s 2024 Annual Report. Investors should not place undue reliance on these forward-looking statements, as they speak only as of the date of filing of this Form 10-Q, and Barnwell expressly disclaims any obligation or undertaking to publicly release any updates or revisions to any forward-looking statements contained herein.
Critical Accounting Policies and Estimates
Management has determined that our most critical accounting policies and estimates are those related to the full-cost ceiling calculation and depletion of our oil and natural gas properties, the estimation of our contract drilling segment's revenues and expenses, and the calculation of our income taxes, all of which are discussed in our 2024 Annual Report. There have been no significant changes to these critical accounting policies and estimates during the three months ended December 31, 2024. We continue to monitor our accounting policies to ensure proper application of current rules and regulations.
Impact of Recently Issued Accounting Standards on Future Filings
In November 2023, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2023-07 “Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures,” which expands reportable segment disclosure requirements on an annual and interim basis, primarily through enhanced disclosures about significant segment expenses. This ASU is effective for annual reporting periods beginning after December 15, 2023 (our fiscal 2025) and interim periods within fiscal years beginning after December 15, 2024 (our fiscal 2026), with early adoption permitted. The Company is currently evaluating the impact of this standard on Barnwell’s consolidated financial statements but does not expect that the adoption of this update will have a material impact on Barnwell's consolidated financial statements.
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In December 2023, the FASB issued ASU No. 2023-09 “Income Taxes (Topic 740): Improvements to Income Tax Disclosures,” which requires disclosure of incremental income tax information within the tax rate reconciliation and expanded disclosures of income taxes paid both in the U.S. and foreign jurisdiction, among other disclosure requirements. This ASU is effective for annual reporting periods beginning after December 15, 2024, with early adoption permitted. The Company is currently evaluating the impact of this standard on Barnwell’s consolidated financial statements.
In November 2024, the FASB issued ASU No. 2024-03 “Income Statement - Reporting Comprehensive Income - Expense Disaggregation Disclosures (Subtopic 220-40): Disaggregation of Income Statement Expenses,” which requires public companies to disclose specified information about certain costs and expenses in the notes to the financial statements at interim and annual reporting periods. This ASU is effective for annual reporting periods beginning after December 15, 2026 and interim reporting periods within annual reporting periods beginning after December 15, 2027, with early adoption permitted. The Company is currently evaluating the impact of this standard on Barnwell’s consolidated financial statements.
Overview
Barnwell is engaged in the following lines of business: 1) acquiring, developing, producing and selling oil and natural gas in Canada and the U.S. (oil and natural gas segment), 2) leasehold land interests in Hawaii (land investment segment), and 3) drilling wells and installing and repairing water pumping systems in Hawaii (contract drilling segment).
Oil and Natural Gas Segment
Barnwell is involved in the acquisition and development of oil and natural gas properties in Canada where we initiate and participate in acquisition and developmental operations for oil and natural gas on properties in which we have an interest, and evaluate proposals by third parties with regard to participation in exploratory and developmental operations elsewhere. Additionally, through its wholly-owned subsidiaries, Barnwell is involved in several non-operated oil and natural gas investments in Oklahoma and Texas.
Land Investment Segment
Through Barnwell’s 77.6% interest in Kaupulehu Developments, 75% interest in KD Kona, and 34.45% non-controlling interest in KKM Makai, the Company’s land investment interests include the following:
•The right to receive percentage of sales payments from KD I resulting from the sale of single-family residential lots by KD I, within Increment I of the Kaupulehu Lot 4A area located in the North Kona District of the island of Hawaii. However, in the quarter ended March 31, 2024, the last two remaining single-family lots of the 80 lots developed within Increment I were sold and there are no more lots available for sale in Increment I. Kaupulehu Developments was entitled to receive payments from KD I based on 10% of the gross receipts from KD I’s sales at Increment I.
