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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 March 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

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 May 13, 2024 there were 10,028,090 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 - March 31, 2024 and September 30, 2023 | 3
| Condensed Consolidated Statements of Operations - three and six months ended March 31, 2024 and 2023 | 4
| Condensed Consolidated Statements of Comprehensive Loss - three and six months ended March 31, 2024 and 2023 | 5
| Condensed Consolidated Statements of Equity - three and six months ended March 31, 2024 and 2023 | 6
| Condensed Consolidated Statements of Cash Flows - six months ended March 31, 2024 and 2023 | 8
| Notes to Condensed Consolidated Financial Statements | 9
Item 2. | Management’s Discussion and Analysis of Financial Condition and Results of Operations | 27
Item 4. | Controls and Procedures | 39
PART II. | OTHER INFORMATION: |
Item 6. | Exhibits | 40
| Signature | 41
| Index to Exhibits | 42

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

| March 31, 2024 |  | September 30, 2023
ASSETS |  |  |
Current assets: |  |  |
Cash and cash equivalents | $ | 3,685,000 |  |  | $ | 2,830,000 |
Accounts and other receivables, net of allowance for credit losses of: $339,000 at March 31, 2024; $284,000 at September 30, 2023 | 3,385,000 |  |  | 3,246,000 |
Assets held for sale | 69,000 |  |  | — |
Other current assets | 2,507,000 |  |  | 3,009,000 |
Total current assets | 9,646,000 |  |  | 9,085,000 |
Asset for retirement benefits | 4,649,000 |  |  | 4,471,000 |
Operating lease right-of-use assets | 79,000 |  |  | 54,000 |
Property and equipment: |  |  |
Proved oil and natural gas properties (full cost method) | 82,118,000 |  |  | 80,851,000 |
Drilling rigs and other property and equipment | 3,752,000 |  |  | 7,223,000 |
Total property and equipment | 85,870,000 |  |  | 88,074,000 |
Accumulated depletion, impairment, depreciation, and amortization | (67,462,000) |  |  | (66,263,000) |
Total property and equipment, net | 18,408,000 |  |  | 21,811,000 |
Total assets | $ | 32,782,000 |  |  | $ | 35,421,000 |
LIABILITIES AND EQUITY |  |  |
Current liabilities: |  |  |
Accounts payable | $ | 1,257,000 |  |  | $ | 881,000 |
Accrued capital expenditures | 528,000 |  |  | 1,099,000 |
Accrued compensation | 396,000 |  |  | 726,000 |
Accrued operating and other expenses | 1,671,000 |  |  | 1,747,000 |
Current portion of asset retirement obligation | 1,828,000 |  |  | 1,536,000 |
Other current liabilities | 634,000 |  |  | 609,000 |
Total current liabilities | 6,314,000 |  |  | 6,598,000 |
Operating lease liabilities | 25,000 |  |  | 47,000 |
Liability for retirement benefits | 1,710,000 |  |  | 1,664,000 |
Asset retirement obligation | 8,226,000 |  |  | 8,297,000 |
Deferred income tax liabilities | 109,000 |  |  | 58,000 |
Total liabilities | 16,384,000 |  |  | 16,664,000 |
Commitments and contingencies |  |  |
Equity: |  |  |
Common stock, par value $0.50 per share; authorized, 40,000,000 shares: 10,195,990 issued at March 31, 2024; 10,158,678 issued at September 30, 2023 | 5,098,000 |  |  | 5,079,000 |
Additional paid-in capital | 7,779,000 |  |  | 7,687,000 |
Retained earnings | 3,724,000 |  |  | 6,160,000 |
Accumulated other comprehensive income, net | 2,069,000 |  |  | 2,104,000 |
Treasury stock, at cost: 167,900 shares at March 31, 2024 and September 30, 2023 | (2,286,000) |  |  | (2,286,000) |
Total stockholders’ equity | 16,384,000 |  |  | 18,744,000 |
Non-controlling interests | 14,000 |  |  | 13,000 |
Total equity | 16,398,000 |  |  | 18,757,000 |
Total liabilities and equity | $ | 32,782,000 |  |  | $ | 35,421,000 |

See Notes to Condensed Consolidated Financial Statements
3

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

| Three months ended March 31, |  | Six months ended March 31,
| 2024 |  | 2023 |  | 2024 |  | 2023
Revenues: |  |  |  |  |  |  |
Oil and natural gas | $ | 4,144,000 |  |  | $ | 3,686,000 |  |  | $ | 9,274,000 |  |  | $ | 8,912,000 |
Contract drilling | 1,070,000 |  |  | 1,501,000 |  |  | 2,063,000 |  |  | 3,449,000 |
Sale of interest in leasehold land | 500,000 |  |  | — |  |  | 500,000 |  |  | 265,000 |
Gas processing and other | 60,000 |  |  | 52,000 |  |  | 92,000 |  |  | 124,000 |
| 5,774,000 |  |  | 5,239,000 |  |  | 11,929,000 |  |  | 12,750,000 |
Costs and expenses: |  |  |  |  |  |  |
Oil and natural gas operating | 2,330,000 |  |  | 2,267,000 |  |  | 5,121,000 |  |  | 4,711,000 |
Contract drilling operating | 1,387,000 |  |  | 1,401,000 |  |  | 2,556,000 |  |  | 3,258,000 |
General and administrative | 1,381,000 |  |  | 2,050,000 |  |  | 2,785,000 |  |  | 4,299,000 |
Depletion, depreciation, and amortization | 1,392,000 |  |  | 761,000 |  |  | 2,903,000 |  |  | 1,601,000 |
Impairment of assets | 1,677,000 |  |  | — |  |  | 1,677,000 |  |  | — |
Foreign currency loss (gain) | 128,000 |  |  | (2,000) |  |  | 2,000 |  |  | (80,000) |
Interest expense | — |  |  | — |  |  | 2,000 |  |  | — |
Gain on sale of assets | — |  |  | — |  |  | — |  |  | (551,000) |
| 8,295,000 |  |  | 6,477,000 |  |  | 15,046,000 |  |  | 13,238,000 |
Loss before equity in income of affiliates and income taxes | (2,521,000) |  |  | (1,238,000) |  |  | (3,117,000) |  |  | (488,000) |
Equity in income of affiliates | 1,071,000 |  |  | — |  |  | 1,071,000 |  |  | 538,000 |
(Loss) earnings before income taxes | (1,450,000) |  |  | (1,238,000) |  |  | (2,046,000) |  |  | 50,000 |
Income tax provision (benefit) | 100,000 |  |  | (3,000) |  |  | 166,000 |  |  | 76,000 |
Net loss | (1,550,000) |  |  | (1,235,000) |  |  | (2,212,000) |  |  | (26,000) |
Less: Net earnings attributable to non-controlling interests | 222,000 |  |  | 2,000 |  |  | 224,000 |  |  | 122,000 |
Net loss attributable to Barnwell Industries, Inc. | $ | (1,772,000) |  |  | $ | (1,237,000) |  |  | $ | (2,436,000) |  |  | $ | (148,000) |
Basic and diluted net loss per common share attributable to Barnwell Industries, Inc. stockholders | $ | (0.18) |  |  | $ | (0.12) |  |  | $ | (0.24) |  |  | $ | (0.01) |
Weighted-average number of common shares outstanding: |  |  |  |  |  |  |
Basic and diluted | 10,019,172 |  |  | 9,956,687 |  |  | 10,007,905 |  |  | 9,956,687 |