•The right to receive 15% of the distributions of KD II, the cost of which is to be solely borne by KDK out of its 55% ownership interest in KD II, plus a priority payout of 10% of KDK's cumulative net profits derived from Increment II sales subsequent to Phase 2A, up to a maximum
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of $3,000,000. Such interests are limited to distributions or net profits interests and Barnwell does not have any partnership interest in KD II or KDK through its interest in Kaupulehu Developments. Barnwell also has rights to three single-family residential lots in Phase 2A of Increment II, and four single-family residential lots in phases subsequent to Phase 2A when such lots are developed by KD II, all at no cost to Barnwell. Barnwell is committed to commence construction of improvements within 90 days of the transfer of the four lots in the phases subsequent to Phase 2A as a condition of the transfer of such lots. Also, in addition to Barnwell's existing obligations to pay professional fees to certain parties based on percentages of its gross receipts, Kaupulehu Developments is also obligated to pay an amount equal to 0.72% and 0.20% of the cumulative net profits of KD II to KD Development, LLC and a pool of various individuals, respectively, all of whom are partners of KKM and are unrelated to Barnwell. The remaining acreage within Increment II is not yet under development, and there is no assurance that development of such acreage will in fact occur. No definitive development plans have been made by KD II, the developer of Increment II, as of the date of this report.
•An indirect 19.6% non-controlling ownership interest in KD Kukio Resorts, LLLP, KD Maniniowali, LLLP and KD I and an indirect 10.8% non-controlling ownership interest in KD II through KDK. These entities, collectively referred to hereinafter as the “Kukio Resort Land Development Partnerships,” own certain real estate and development rights interests in the Kukio, Maniniowali and Kaupulehu portions of Kukio Resort, a private residential community on the Kona coast of the island of Hawaii, as well as Kukio Resort’s real estate sales office operations. KDK was the developer of Kaupulehu Lot 4A Increments I and II. The partnerships derive income from the sale of residential parcels in Increment I, which is now completely sold, as well as from commissions on real estate resales by the real estate sales office and revenues resulting from the sale of private club memberships, a few of which remain available for sale.
The Kukio Resort Land Development Partnerships have remaining Increment I obligations to complete project amenities, infrastructure, beautification, and restoration of certain areas and therefore has yet to fully recognize its deferred profit on the Increment I project as a whole. The Increment I deferred profit at December 31, 2024 for the Kukio Resort Land Development Partnerships as a whole was approximately $4,500,000; the recognition of which is dependent upon the completion of the Increment I obligations. The Kukio Resort Land Development Partnerships have accrued estimated costs of these obligations of approximately $3,000,000. The Kukio Resort Land Development Partnerships currently appears to have the ability to fund those obligations but there are no assurances that it can ultimately do so in the future if unforeseen events occur. The Kukio Resort Land Development Partnerships will recognize the Increment I deferred revenue and costs of sales on a percentage completion basis as the cash outlays to complete the remaining project obligations are made. The Kukio Resort Land Development Partnerships’ deferred profit and accrued costs to complete are not reflected in Barnwell’s Condensed Consolidated Balance Sheets as we account for our investment in the Kukio Resort Land Development Partnerships under the equity method of accounting. No percentage of sales payments will be earned by Barnwell on any future recognition of Increment I deferred profit as such payments were already fully earned and received based on cash received by the Kukio Resort Land Development Partnerships as the Increment I lots were sold.
•Approximately 1,000 acres of vacant leasehold land zoned conservation in the Kaupulehu Lot 4C area, which currently has no development potential without both a development agreement with the lessor and zoning reclassification. The lease terminates in December 2025.
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Contract Drilling Segment
Barnwell’s wholly-owned subsidiary, Water Resources International, Inc. (“Water Resources”), drills water and water monitoring wells and installs and repairs water pumping systems in Hawaii.
Results of Operations
Summary
The net loss attributable to Barnwell for the three months ended December 31, 2024 totaled $1,917,000, a $1,253,000 decrease in operating results from net loss of $664,000 for the three months ended December 31, 2023. The following factors affected the results of operations for the three months ended December 31, 2024 as compared to the same period in the prior year:
•A $997,000 decrease in oil and natural gas segment operating results, before income taxes, primarily attributable to a $613,000 non-cash ceiling test impairment in the current year period and due to decreases in natural gas, oil, and natural gas liquids prices and production in the current year period as compared to the same period in the prior year;
•A $477,000 increase in negative impacts due to a $351,000 foreign currency loss recorded in the current period as compared to a $126,000 gain recorded in the prior year period due to the effects of foreign currency exchange rate changes on intercompany loans and advances as a result of changes in the U.S. dollar against the Canadian dollar; and
•Partially offsetting these decreases was a $123,000 decrease in general and administrative expenses primarily due to a decrease in professional fees in the current year period as compared to the same period in the prior year and a $14,000 credit loss recovery recorded in the current year period as compared to a $37,000 credit loss expense in the prior year period.
General
Barnwell conducts operations in the U.S. and Canada. Consequently, Barnwell is subject to foreign currency translation and transaction gains and losses due to fluctuations of the exchange rates between the Canadian dollar and the U.S. dollar. Barnwell cannot accurately predict future fluctuations of the exchange rates and the impact of such fluctuations may be material from period to period. To date, we have not entered into foreign currency hedging transactions. Foreign currency gains or losses on intercompany loans and advances that are not considered long-term investments in nature because management intends to settle these intercompany balances in the future are included in our statements of operations.
The average exchange rate of the Canadian dollar to the U.S. dollar decreased 3% in the three months ended December 31, 2024 as compared to the same period in the prior year, and the exchange rate of the Canadian dollar to the U.S. dollar decreased 6% at December 31, 2024 as compared to September 30, 2024. Accordingly, the assets, liabilities, stockholders’ equity and revenues and expenses of Barnwell’s subsidiaries operating in Canada have been adjusted to reflect the change in the exchange rates. Other comprehensive income and losses are not included in net earnings and net loss. Other comprehensive income due to foreign currency translation adjustments, net of taxes, for the three months ended December 31, 2024 was $93,000, a $63,000 change from other comprehensive income due to foreign currency translation adjustments, net of taxes, of $30,000 for the same period in the prior year.
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There were no taxes on other comprehensive income due to foreign currency translation adjustments in the three months ended December 31, 2024 and 2023 due to a full valuation allowance on the related deferred tax assets.
Oil and natural gas
The following tables set forth Barnwell’s average prices per unit of production and net production volumes. Production amounts reported are net of royalties.

| Average Price Per Unit
| Three months ended |  | Increase
| December 31, |  | (Decrease)
| 2024 |  | 2023 |  | $ |  | %
Natural Gas (Mcf)* | $ | 1.09 |  |  | $ | 1.82 |  |  | $ | (0.73) |  |  | (40 | %)
Oil (Bbls)** | $ | 65.53 |  |  | $ | 67.08 |  |  | $ | (1.55) |  |  | (2 | %)
Natural gas liquids (Bbls)** | $ | 26.98 |  |  | $ | 29.23 |  |  | $ | (2.25) |  |  | (8 | %)

| Net Production
| Three months ended |  | Increase
| December 31, |  | (Decrease)
| 2024 |  | 2023 |  | Units |  | %
Natural Gas (Mcf)* | 298,000 |  |  | 379,000 |  |  | (81,000) |  |  | (21 | %)
Oil (Bbls)** | 48,000 |  |  | 58,000 |  |  | (10,000) |  |  | (17 | %)
Natural gas liquids (Bbls)** | 15,000 |  |  | 18,000 |  |  | (3,000) |  |  | (17 | %)

_______________________________________
* Mcf = 1,000 cubic feet. Natural gas price per unit is net of pipeline charges.
** Bbl = stock tank barrel equivalent to 42 U.S. gallons
The oil and natural gas segment generated an $116,000 operating loss before general and administrative expenses in the three months ended December 31, 2024, a decrease in operating results of $997,000 as compared to a $881,000 operating profit before general and administrative expenses generated during the same period of the prior year.