See Notes to Condensed Consolidated Financial Statements
4

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

| Three months ended March 31, |  | Six months ended March 31,
| 2024 |  | 2023 |  | 2024 |  | 2023
Net loss | $ | (1,550,000) |  |  | $ | (1,235,000) |  |  | $ | (2,212,000) |  |  | $ | (26,000) |
Other comprehensive (loss) income: |  |  |  |  |  |  |
Foreign currency translation adjustments, net of taxes of $0 | (22,000) |  |  | — |  |  | 8,000 |  |  | 2,000 |
Retirement plans: |  |  |  |  |  |  |
Amortization of accumulated other comprehensive gain into net periodic benefit cost, net of taxes of $0 | (22,000) |  |  | (20,000) |  |  | (43,000) |  |  | (40,000) |
Total other comprehensive loss | (44,000) |  |  | (20,000) |  |  | (35,000) |  |  | (38,000) |
Total comprehensive loss | (1,594,000) |  |  | (1,255,000) |  |  | (2,247,000) |  |  | (64,000) |
Less: Comprehensive income attributable to non-controlling interests | (222,000) |  |  | (2,000) |  |  | (224,000) |  |  | (122,000) |
Comprehensive loss attributable to Barnwell Industries, Inc. | $ | (1,816,000) |  |  | $ | (1,257,000) |  |  | $ | (2,471,000) |  |  | $ | (186,000) |

See Notes to Condensed Consolidated Financial Statements
5

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

| Shares Outstanding |  | Common Stock |  | Additional Paid-In Capital |  | Retained Earnings |  | Accumulated Other Comprehensive Income |  | Treasury Stock |  | Non-controlling Interests |  | Total Equity
Balance at December 31, 2022 | 9,956,687 |  |  | $ | 5,062,000 |  |  | $ | 7,466,000 |  |  | $ | 8,660,000 |  |  | $ | 1,276,000 |  |  | $ | (2,286,000) |  |  | $ | 32,000 |  |  | $ | 20,210,000 |
Net (loss) earnings | — |  |  | — |  |  | — |  |  | (1,237,000) |  |  | — |  |  | — |  |  | 2,000 |  |  | (1,235,000) |
Distributions to non-controlling interests | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (16,000) |  |  | (16,000) |
Share-based compensation | — |  |  | — |  |  | 75,000 |  | — |  |  | — |  |  | — |  |  | — |  |  | 75,000
Dividends declared, $0.015 per share | — |  |  | — |  |  | — |  |  | (150,000) |  |  | — |  |  | — |  |  | — |  |  | (150,000) |
Retirement plans: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Amortization of accumulated other comprehensive gain into net periodic benefit cost, net of taxes of $0 | — |  |  | — |  |  | — |  |  | — |  |  | (20,000) |  |  | — |  |  | — |  |  | (20,000) |
Balance at March 31, 2023 | 9,956,687 |  |  | $ | 5,062,000 |  |  | $ | 7,541,000 |  |  | $ | 7,273,000 |  |  | $ | 1,256,000 |  |  | $ | (2,286,000) |  |  | $ | 18,000 |  |  | $ | 18,864,000 |
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 |
Net (loss) earnings | — |  |  | — |  |  | — |  |  | (1,772,000) |  |  | — |  |  | — |  |  | 222,000 |  |  | (1,550,000) |
Foreign currency translation adjustments, net of taxes of $0 | — |  |  | — |  |  | — |  |  | — |  |  | (22,000) |  |  | — |  |  | — |  |  | (22,000) |
Distributions to non-controlling interests | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (219,000) |  |  | (219,000) |
Share-based compensation | — |  |  | — |  |  | 46,000 |  | — |  |  | — |  |  | — |  |  | — |  |  | 46,000
Issuance of common stock for restricted stock unites vested | 27,984 |  |  | 14,000 |  |  | (14,000) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Retirement plans: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Amortization of accumulated other comprehensive gain into net periodic benefit cost, net of taxes of $0 | — |  |  | — |  |  | — |  |  | — |  |  | (22,000) |  |  | — |  |  | — |  |  | (22,000) |
Balance at March 31, 2024 | 10,028,090 |  |  | $ | 5,098,000 |  |  | $ | 7,779,000 |  |  | $ | 3,724,000 |  |  | $ | 2,069,000 |  |  | $ | (2,286,000) |  |  | $ | 14,000 |  |  | $ | 16,398,000 |

See Notes to Condensed Consolidated Financial Statements
6

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

| Shares Outstanding |  | Common Stock |  | Additional Paid-In Capital |  | Retained Earnings |  | Accumulated Other Comprehensive Income |  | Treasury Stock |  | Non-controlling Interests |  | Total Equity
Balance at September 30, 2022 | 9,956,687 |  |  | $ | 5,062,000 |  |  | $ | 7,351,000 |  |  | $ | 7,720,000 |  |  | $ | 1,294,000 |  |  | $ | (2,286,000) |  |  | $ | 20,000 |  |  | $ | 19,161,000 |
Net (loss) earnings | — |  |  | — |  |  | — |  |  | (148,000) |  |  | — |  |  | — |  |  | 122,000 |  |  | (26,000) |
Foreign currency translation adjustments, net of taxes of $0 | — |  |  | — |  |  | — |  |  | — |  |  | 2,000 |  |  | — |  |  | — |  |  | 2,000 |
Distributions to non-controlling interests | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (124,000) |  |  | (124,000) |
Share-based compensation | — |  |  | — |  |  | 190,000 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 190,000 |
Dividends declared, $0.030 per share | — |  |  | — |  |  | — |  |  | (299,000) |  |  | — |  |  | — |  |  | — |  |  | (299,000) |
Retirement plans: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Amortization of accumulated other comprehensive gain into net periodic benefit cost, net of taxes of $0 | — |  |  | — |  |  | — |  |  | — |  |  | (40,000) |  |  | — |  |  | — |  |  | (40,000) |
Balance at March 31, 2023 | 9,956,687 |  |  | $ | 5,062,000 |  |  | $ | 7,541,000 |  |  | $ | 7,273,000 |  |  | $ | 1,256,000 |  |  | $ | (2,286,000) |  |  | $ | 18,000 |  |  | $ | 18,864,000 |
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 | — |  |  | — |  |  | — |  |  | (2,436,000) |  |  | — |  |  | — |  |  | 224,000 |  |  | (2,212,000) |
Foreign currency translation adjustments, net of taxes of $0 | — |  |  | — |  |  | — |  |  | — |  |  | 8,000 |  |  | — |  |  | — |  |  | 8,000 |
Distributions to non-controlling interests | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (223,000) |  |  | (223,000) |
Share-based compensation | — |  |  | — |  |  | 111,000 |  | — |  |  | — |  |  | — |  |  | — |  |  | 111,000
Issuance of common stock for restricted stock unites vested | 37,312 |  |  | 19,000 |  |  | (19,000) |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Retirement plans: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Amortization of accumulated other comprehensive gain into net periodic benefit cost, net of taxes of $0 | — |  |  | — |  |  | — |  |  | — |  |  | (43,000) |  |  | — |  |  | — |  |  | (43,000) |
Balance at March 31, 2024 | 10,028,090 |  |  | $ | 5,098,000 |  |  | $ | 7,779,000 |  |  | $ | 3,724,000 |  |  | $ | 2,069,000 |  |  | $ | (2,286,000) |  |  | $ | 14,000 |  |  | $ | 16,398,000 |