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The following table sets forth Barnwell’s oil and natural gas segment operating (loss) profit before general and administrative expenses by geographic location:

| Three months ended December 31,
| 2024 |  | 2023
Operating (loss) profit (before general and administrative expenses) |  |  |
Canada | $ | 402,000 |  |  | $ | 536,000 |
United States (1) | (518,000) |  |  | 345,000 |
Total operating (loss) profit | $ | (116,000) |  |  | $ | 881,000 |

________________________
(1) The operating loss for the United States for the three months ended December 31, 2024 includes a non-cash ceiling test impairment of $613,000.
Oil and natural gas segment revenues decreased $1,233,000 (24%) for the three months ended December 31, 2024, as compared to the same period in the prior year, primarily due to decreases in oil, natural gas and natural gas liquids production, which decreased 17%, 21% and 17%, respectively, as compared to the same period in the prior year. The decrease was also attributable to decreases in natural gas, oil, and natural gas liquids prices, which decreased 40%, 2%, and 8%, respectively, as compared to the same period in the prior year.
The decreases in production are primarily the result of natural declines as the wells age. The production decreases were also partially due to properties sold and certain wells that were temporarily shut-in for workovers. The Company's latest Canadian well drilled, which is 100%-owned and operated, started producing in mid-September 2024 and contributed approximately 107 net barrels of equivalent per day for a total of approximately 10,000 net barrels of equivalent during the three months ended December 31, 2024.
In the quarter ended December 31, 2023, the Company amended certain of its Canadian purchase and sales contracts to change the sales price on 1,055 gross Mcf per day of the Canadian natural gas that it sold during the period from April 1, 2024 to October 31, 2024 to a fixed index price before differentials of $2.55 Canadian dollars per Mcf, with remaining volumes continuing to be sold at spot prices. In July 2024, the Company amended the sales price on 1,055 gross Mcf per day of the Canadian natural gas it will sell during the period from November 1, 2024 to March 31, 2025 to a fixed index price before differentials of $2.64 Canadian dollars per Mcf, with remaining volumes continuing to be sold at spot prices. This per day volume of natural gas under this fixed index price contract that will affect the period from January 1, 2025 to March 31, 2025, is equivalent to approximately 38% of Canadian natural gas gross production per day for the quarter ended December 31, 2024. These natural gas contracts were eligible for and elected as normal purchase and normal sales exception contracts and were thus excluded from derivative accounting.
In July 2024, the Company amended certain of its Canadian purchase and sales contracts to change the sales price on 100 gross barrels per day of the Canadian oil that it sold during the period from August 1, 2024 to December 31, 2024 to a fixed index price before differentials of $79.00 per net barrel, with remaining volumes continuing to be sold at spot prices. This per day volume of oil under this fixed index price contract was equivalent to approximately 17% of Canadian oil gross production per day for the quarter ended December 31, 2024. These oil contracts were eligible for and elected as normal purchase and normal sales exception contracts and were thus excluded from derivative accounting.
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Oil and natural gas segment operating expenses decreased $295,000 (11%) for the three months ended December 31, 2024, as compared to the same period in the prior year, due to lower production, partially offset by an increase in workovers and repair costs in the current year, as compared to the same period in the prior year.
Oil and natural gas segment depletion decreased $554,000 (38%) for the three months ended December 31, 2024, as compared to the prior year period. The decrease was due to both a decrease in the depletion rate and a decrease in production. The depletion rate decreased as a result of a decrease in the depletable base from significant ceiling test impairments between the prior year period and the current year period.
Contract drilling
The contract drilling segment generated a $201,000 operating loss before general and administrative expenses in the three months ended December 31, 2024, an increase in operating results of $27,000 as compared to a $228,000 operating loss during the same period of the prior year. Contract drilling revenues and contract drilling costs decreased $450,000 (45%) and $449,000 (38%), respectively, for the three months ended December 31, 2024, as compared to the same period in the prior year. These decreases were primarily due to less activity in the current year period as compared to the same period in the prior year. The contract drilling segment worked on only one water well drilling job in the current year period, as compared to three water well drilling jobs and one pump installation job in the prior year period.
In December 2024, the Company entered into an agreement with an independent third party for the sale of a contract drilling segment drilling rig and related ancillary equipment, which are all fully depreciated, and received a payment of $585,000 from the buyer. At December 31, 2024, the delivery of the drilling rig and the transfer of the legal title to the buyer had not yet occurred and therefore, the Company did not record a sale during the three months ended December 31, 2024. The payment received from the buyer was recognized as a deposit and recorded in “Other current liabilities” on the Company's Condensed Consolidated Balance Sheet at December 31, 2024.
In February 2025, the drilling rig was delivered and the legal title was transferred to the buyer and as a result, the Company will recognize a gain, net of costs, on the sale of the drilling rig in the quarter ending March 31, 2025.
The Company continues to investigate strategies regarding Water Resources' future including, but not limited to, other potential opportunities for a sale of its stock or assets. If no sale of its stock or assets along with contract backlog can be secured, Water Resources will likely be wound down after all contracts in backlog are completed and any remaining drilling rigs and equipment will be liquidated. Management estimates that its three remaining contracts in backlog at December 31, 2024 will be completed in March 2025 or soon thereafter, however it is uncertain as to when the contingent liability related to the required drilling of a monitoring well in satisfaction of a regulatory assessment will be settled (see Note 14 in the “Notes to Consolidated Financial Statements” of this report).
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General and administrative expenses
General and administrative expenses decreased $123,000 (9%) for the three months ended December 31, 2024, as compared to the same period in the prior year. The decrease was due to a decrease in professional fees in the current year period as compared to the same period in the prior year and a $14,000 credit loss recovery recorded in the current year period as compared to a $37,000 credit loss expense in the prior year period.
Depletion, depreciation, and amortization
Depletion, depreciation, and amortization decreased $583,000 (39%) for the three months ended December 31, 2024, as compared to the same period in the prior year, primarily due to both a decrease in the depletion rate and a decrease in production, as discussed in the “Oil and natural gas” section above.
Impairment of assets
Under the full cost method of accounting, the Company performs quarterly oil and natural gas ceiling test calculations. Changes in the 12-month rolling average first-day-of-the-month prices for oil, natural gas and natural gas liquids prices (except where prices are defined by contractual arrangements), the value of reserve additions as compared to the amount of capital expenditures to obtain them, and changes in production rates and estimated levels of reserves, future development costs and the market value of unproved properties, impact the determination of the maximum carrying value of oil and natural gas properties.
During the three months ended December 31, 2024, the Company incurred a non-cash ceiling test impairment for our U.S. oil and natural gas properties of $613,000. There was no ceiling test impairment during the three months ended December 31, 2023.
As discussed above, the ceiling test uses a 12-month historical rolling average first-day-of-the-month prices. As such, declines in the 12-month historical rolling average first-day-of-the-month prices used in our ceiling test calculation in future periods could result in impairment write-downs in future periods in the absence of any offsetting factors that are not currently known or projected.
Foreign currency loss (gain)
During the three months ended December 31, 2024 and 2023, there was a $351,000 foreign currency loss and a $126,000 foreign currency gain, respectively, due to the effects of foreign exchange rate changes on intercompany loans and advances as a result of changes in the exchange rate between the U.S. dollar against the Canadian dollar. The foreign currency losses or gains from intercompany balances are included in our our consolidated statement of operations as the intercompany balances were not considered long-term in nature because management estimates that these intercompany balances will be settled in the future.
Income taxes
Barnwell’s effective consolidated income tax rate for the three months ended December 31, 2024, after adjusting loss before income taxes for non-controlling interests, was nil, as compared to an effective income tax rate of (11)% for the three months ended December 31, 2023.