See Notes to Condensed Consolidated Financial Statements
7

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

| Six months ended March 31,
| 2024 |  | 2023
Cash flows from operating activities: |  |  |
Net loss | $ | (2,212,000) |  |  | $ | (26,000) |
Adjustments to reconcile net loss to net cash |  |  |
provided by operating activities: |  |  |
Equity in income of affiliates | (1,071,000) |  |  | (538,000) |
Depletion, depreciation, and amortization | 2,903,000 |  |  | 1,601,000 |
Impairment of assets | 1,677,000 |  |  | — |
Gain on sale of assets | — |  |  | (551,000) |
Sale of interest in leasehold land, net of fees paid | (439,000) |  |  | (233,000) |
Distributions of income from equity investees | 1,071,000 |  |  | 319,000 |
Retirement benefits income | (173,000) |  |  | (126,000) |
Non-cash rent income | (13,000) |  |  | (12,000) |
Accretion of asset retirement obligation | 434,000 |  |  | 395,000 |
Deferred income tax expense (benefit) | 51,000 |  |  | (57,000) |
Asset retirement obligation payments | (396,000) |  |  | (529,000) |
Share-based compensation expense | 111,000 |  |  | 190,000 |
Retirement plan contributions and payments | (2,000) |  |  | (2,000) |
Credit loss expense | 46,000 |  |  | 18,000 |
Foreign currency loss (gain) | 2,000 |  |  | (80,000) |
Increase from changes in current assets and liabilities | 273,000 |  |  | 365,000 |
Net cash provided by operating activities | 2,262,000 |  |  | 734,000 |
Cash flows from investing activities: |  |  |
Distribution from equity investees in excess of earnings | — |  |  | 219,000 |
Proceeds from sale of interest in leasehold land, net of fees paid | 439,000 |  |  | 233,000 |
Capital expenditures - oil and natural gas | (1,624,000) |  |  | (7,306,000) |
Capital expenditures - all other | (1,000) |  |  | (35,000) |
Advances to operators for capital expenditures | — |  |  | (481,000) |
Net cash used in investing activities | (1,186,000) |  |  | (7,370,000) |
Cash flows from financing activities: |  |  |
Distributions to non-controlling interests | (223,000) |  |  | (124,000) |
Payment of dividends | — |  |  | (299,000) |
Net cash used in financing activities | (223,000) |  |  | (423,000) |
Effect of exchange rate changes on cash and cash equivalents | 2,000 |  |  | 34,000 |
Net increase (decrease) in cash and cash equivalents | 855,000 |  |  | (7,025,000) |
Cash and cash equivalents at beginning of period | 2,830,000 |  |  | 12,804,000 |
Cash and cash equivalents at end of period | $ | 3,685,000 |  |  | $ | 5,779,000 |

See Notes to Condensed Consolidated Financial Statements
8

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), a 75%-owned land investment partnership (KD Kona 2013 LLLP), and a variable interest entity (Teton Barnwell Fund I, LLC) for which the Company is deemed to be the primary beneficiary. 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, 2023 Annual Report on Form 10-K, as amended by our Form 10-K/A Amendment No. 1 (our “2023 Annual Report”). The Condensed Consolidated Balance Sheet as of September 30, 2023 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 March 31, 2024, results of operations, comprehensive loss, and equity for the three and six months ended March 31, 2024 and 2023, and cash flows for the six months ended March 31, 2024 and 2023, have been made. The results of operations for the period ended March 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
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valuation of deferred tax assets, asset retirement obligations, contract drilling estimated costs to complete, proved oil and natural gas reserves, and the carrying value of other assets, and such assumptions may impact the amount at which such items are recorded.
Significant Accounting Policies
Other than as set forth below, 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 2023 Annual Report.
Accounts and Other Receivables
Accounts receivable are recorded at the invoiced amount and do not bear interest. The allowance for credit losses is Barnwell’s best estimate of the amount of current expected credit losses in Barnwell’s existing accounts receivable and is based on the aging of the receivable balances, analysis of historical credit loss rates, and current and future economic conditions affecting collectability. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote. Barnwell does not have any off-balance sheet credit exposure related to its customers.
Derivative Instruments
Barnwell utilizes physical forward commodity contracts to mitigate market price risk on its oil and natural gas output when deemed appropriate. Purchase and sale contracts with a fixed price determined at inception are recorded on the consolidated balance sheet as derivative financial instruments if such contracts are readily convertible to cash - unless the contracts are eligible for and elected as the normal purchases and normal sales exception (“NPNS”); in which case, the contracts are recorded on an accrual basis and the Company recognizes the amounts relating to such transactions during the period when the commodities are physically delivered. The Company generally applies the NPNS exception to eligible oil and natural gas contracts to purchase or sell quantities it expects to use or sell in the normal course of business. The Company has not traded in any derivative contracts other than where the NPNS exception is applied, and it does not apply hedge accounting.
Recently Adopted Accounting Pronouncements
In June 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-13, “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments,” which replaces the incurred loss model with an expected loss model referred to as the current expected credit loss (“CECL”) model. The CECL model is applicable to the measurement of credit losses on financial assets measured at amortized cost, including but not limited to trade receivables. The FASB has subsequently issued other related ASUs which amend ASU 2016-13 to provide clarification and additional guidance. The Company adopted the provisions of this ASU effective October 1, 2023. The adoption of this update did not have an impact on Barnwell’s consolidated financial statements.
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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 76,336 restricted stock units were excluded from the computation of diluted shares for the three and six months ended March 31, 2024, as their inclusion would have been anti-dilutive. Options to purchase 615,000 shares of common stock were excluded from the computation of diluted shares for the three and six months ended March 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 March 31, 2024
| Net Loss (Numerator) |  | Shares (Denominator) |  | Per-Share Amount
Basic | $ | (1,772,000) |  |  | 10,019,172 |  |  | $ | (0.18) |
Effect of dilutive securities - |  |  |  |  |
common stock options and restricted stock units | — |  |  | — |  |  |
Diluted | $ | (1,772,000) |  |  | 10,019,172 |  |  | $ | (0.18) |

| Six months ended March 31, 2024
| Net Loss (Numerator) |  | Shares (Denominator) |  | Per-Share Amount
Basic | $ | (2,436,000) |  |  | 10,007,905 |  |  | $ | (0.24) |
Effect of dilutive securities - |  |  |  |  |
common stock options and restricted stock units | — |  |  | — |  |  |
Diluted | $ | (2,436,000) |  |  | 10,007,905 |  |  | $ | (0.24) |

| Three months ended March 31, 2023
| Net Loss (Numerator) |  | Shares (Denominator) |  | Per-Share Amount
Basic | $ | (1,237,000) |  |  | 9,956,687 |  |  | $ | (0.12) |
Effect of dilutive securities - |  |  |  |  |
common stock options | — |  |  | — |  |  |
Diluted | $ | (1,237,000) |  |  | 9,956,687 |  |  | $ | (0.12) |

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| Six months ended March 31, 2023
| Net Loss (Numerator) |  | Shares (Denominator) |  | Per-Share Amount
Basic | $ | (148,000) |  |  | 9,956,687 |  |  | $ | (0.01) |
Effect of dilutive securities - |  |  |  |  |
common stock options | — |  |  | — |  |  |
Diluted | $ | (148,000) |  |  | 9,956,687 |  |  | $ | (0.01) |