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Consolidated taxes do not bear a customary relationship to pretax results due primarily to the fact that the Company is taxed separately in Canada based on Canadian source operations and in the U.S. based on consolidated operations, and essentially all deferred tax assets, net of relevant offsetting deferred tax liabilities, are not estimated to have a future benefit as tax credits or deductions. The Company operates two subsidiaries in Canada, one of which is a U.S. corporation operating as a branch in Canada that is treated as a non-resident for Canadian tax purposes and thus has operating results that cannot be offset against or combined with the other Canadian subsidiary that files as a resident for Canadian tax purposes. Income from our non-controlling interest in the Kukio Resort Land Development Partnerships is treated as non-unitary for state of Hawaii unitary filing purposes, thus unitary Hawaii losses provide limited sheltering of such non-unitary income. Income from our investment in the Oklahoma oil venture is 100% allocable to Oklahoma. As such, Barnwell receives no benefit from consolidated or unitary losses and, therefore, is subject to Oklahoma state taxes. Our operations in Texas are subject to a franchise tax assessed by the state of Texas, however no significant amounts have been incurred to date.
Liquidity and Capital Resources
At December 31, 2024, Barnwell had $642,000 in working capital. Barnwell’s primary sources of liquidity are cash on hand and cash flow generated by our oil and natural gas operations, as cash flow from our land investment segment, if any, are expected to be minimal.
In recent years, the Company generated a significant amount of cash inflows from its land investment segment, however, there are no more lots available for sale in Increment I. In addition, no definitive development plans have been made by the developer of Increment II as of the date of this report and thus future cash inflows from the land investment segment are uncertain. Management estimates that cash flows from the sale of the contract drilling segment business or its operating assets may also provide some level of liquidity in the near-term. The Company will primarily be reliant upon sufficient operating cash inflows from its oil and natural gas segment, which in turn will be largely determined by prices and production levels. A certain level of oil and natural gas capital expenditures will be necessary to grow reserves and production or at a minimum replace declining production from aging wells. Such a level of oil and natural gas capital expenditures may require funding from external debt or equity sources that are not currently in place, but those sources may not be feasible or sufficient. Management estimates that, barring any significant unforeseen events, it is more likely than not that there is sufficient cash on hand, cash flows from contract drilling segment asset sales and cash flows from oil and natural gas segment operations to continue as a going concern for the twelve months from the filing of this report. However, the aforementioned factors will influence the Company’s liquidity beyond that twelve month period.
Cash Flows
Cash flows used in operating activities totaled $759,000 for the three months ended December 31, 2024, as compared to cash flows provided by operating activities of $1,375,000 for the three months ended December 31, 2023. This $2,134,000 change in operating cash flows was primarily due to changes in working capital and lower operating results for the oil and natural gas segment in the current year period as compared to the same period in the prior year. The adjustment in operating cash flows due to the effect of changes in current assets and liabilities was a decrease of $793,000 in the current year period as compared to an increase of $606,000 in the prior year period.
Cash flows used in investing activities totaled $1,662,000 during the three months ended December 31, 2024, as compared to cash flows used in investing activities of $1,019,000 during the same period of the prior year. This $643,000 change in investing cash flows was due to $1,511,000 more in cash
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paid for investments in oil and natural gas properties in the current year as compared to the same period in the prior year, partially offset by a $585,000 deposit received for a pending sale of a contract drilling segment drilling rig and $282,000 of proceeds from the sale of oil and natural gas properties in Canada in the current year period; there were no such amounts in the same period of the prior year.
Oil and Natural Gas Capital Expenditures
Barnwell’s oil and natural gas capital expenditures, including accrued capital expenditures and excluding additions and revisions to estimated asset retirement obligations, totaled $314,000 for the three months ended December 31, 2024, as compared to $495,000 for the same period in the prior year.
Barnwell estimates that investments in oil and natural gas properties for fiscal 2025 will range from $1,500,000 to $3,000,000. This estimated amount may increase or decrease as dictated by cash flows and management's assessment of the oil and natural gas environment and prospects.
Oil and Natural Gas Property Dispositions
There were no significant oil and natural gas property dispositions during the three months ended December 31, 2024. The $282,000 of proceeds from sale of oil and natural gas properties included in the Condensed Consolidated Statement of Cash Flows for the three months ended December 31, 2024 represents proceeds that were credited to our cash in October 2024 from a sale of properties that closed in late September 2024.
ITEM 4. CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
We have established disclosure controls and procedures to ensure that material information relating to Barnwell, including its consolidated subsidiaries, is made known to the officers who certify Barnwell’s financial reports and to other members of executive management and the Board of Directors.
As of December 31, 2024, an evaluation was carried out by Barnwell’s Chief Executive Officer and Chief Financial Officer of the effectiveness of Barnwell’s disclosure controls and procedures. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that Barnwell’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) were effective as of December 31, 2024 to ensure that information required to be disclosed by Barnwell in the reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the Securities Exchange Act of 1934 and the rules thereunder.
Changes in Internal Control Over Financial Reporting
There was no change in Barnwell’s internal control over financial reporting during the quarter ended December 31, 2024 that materially affected, or is reasonably likely to materially affect, Barnwell’s internal control over financial reporting.
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PART II - OTHER INFORMATION
ITEM 1A. RISK FACTORS
In addition to the other information set forth in this Quarterly Report on Form 10-Q, the reader should carefully consider the factors discussed in Part I, “Item 1A. Risk Factors” in the Company’s Annual Report on Form 10-K for the year ended September 30, 2024. There have been no material changes in the Company's risk factors from those disclosed in Part I, Item 1A, of the Company's Annual Report on Form 10-K for the fiscal year ended September 30, 2024, except for the item listed below.
Entity-Wide Risks
Actions of activist stockholders could impact the pursuit of our business strategies and adversely affect our results of operations, financial condition and/or share price.
Our Board of Directors and management team value constructive input from investors and are committed to acting in the best interests of all our stockholders. However, activist stockholders who disagree with the composition of the Board of Directors, our strategy, or the way the Company is managed may seek to effect change through various strategies and channels, such as through commencing a proxy contest, making public statements critical of our performance or business or engaging in other similar activities. Responding to such actions by activist investors can be costly and time-consuming, disruptive to our operations and divert the attention of management, our Board of Directors and our employees, and our ability to execute our strategic plan also could be impaired as a result.
In January 2023, the Company entered into a cooperation and support agreement (the “Cooperation Agreement”) with Alexander C. Kinzler, the Company’s then CEO and President in his capacity as a stockholder, Ned L. Sherwood and certain entities affiliated with Mr. Sherwood, with respect to a potential proxy contest at our 2023 annual meeting of stockholders. Under the terms of the Cooperation Agreement, Mr. Sherwood and his affiliated entities agreed to limit their beneficial and economic ownership of the Company to 28% of the outstanding common stock of the Company for the first 12 months of the agreement and 30% for the second 12-month period. The Cooperation Agreement expired in early February 2025. In both private and public communications, both before and after the expiration of the Cooperation Agreement, Mr. Sherwood has made certain proposals regarding the composition of the Board and the Company’s management team. He also has indicated, through public and private communications, that he intends to nominate a group of candidates to stand for election at the Company’s next annual meeting of stockholders.
In connection with the pending termination of the Cooperation Agreement, in late 2024, our Board authorized the creation of an ad hoc special committee of the Board for the purpose of considering various matters relating to the pending expiration of the Cooperation Agreement and a possible proxy contest or other actions initiated by Mr. Sherwood and his affiliated entities. We have been required to retain the services of various professionals to advise us on matters relating to Mr. Sherwood, including legal and financial advisors. In the event of a proxy contest, we could be required to incur substantially increased legal, public relations and other advisory fees and proxy solicitation expenses. In addition, perceived uncertainties as to our future direction, strategy or leadership created as a consequence may result in the loss of potential business opportunities, harm our ability to attract new or retain existing directors and employees, disrupt relationships with the Company, and the market price of our common stock could also experience periods of increased volatility as a result.
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ITEM 5. OTHER INFORMATION
During the three months ended December 31, 2024, no director or officer of the Company adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408 of Regulation S-K.