3. 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 sales by the real estate sales office and revenues resulting from the sale of private club memberships. During the three months ended March 31, 2024, the last two remaining single-family lots of the 80 lots developed within Increment I were sold.
Increment II is not yet under development, and there is no assurance that development of such acreage will occur. No definitive development plans have been made by KD II, the developer of Increment II, as of the date of this report.
Barnwell has the right to receive distributions from the Kukio Resort Land Development Partnerships via its non-controlling interest in KD Kona and KKM, based on its respective partnership sharing ratios of 75% and 34.45%, respectively. During the three and six months ended March 31, 2024, Barnwell received cash distributions of $1,071,000 (resulting in a net amount of $953,000, after distributing $118,000 to non-controlling interests) from the Kukio Resort Land Development Partnerships.
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No cash distributions were received during the three months ended March 31, 2023. During the six months ended March 31, 2023, Barnwell received cash distributions of $538,000 from the Kukio Resort Land Development Partnerships resulting in a net amount of $478,000 after distributing $60,000 to non-controlling interests.
Equity in income of affiliates was $1,071,000 for the three and six months ended March 31, 2024, as compared to equity in income of affiliates of nil and $538,000 for the three and six months ended March 31, 2023, respectively.
Summarized financial information for the Kukio Resort Land Development Partnerships is as follows:

| Three months ended March 31,
| 2024 |  | 2023
Revenue | $ | 10,153,000 |  |  | $ | 1,284,000 |
Gross profit | $ | 7,329,000 |  |  | $ | 738,000 |
Net earnings (loss) | $ | 6,658,000 |  |  | $ | (82,000) |

| Six months ended March 31,
| 2024 |  | 2023
Revenue | $ | 12,039,000 |  |  | $ | 4,996,000 |
Gross profit | $ | 8,146,000 |  |  | $ | 3,160,000 |
Net earnings | $ | 7,012,000 |  |  | $ | 1,225,000 |

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 Partnerships 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 Partnerships’ cumulative earnings in excess of distributions during the suspended period exceeds our share of the Kukio Resort Land Development Partnerships’ income recognized for the excess distributions, and during this suspended period any distributions received will be recorded as equity in income of affiliates. Accordingly, the amount of equity in income of affiliates recognized in the six months ended March 31, 2024 was equivalent to the $1,071,000 of distributions received in that period.
Cumulative distributions received from the Kukio Resort Land Development Partnerships in excess of our investment balance was $225,000 at March 31, 2024 and $708,000 at September 30, 2023.
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).
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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. During the three months ended March 31, 2024, the last two remaining single-family lots of the 80 lots developed within Increment I were sold.
The following table summarizes the Increment I revenues from KD I and the amount of fees directly related to such revenues:

| Three months ended March 31, |  | Six months ended March 31,
| 2024 |  | 2023 |  | 2024 |  | 2023
Sale of interest in leasehold land: |  |  |  |  |  |  |
Revenues - sale of interest in leasehold land | $ | 500,000 |  |  | $ | — |  |  | $ | 500,000 |  |  | $ | 265,000 |
Fees - included in general and administrative expenses | (61,000) |  |  | — |  |  | (61,000) |  |  | (32,000) |
Sale of interest in leasehold land, net of fees paid | $ | 439,000 |  |  | $ | — |  |  | $ | 439,000 |  |  | $ | 233,000 |

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.
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.
4. CONSOLIDATED VARIABLE INTEREST ENTITY
In February 2021, Barnwell Industries, Inc. established a new wholly-owned subsidiary named BOK Drilling, LLC (“BOK”) for the purpose of indirectly investing in oil and natural gas exploration and development in Oklahoma. BOK and Gros Ventre Partners, LLC (“Gros Ventre”) entered into the Limited Liability Agreement (the “Teton Operating Agreement”) of Teton Barnwell Fund I, LLC (“Teton Barnwell”), an entity formed for the purpose of directly entering into such oil and natural gas investments. Under the terms of the Teton Operating Agreement, the profits of Teton Barnwell are split between BOK and Gros Ventre at 98% and 2%, respectively, and as the manager of Teton Barnwell, Gros Ventre is paid an annual asset management fee equal to 1% of the cumulative capital contributions made to Teton Barnwell as compensation for its management services. BOK is responsible for 100% of the capital contributions made to Teton Barnwell.
The Company has determined that Teton Barnwell is a variable interest entity (“VIE”) as the entity is structured with non-substantive voting rights and that the Company is the primary beneficiary. This is due to the fact that even though Teton Barnwell has a unanimous consent voting structure, BOK is responsible for 100% of the capital contributions required to fund Teton Barnwell’s future oil exploration and development investments pursuant to the Teton Operating Agreement and thus, BOK has the power to steer the decisions that most significantly impact Teton Barnwell’s economic performance and has the
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obligation to absorb any potential losses that could be significant to Teton Barnwell. As BOK is the primary beneficiary of the VIE, Teton Barnwell’s operating results, assets and liabilities are consolidated by the Company.
The following table summarizes the carrying value of the assets and liabilities of Teton Barnwell that are consolidated by the Company. Intercompany balances are eliminated in consolidation and, thus, are not reflected in the table below.

| March 31, 2024 |  | September 30, 2023
ASSETS |  |  |
Cash and cash equivalents | $ | 19,000 |  |  | $ | 83,000 |
Accounts and other receivables | 213,000 |  |  | 175,000 |
Property and equipment: |  |  |
Proved oil and natural gas properties, net (full cost method) | 501,000 |  |  | 544,000 |
Total assets | $ | 733,000 |  |  | $ | 802,000 |
LIABILITIES |  |  |
Accounts payable | $ | 10,000 |  |  | $ | 10,000 |
Accrued operating and other expenses | 19,000 |  |  | 15,000 |
Total liabilities | $ | 29,000 |  |  | $ | 25,000 |

5. ASSETS HELD FOR SALE
Contract Drilling Segment Property and Equipment
During 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 property and equipment deemed necessary to complete the contract drilling segment's contracts in backlog will continue to be classified as held and used.
6. OIL AND NATURAL GAS PROPERTIES
Investments and Acquisitions
In December 2022, Barnwell Texas, LLC (“Barnwell Texas”), a new wholly-owned subsidiary of the Company, entered into a purchase and sale agreement with an independent third party whereby Barnwell Texas acquired a 22.3% non-operated working interest in oil and natural gas leasehold acreage in the Permian Basin in Texas for cash consideration of $806,000. Additionally, in connection with the purchase of such leasehold interests, Barnwell Texas acquired a 15.4% non-operated working interest in two oil wells in the Wolfcamp Formation in Loving and Ward Counties, Texas and had paid $4,293,000 for its share of the costs to drill, complete, and equip the wells in the six months ended March 31, 2023.
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. During the three and six months ended March 31, 2024, the Company incurred a
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non-cash ceiling test impairment for our Canadian oil and natural gas properties of $1,677,000. There was no ceiling test impairment during the three and six months ended March 31, 2023.
Changes in the 12-month rolling average first-day-of-the-month prices for oil, natural gas and natural gas liquids prices, 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. If oil and natural gas prices decline sufficiently from the 12-month historical rolling average first-day-of-the-month prices used in the ceiling test at March 31, 2024, it is more likely than not that the Company will incur further 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 tables detail the components of net periodic benefit (income) cost for Barnwell’s retirement plans:

| Pension Plan |  | SERP
| Three months ended March 31,
| 2024 |  | 2023 |  | 2024 |  | 2023
Interest cost | $ | 102,000 |  |  | $ | 101,000 |  |  | $ | 24,000 |  |  | $ | 22,000 |
Expected return on plan assets | (191,000) |  |  | (166,000) |  |  | — |  |  | — |
Amortization of net actuarial gain | — |  |  | — |  |  | (22,000) |  |  | (20,000) |
Net periodic benefit (income) cost | $ | (89,000) |  |  | $ | (65,000) |  |  | $ | 2,000 |  |  | $ | 2,000 |

| Pension Plan |  | SERP
| Six months ended March 31,
| 2024 |  | 2023 |  | 2024 |  | 2023
Interest cost | $ | 205,000 |  |  | $ | 203,000 |  |  | $ | 48,000 |  |  | $ | 44,000 |
Expected return on plan assets | (383,000) |  |  | (333,000) |  |  | — |  |  | — |
Amortization of net actuarial gain | — |  |  | — |  |  | (43,000) |  |  | (40,000) |
Net periodic benefit (income) cost | $ | (178,000) |  |  | $ | (130,000) |  |  | $ | 5,000 |  |  | $ | 4,000 |

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 expected to be made to the Pension Plan during fiscal 2024. The SERP plan is unfunded and Barnwell funds benefits when payments are made. Expected payments under the SERP for fiscal 2024 are not material. Fluctuations in actual equity market returns as well as changes
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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.
8. INCOME TAXES
The components of loss before income taxes, after adjusting the loss for non-controlling interests, are as follows:

| Three months ended March 31, |  | Six months ended March 31,
| 2024 |  | 2023 |  | 2024 |  | 2023
United States | $ | 538,000 |  |  | $ | (1,275,000) |  |  | $ | (151,000) |  |  | $ | (1,257,000) |
Canada | (2,210,000) |  |  | 35,000 |  |  | (2,119,000) |  |  | 1,185,000 |
| $ | (1,672,000) |  |  | $ | (1,240,000) |  |  | $ | (2,270,000) |  |  | $ | (72,000) |

The components of the income tax provision (benefit) are as follows:

| Three months ended March 31, |  | Six months ended March 31,
| 2024 |  | 2023 |  | 2024 |  | 2023
Current | $ | 47,000 |  |  | $ | 42,000 |  |  | $ | 115,000 |  |  | $ | 133,000 |
Deferred | 53,000 |  |  | (45,000) |  |  | 51,000 |  |  | (57,000) |
| $ | 100,000 |  |  | $ | (3,000) |  |  | $ | 166,000 |  |  | $ | 76,000 |

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

|  | Three months ended March 31, 2024
|  | Oil and natural gas |  | Contract drilling |  | Land investment |  | Other |  | Total
Revenue streams: |  |  |  |  |  |  |  |  |
| Oil | $ | 2,985,000 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 2,985,000 |
| Natural gas | 678,000 |  |  | — |  |  | — |  |  | — |  |  | 678,000 |
| Natural gas liquids | 481,000 |  |  | — |  |  | — |  |  | — |  |  | 481,000 |
| Drilling and pump | — |  |  | 1,070,000 |  |  | — |  |  | — |  |  | 1,070,000 |
| Contingent residual payments | — |  |  | — |  |  | 500,000 |  |  | — |  |  | 500,000 |
| Other | — |  |  | — |  |  | — |  |  | 42,000 |  |  | 42,000 |
| Total revenues before interest income | $ | 4,144,000 |  |  | $ | 1,070,000 |  |  | $ | 500,000 |  |  | $ | 42,000 |  |  | $ | 5,756,000 |
Geographical regions: |  |  |  |  |  |  |  |  |
| United States | $ | 674,000 |  |  | $ | 1,070,000 |  |  | $ | 500,000 |  |  | $ | 25,000 |  |  | $ | 2,269,000 |
| Canada | 3,470,000 |  |  | — |  |  | — |  |  | 17,000 |  |  | 3,487,000 |
| Total revenues before interest income | $ | 4,144,000 |  |  | $ | 1,070,000 |  |  | $ | 500,000 |  |  | $ | 42,000 |  |  | $ | 5,756,000 |
Timing of revenue recognition: |  |  |  |  |  |  |  |  |
| Goods transferred at a point in time | $ | 4,144,000 |  |  | $ | — |  |  | $ | 500,000 |  |  | $ | 42,000 |  |  | $ | 4,686,000 |
| Services transferred over time | — |  |  | 1,070,000 |  |  | — |  |  | — |  |  | 1,070,000 |
| Total revenues before interest income | $ | 4,144,000 |  |  | $ | 1,070,000 |  |  | $ | 500,000 |  |  | $ | 42,000 |  |  | $ | 5,756,000 |

|  | Three months ended March 31, 2023
|  | Oil and natural gas |  | Contract drilling |  | Land investment |  | Other |  | Total
Revenue streams: |  |  |  |  |  |  |  |  |
| Oil | $ | 2,789,000 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 2,789,000 |
| Natural gas | 616,000 |  |  | — |  |  | — |  |  | — |  |  | 616,000 |
| Natural gas liquids | 281,000 |  |  | — |  |  | — |  |  | — |  |  | 281,000 |
| Drilling and pump | — |  |  | 1,501,000 |  |  | — |  |  | — |  |  | 1,501,000 |
| Other | — |  |  | — |  |  | — |  |  | 29,000 |  |  | 29,000 |
| Total revenues before interest income | $ | 3,686,000 |  |  | $ | 1,501,000 |  |  | $ | — |  |  | $ | 29,000 |  |  | $ | 5,216,000 |
Geographical regions: |  |  |  |  |  |  |  |  |
| United States | $ | 309,000 |  |  | $ | 1,501,000 |  |  | $ | — |  |  | $ | 6,000 |  |  | $ | 1,816,000 |
| Canada | 3,377,000 |  |  | — |  |  | — |  |  | 23,000 |  |  | 3,400,000 |
| Total revenues before interest income | $ | 3,686,000 |  |  | $ | 1,501,000 |  |  | $ | — |  |  | $ | 29,000 |  |  | $ | 5,216,000 |
Timing of revenue recognition: |  |  |  |  |  |  |  |  |
| Goods transferred at a point in time | $ | 3,686,000 |  |  | $ | — |  |  | $ | — |  |  | $ | 29,000 |  |  | $ | 3,715,000 |
| Services transferred over time | — |  |  | 1,501,000 |  |  | — |  |  | — |  |  | 1,501,000 |
| Total revenues before interest income | $ | 3,686,000 |  |  | $ | 1,501,000 |  |  | $ | — |  |  | $ | 29,000 |  |  | $ | 5,216,000 |

18

|  | Six months ended March 31, 2024
|  | Oil and natural gas |  | Contract drilling |  | Land investment |  | Other |  | Total
Revenue streams: |  |  |  |  |  |  |  |  |
| Oil | $ | 6,877,000 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 6,877,000 |
| Natural gas | 1,390,000 |  |  | — |  |  | — |  |  | — |  |  | 1,390,000 |
| Natural gas liquids | 1,007,000 |  |  | — |  |  | — |  |  | — |  |  | 1,007,000 |
| Drilling and pump | — |  |  | 2,063,000 |  |  | — |  |  | — |  |  | 2,063,000 |
| Contingent residual payments | — |  |  | — |  |  | 500,000 |  |  | — |  |  | 500,000 |
| Other | — |  |  | — |  |  | — |  |  | 59,000 |  |  | 59,000 |
| Total revenues before interest income | $ | 9,274,000 |  |  | $ | 2,063,000 |  |  | $ | 500,000 |  |  | $ | 59,000 |  |  | $ | 11,896,000 |
Geographical regions: |  |  |  |  |  |  |  |  |
| United States | $ | 1,428,000 |  |  | $ | 2,063,000 |  |  | $ | 500,000 |  |  | $ | 26,000 |  |  | $ | 4,017,000 |
| Canada | 7,846,000 |  |  | — |  |  | — |  |  | 33,000 |  |  | 7,879,000 |
| Total revenues before interest income | $ | 9,274,000 |  |  | $ | 2,063,000 |  |  | $ | 500,000 |  |  | $ | 59,000 |  |  | $ | 11,896,000 |
Timing of revenue recognition: |  |  |  |  |  |  |  |  |
| Goods transferred at a point in time | $ | 9,274,000 |  |  | $ | — |  |  | $ | 500,000 |  |  | $ | 59,000 |  |  | $ | 9,833,000 |
| Services transferred over time | — |  |  | 2,063,000 |  |  | — |  |  | — |  |  | 2,063,000 |
| Total revenues before interest income | $ | 9,274,000 |  |  | $ | 2,063,000 |  |  | $ | 500,000 |  |  | $ | 59,000 |  |  | $ | 11,896,000 |