ITEM 6. EXHIBITS

Exhibit Number |  | Description
3.2 |  | Amended and Restated Bylaws of Barnwell Industries, Inc. (1)
4.2 |  | Rights Agreement, dated as of January 26, 2025, by and between Barnwell Industries, Inc. and Broadridge Corporate Issuer Solutions, LLC, as rights agent, which includes as Exhibit A the Form of Right Certificate. (2)
4.3 |  | Amendment No. 1 to the Rights Agreement, dated as of February 6, 2025, by and between Barnwell Industries, Inc. and Broadridge Corporate Issuer Solutions, LLC, as Rights agent. (3)
31.1* |  | Certification of Chief Executive Officer Pursuant To Section 302 of the Sarbanes-Oxley Act of 2002
31.2* |  | Certification of Chief Financial Officer Pursuant To Section 302 of the Sarbanes-Oxley Act of 2002
32** |  | Certification Pursuant To Section 906 of the Sarbanes-Oxley Act of 2002
101.INS* |  | Inline XBRL Instance Document
101.SCH* |  | Inline XBRL Taxonomy Extension Schema Document
101.CAL* |  | Inline XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF* |  | Inline XBRL Taxonomy Extension Definition Linkbase Document
101.LAB* |  | Inline XBRL Taxonomy Extension Label Linkbase Document
101.PRE* |  | Inline XBRL Taxonomy Extension Presentation Linkbase Document
104 |  | Cover Page Interactive Data File (embedded within the Inline XBRL document)

__________________________________________________
* Filed herewith.
** Furnished herewith.
(1) Incorporated by reference to Exhibit 3.2 to Registrant’s Current Report on Form 8-K filed on February 5, 2025.
(2) Incorporated by reference to Exhibit 4.1 to Registrant’s Current Report on Form 8-K filed on January 27, 2025.
(3) Incorporated by reference to Exhibit 4.1 to Registrant’s Current Report on Form 8-K filed on February 7, 2025.
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SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

|  | BARNWELL INDUSTRIES, INC.
|  | (Registrant)
Date: | February 14, 2025 | /s/ Russell M. Gifford
|  | Russell M. Gifford
|  | Executive Vice President,
|  | Chief Financial Officer,
|  | and Treasurer

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INDEX TO EXHIBITS

Exhibit Number |  | Description
3.2 |  | Amended and Restated Bylaws of Barnwell Industries, Inc. (1)
4.2 |  | Rights Agreement, dated as of January 26, 2025, by and between Barnwell Industries, Inc. and Broadridge Corporate Issuer Solutions, LLC, as rights agent, which includes as Exhibit A the Form of Right Certificate. (2)
4.3 |  | Amendment No. 1 to the Rights Agreement, dated as of February 6, 2025, by and between Barnwell Industries, Inc. and Broadridge Corporate Issuer Solutions, LLC, as R ights agent. (3)
31.1* |  | Certification of Chief Executive Officer Pursuant To Section 302 of the Sarbanes-Oxley Act of 2002
31.2* |  | Certification of Chief Financial Officer Pursuant To Section 302 of the Sarbanes-Oxley Act of 2002
32** |  | Certification Pursuant To Section 906 of the Sarbanes-Oxley Act of 2002
101.INS* |  | Inline XBRL Instance Document
101.SCH* |  | Inline XBRL Taxonomy Extension Schema Document
101.CAL* |  | Inline XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF* |  | Inline XBRL Taxonomy Extension Definition Linkbase Document
101.LAB* |  | Inline XBRL Taxonomy Extension Label Linkbase Document
101.PRE* |  | Inline XBRL Taxonomy Extension Presentation Linkbase Document
104 |  | Cover Page Interactive Data File (embedded within the Inline XBRL document)

_________________________________________________
* Filed herewith.
** Furnished herewith.
(1) Incorporated by reference to Exhibit 3.2 to Registrant’s Current Report on Form 8-K filed on February 5, 2025.
(2) Incorporated by reference to Exhibit 4.1 to Registrant’s Current Report on Form 8-K filed on January 27, 2025.
(3) Incorporated by reference to Exhibit 4.1 to Registrant’s Current Report on Form 8-K filed on February 7, 2025.
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