|  | Six months ended March 31, 2023
|  | Oil and natural gas |  | Contract drilling |  | Land investment |  | Other |  | Total
Revenue streams: |  |  |  |  |  |  |  |  |
| Oil | $ | 6,273,000 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | 6,273,000 |
| Natural gas | 1,918,000 |  |  | — |  |  | — |  |  | — |  |  | 1,918,000 |
| Natural gas liquids | 721,000 |  |  | — |  |  | — |  |  | — |  |  | 721,000 |
| Drilling and pump | — |  |  | 3,449,000 |  |  | — |  |  | — |  |  | 3,449,000 |
| Contingent residual payments | — |  |  | — |  |  | 265,000 |  |  | — |  |  | 265,000 |
| Other | — |  |  | — |  |  | — |  |  | 72,000 |  |  | 72,000 |
| Total revenues before interest income | $ | 8,912,000 |  |  | $ | 3,449,000 |  |  | $ | 265,000 |  |  | $ | 72,000 |  |  | $ | 12,698,000 |
Geographical regions: |  |  |  |  |  |  |  |  |
| United States | $ | 826,000 |  |  | $ | 3,449,000 |  |  | $ | 265,000 |  |  | $ | 8,000 |  |  | $ | 4,548,000 |
| Canada | 8,086,000 |  |  | — |  |  | — |  |  | 64,000 |  |  | 8,150,000 |
| Total revenues before interest income | $ | 8,912,000 |  |  | $ | 3,449,000 |  |  | $ | 265,000 |  |  | $ | 72,000 |  |  | $ | 12,698,000 |
Timing of revenue recognition: |  |  |  |  |  |  |  |  |
| Goods transferred at a point in time | $ | 8,912,000 |  |  | $ | — |  |  | $ | 265,000 |  |  | $ | 72,000 |  |  | $ | 9,249,000 |
| Services transferred over time | — |  |  | 3,449,000 |  |  | — |  |  | — |  |  | 3,449,000 |
| Total revenues before interest income | $ | 8,912,000 |  |  | $ | 3,449,000 |  |  | $ | 265,000 |  |  | $ | 72,000 |  |  | $ | 12,698,000 |

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

| March 31, 2024 |  | September 30, 2023 |  | September 30, 2022
Accounts receivables from contracts with customers | $ | 3,046,000 |  |  | $ | 2,931,000 |  |  | $ | 4,038,000 |
Contract assets | 714,000 |  |  | 958,000 |  |  | 580,000 |
Contract liabilities | 320,000 |  |  | 377,000 |  |  | 1,087,000 |

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. As of March 31, 2024 and September 30, 2023, the Company had $320,000 and $377,000, respectively, included in “Other current liabilities” in the accompanying Condensed Consolidated Balance Sheets for those performance obligations expected to be completed in the next twelve months.
During the six months ended March 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 $347,000 and $969,000, 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.
20

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 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 March 31, 2024, the Company had three contract drilling jobs with original expected durations of greater than one year. For these contracts, 100% of the remaining performance obligation of $56,000 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 March 31, 2024 and September 30, 2023, the Company had $324,000 and $504,000, respectively, in unamortized preconstruction costs related to contracts that were not completed. During the three months ended March 31, 2024 and 2023, the amortization of preconstruction costs related to contracts were not material. During the six months ended March 31, 2024 and 2023, the amortization of preconstruction costs related to contracts was $155,000 and $178,000, respectively. These amounts have been included in “Contract drilling operating” costs and expenses 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 and six months ended March 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) investing in 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 March 31, |  | Six months ended March 31,
| 2024 |  | 2023 |  | 2024 |  | 2023
Revenues: |  |  |  |  |  |  |
Oil and natural gas | $ | 4,144,000 |  |  | $ | 3,686,000 |  |  | $ | 9,274,000 |  |  | $ | 8,912,000 |
Contract drilling | 1,070,000 |  |  | 1,501,000 |  |  | 2,063,000 |  |  | 3,449,000 |
Land investment | 500,000 |  |  | — |  |  | 500,000 |  |  | 265,000 |
Other | 42,000 |  |  | 29,000 |  |  | 59,000 |  |  | 72,000 |
Total before interest income | 5,756,000 |  |  | 5,216,000 |  |  | 11,896,000 |  |  | 12,698,000 |
Interest income | 18,000 |  |  | 23,000 |  |  | 33,000 |  |  | 52,000 |
Total revenues | $ | 5,774,000 |  |  | $ | 5,239,000 |  |  | $ | 11,929,000 |  |  | $ | 12,750,000 |
Depletion, depreciation, and amortization: |  |  |  |  |  |  |
Oil and natural gas | $ | 1,342,000 |  |  | $ | 718,000 |  |  | $ | 2,800,000 |  |  | $ | 1,514,000 |
Contract drilling | 50,000 |  |  | 43,000 |  |  | 102,000 |  |  | 86,000 |
Other | — |  |  | — |  |  | 1,000 |  |  | 1,000 |
Total depletion, depreciation, and amortization | $ | 1,392,000 |  |  | $ | 761,000 |  |  | $ | 2,903,000 |  |  | $ | 1,601,000 |
Impairment: |  |  |  |  |  |  |
Oil and natural gas | $ | 1,677,000 |  |  | $ | — |  |  | $ | 1,677,000 |  |  | $ | — |
Total impairment | $ | 1,677,000 |  |  | $ | — |  |  | $ | 1,677,000 |  |  | $ | — |
Operating profit (loss) (before general and administrative expenses): |  |  |  |  |  |  |
Oil and natural gas | $ | (1,205,000) |  |  | $ | 701,000 |  |  | $ | (324,000) |  |  | $ | 2,687,000 |
Contract drilling | (367,000) |  |  | 57,000 |  |  | (595,000) |  |  | 105,000 |
Land investment | 500,000 |  |  | — |  |  | 500,000 |  |  | 265,000 |
Other | 42,000 |  |  | 29,000 |  |  | 58,000 |  |  | 71,000 |
Gain on sale of assets | — |  |  | — |  |  | — |  |  | 551,000 |
Total operating (loss) profit | (1,030,000) |  |  | 787,000 |  |  | (361,000) |  |  | 3,679,000 |
Equity in income of affiliates: |  |  |  |  |  |  |
Land investment | 1,071,000 |  |  | — |  |  | 1,071,000 |  |  | 538,000 |
General and administrative expenses | (1,381,000) |  |  | (2,050,000) |  |  | (2,785,000) |  |  | (4,299,000) |
Foreign currency (loss) gain | (128,000) |  |  | 2,000 |  |  | (2,000) |  |  | 80,000 |
Interest expense | — |  |  | — |  |  | (2,000) |  |  | — |
Interest income | 18,000 |  |  | 23,000 |  |  | 33,000 |  |  | 52,000 |
(Loss) earnings before income taxes | $ | (1,450,000) |  |  | $ | (1,238,000) |  |  | $ | (2,046,000) |  |  | $ | 50,000 |

22

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

| Three months ended March 31, |  | Six months ended March 31,
| 2024 |  | 2023 |  | 2024 |  | 2023
Foreign currency translation: |  |  |  |  |  |  |
Beginning accumulated foreign currency translation | $ | 250,000 |  |  | $ | 224,000 |  |  | $ | 220,000 |  |  | $ | 222,000 |
Change in cumulative translation adjustment before reclassifications | (22,000) |  |  | — |  |  | 8,000 |  |  | 2,000 |
Income taxes | — |  |  | — |  |  | — |  |  | — |
Net current period other comprehensive (loss) income | (22,000) |  |  | — |  |  | 8,000 |  |  | 2,000 |
Ending accumulated foreign currency translation | 228,000 |  |  | 224,000 |  |  | 228,000 |  |  | 224,000 |
Retirement plans: |  |  |  |  |  |  |
Beginning accumulated retirement plans benefit income | 1,863,000 |  |  | 1,052,000 |  |  | 1,884,000 |  |  | 1,072,000 |
Amortization of net actuarial gain | (22,000) |  |  | (20,000) |  |  | (43,000) |  |  | (40,000) |
Income taxes | — |  |  | — |  |  | — |  |  | — |
Net current period other comprehensive loss | (22,000) |  |  | (20,000) |  |  | (43,000) |  |  | (40,000) |
Ending accumulated retirement plans benefit income | 1,841,000 |  |  | 1,032,000 |  |  | 1,841,000 |  |  | 1,032,000 |
Accumulated other comprehensive income, net of taxes | $ | 2,069,000 |  |  | $ | 1,256,000 |  |  | $ | 2,069,000 |  |  | $ | 1,256,000 |

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
23

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 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 November 2, 2023, the Board of Directors of the Company granted a total of 76,336 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 dates; provided that, any unvested restricted stock would vest upon a director’s death, disability, a change in control of the Company resulting in the director not continuing as a director or the director not being renominated for election even though he was willing to stand for re-election.
The following table summarizes Barnwell’s restricted stock unit activity from October 1, 2023 through March 31, 2024:

Restricted Stock Units |  | Shares |  | Weighted-Average Grant Date Fair Value
Nonvested at October 1, 2023 |  | — |  |  | $ | — |
Granted |  | 76,336 |  |  | 2.62 |
Vested |  | — |  |  | — |
Forfeited |  | — |  |  | — |
Nonvested at March 31, 2024 |  | 76,336 |  |  | $ | 2.62 |

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 and six months ended March 31, 2024, 2024, the Company recognized share-based compensation expense related to restricted stock units of $31,000 and $61,000, respectively. There was no share-based compensation expense related to restricted stock units recognized during the three and six months ended March 31, 2023. As of March 31, 2024, the total remaining unrecognized compensation cost related to nonvested restricted stock units was $139,000, which is expected to be recognized over the weighted-average remaining requisite service period of 1.7 years.
24

Cash Dividends
No dividends were declared or paid during the six months ended March 31, 2024.
In December 2022, the Company's Board of Directors declared a cash dividend of $0.015 per share that was paid on January 11, 2023 to stockholders of record on December 27, 2022.
In February 2023, the Company's Board of Directors declared a cash dividend of $0.015 per share that was paid on March 13, 2023 to stockholders of record on February 23, 2023.
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 the quarter ended December 31, 2021, it was determined that a contract drilling segment well completed in the period did not meet the contract specifications for plumbness under a gyroscopic plumbness test which the contract required. While the well did pass the cage plumbness test, the contract uses the gyroscopic test as the measure of plumbness. Barnwell and the customer currently have an arrangement where Barnwell will provide for centralizers, armored cabling and a pump installation and removal test to confirm that plumbness is satisfactory. The pump installation and removal test was successfully completed. Barnwell’s management believes the plumbness deviation is not impactful to the performance of the submersible pumps that will be installed in the well. Accordingly, while costs for the centralizers, armored cabling and the pump installation and removal test have been accrued, no accrual has been recorded as of March 31, 2024 for any further costs related to this contract as there is no related probable or estimable contingent liability.
15. INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

| Six months ended March 31,
| 2024 |  | 2023
Supplemental disclosure of cash flow information: |  |  |
Cash paid during the year for: |  |  |
Income taxes paid | $ | 71,000 |  |  | $ | 100,000 |

Capital expenditure accruals related to oil and natural gas exploration and development decreased $569,000 and $105,000 during the six months ended March 31, 2024 and 2023, respectively. Additionally, capital expenditure accruals related to oil and natural gas asset retirement obligations increased $179,000 and $220,000 during the six months ended March 31, 2024 and 2023, respectively.
25

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 3.
During the six months ended March 31, 2024, Barnwell received $500,000 in percentage of sales payments from KD I from the sale of the last two single-family lots within Increment I. During the six months ended March 31, 2023, Barnwell received $265,000 in percentage of sales payments from KD I from the sale of one single-family lot within Increment I.
17. SUBSEQUENT EVENTS
Oil and Natural Gas Property Dispositions
Subsequent to March 31, 2024, Barnwell entered into and completed a purchase and sale agreement with an independent third party and sold its interests in certain natural gas and oil properties located in the Kaybob area of Alberta, Canada. The sales price per the agreement was adjusted for customary purchase price adjustments to $448,000 in order to, among other things, reflect an economic effective date of May 1, 2024. The final determination of the customary adjustments to the purchase price has not yet been made, however, it is not expected to result in a material adjustment. The financial results of this transaction will be reflected in Barnwell’s quarter ending June 30, 2024.
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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 2023 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 2023 Annual Report. There have been no significant changes to these critical accounting policies and estimates during the three and six months ended March 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 and interim periods within fiscal years 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 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
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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.
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) investing in 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. 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. Increment I is an area zoned for approximately 80 single-family lots. During the three months ended March 31, 2024, the last two remaining single-family lots in Increment I were sold.
•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 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
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development of such acreage will 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 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 sales by the real estate sales office and revenues resulting from the sale of private club memberships.
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 March 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.
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. Contract drilling results are highly dependent upon the quantity, dollar value and timing of contracts awarded by governmental and private entities and can fluctuate significantly.
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Results of Operations
Summary
The net loss attributable to Barnwell for the three months ended March 31, 2024 totaled $1,772,000, a $535,000 decrease in operating results from net loss of $1,237,000 for the three months ended March 31, 2023. The following factors affected the results of operations for the three months ended March 31, 2024 as compared to the prior year period:
•A $1,906,000 decrease in oil and natural gas segment operating results, before income taxes, primarily attributable to a $1,677,000 non-cash ceiling test impairment in the current year period primarily due to lower 12-month rolling average first-day-of-the-month prices, whereas there was no such ceiling test impairment in the prior year period;
•A $424,000 decrease in contract drilling segment operating results, before income taxes, due to an increase in estimated costs resulting from labor cost increases and operational issues encountered on a job;
•Equity in income from affiliates increased $1,071,000 and land investment segment operating results, before non-controlling interests’ share of such profits, increased $500,000 due to the Kukio Resort Land Development Partnerships' sale of two lots in the current year period, whereas there were no lots sold in the prior year period; and
•General and administrative expenses decreased $669,000 primarily due to decreases in stockholders costs and professional fees in the current year period as compared to the same period in the prior year.
The net loss attributable to Barnwell for the six months ended March 31, 2024 totaled $2,436,000, a $2,288,000 decrease in operating results from a net loss of $148,000 for the six months ended March 31, 2023. The following factors affected the results of operations for the six months ended March 31, 2024 as compared to the prior year period:
•A $3,011,000 decrease in oil and natural gas segment operating results, before income taxes, primarily attributable to a $1,677,000 non-cash ceiling test impairment in the current year period and an increase in oil and natural gas depletion in the current year period as compared to the same period in the prior year;
•A $700,000 decrease in contract drilling segment operating results, before income taxes, due to an increase in estimated costs resulting from labor cost increases and operational issues encountered on jobs;
•Equity in income from affiliates increased $533,000 and land investment segment operating results, before non-controlling interests’ share of such profits, increased $235,000 due to the Kukio Resort Land Development Partnerships' sale of two lots in the current year period, whereas there was one lot sold in the prior year period;
•General and administrative expenses decreased $1,514,000 primarily due to decreases in stockholders costs and professional fees in the current period as compared to the same period in the prior year; and
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•A $551,000 gain recognized in the prior year period from the sale of a contract drilling segment drilling rig, whereas there was no such gain the current 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 remained unchanged in the three and six months ended March 31, 2024, respectively, as compared to the same periods in the prior year. The exchange rate of the Canadian dollar to the U.S. dollar also remained unchanged at March 31, 2024, as compared to September 30, 2023. 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 loss due to foreign currency translation adjustments, net of taxes, for the three months ended March 31, 2024 was $22,000, a $22,000 change from other comprehensive loss due to foreign currency translation adjustments, net of taxes, of nil for the same period in the prior year. Other comprehensive income due to foreign currency translation adjustments, net of taxes, for the six months ended March 31, 2024 was $8,000, a $6,000 change from other comprehensive income due to foreign currency translation adjustments, net of taxes, of $2,000 for the same period in the prior year. There were no taxes on other comprehensive income (loss) due to foreign currency translation adjustments in the three and six months ended March 31, 2024 and 2023 due to a full valuation allowance on the related deferred tax asset.
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
| March 31, |  | (Decrease)
| 2024 |  | 2023 |  | $ |  | %
Natural Gas (Mcf)* | $ | 1.91 |  |  | $ | 2.61 |  |  | $ | (0.70) |  |  | (27 | %)
Oil (Bbls)** | $ | 60.62 |  |  | $ | 64.61 |  |  | $ | (3.99) |  |  | (6 | %)
Natural gas liquids (Bbls)** | $ | 30.06 |  |  | $ | 35.13 |  |  | $ | (5.07) |  |  | (14 | %)

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| Average Price Per Unit
| Six months ended |  | Increase
| March 31, |  | (Decrease)
| 2024 |  | 2023 |  | $ |  | %
Natural Gas (Mcf)* | $ | 1.87 |  |  | $ | 3.54 |  |  | $ | (1.67) |  |  | (47 | %)
Oil (Bbls)** | $ | 64.09 |  |  | $ | 68.68 |  |  | $ | (4.59) |  |  | (7 | %)
Natural gas liquids (Bbls)** | $ | 29.60 |  |  | $ | 40.09 |  |  | $ | (10.49) |  |  | (26 | %)

| Net Production
| Three months ended |  | Increase
| March 31, |  | (Decrease)
| 2024 |  | 2023 |  | Units |  | %
Natural Gas (Mcf)* | 334,000 |  |  | 227,000 |  |  | 107,000 |  |  | 47 | %
Oil (Bbls)** | 50,000 |  |  | 43,000 |  |  | 7,000 |  |  | 16 | %
Natural gas liquids (Bbls)** | 16,000 |  |  | 8,000 |  |  | 8,000 |  |  | 100 | %

| Net Production
| Six months ended |  | Increase
| March 31, |  | (Decrease)
| 2024 |  | 2023 |  | Units |  | %
Natural Gas (Mcf)* | 713,000 |  |  | 527,000 |  |  | 186,000 |  |  | 35 | %
Oil (Bbls)** | 108,000 |  |  | 91,000 |  |  | 17,000 |  |  | 19 | %
Natural gas liquids (Bbls)** | 34,000 |  |  | 18,000 |  |  | 16,000 |  |  | 89 | %

_______________________________________
* 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 a $1,205,000 operating loss before general and administrative expenses in the three months ended March 31, 2024, a decrease in operating results of $1,906,000 as compared to the $701,000 operating profit before general and administrative expenses generated during the same period of the prior year. The oil and natural gas segment generated a $324,000 operating loss before general and administrative expenses in the six months ended March 31, 2024, a decrease in operating results of $3,011,000 as compared to the $2,687,000 operating profit before general and administrative expenses generated during the same period of the prior year. The operating losses for the three and six months ended March 31, 2024 were due to a non-cash ceiling test impairment of $1,677,000. There was no ceiling test impairment during the three and six months ended March 31, 2023. The decrease in operating results for both the three and six month periods of the current year were also due to an increase in depletion expense, as further discussed below.
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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 March 31, |  | Six months ended March 31,
| 2024 |  | 2023 |  | 2024 |  | 2023
Operating profit (loss) (before general and administrative expenses) |  |  |  |  |  |  |
Canada (1) | $ | (1,511,000) |  |  | $ | 489,000 |  |  | $ | (975,000) |  |  | $ | 2,088,000 |
United States | 306,000 |  |  | 212,000 |  |  | 651,000 |  |  | 599,000 |
Total operating (loss) profit | $ | (1,205,000) |  |  | $ | 701,000 |  |  | $ | (324,000) |  |  | $ | 2,687,000 |

________________________
(1) The operating losses for Canada for the three and six months ended March 31, 2024 include a non-cash ceiling test impairment of $1,677,000.
Oil and natural gas revenues increased $458,000 (12%) and $362,000 (4%) for the three and six months ended March 31, 2024, respectively, as compared to the same periods in the prior year. The increases were primarily due to increases in natural gas, oil, and natural gas liquid production from wells drilled in 2023 in the Twining area and from wells in Texas, partially offset by decreases in the prices of all the commodities in the current year periods as compared to the same periods in the prior year.
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 will sell during the period from April 1, 2024 to October 31, 2024 to a fixed index price of $2.55 Canadian dollars per Mcf, with remaining volumes continuing to be sold at spot prices. This per day volume of natural gas under fixed index price contract is equivalent to approximately 34% of what Canadian natural gas gross production per day was for the three months ended March 31, 2024. Additionally, the Company also amended the sales price on 225 gross barrels per day of the Canadian oil for sale for the period from January 1, 2024 to June 30, 2024 to a fixed index price of $69.46 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 is equivalent to approximately 37% of what Canadian oil gross production per day was for the three months ended March 31, 2024. These natural gas and oil contracts were eligible for and elected as normal purchase and normal sales exception contracts and were thus excluded from derivative accounting.
Oil and natural gas operating expenses increased $63,000 (3%) and $410,000 (9%) for the three and six months ended March 31, 2024, respectively, as compared to the same periods in the prior year, primarily due to costs associated with new production from wells in the Twining area and from wells in Texas.
Oil and natural gas segment depletion increased $624,000 (87%) and $1,286,000 (85%) for the three and six months ended March 31, 2024, respectively, as compared to the same periods in the prior year. The increases were primarily due to increases in the depletion rate for Canadian properties and also increased production from those properties, both of which were the result of the wells drilled in 2023 and facilities expansion and upgrade costs, all in the Twining area. The increases were also due to depletion attributable to production in Texas, whereas there was no such depletion in the prior year periods.
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Sale of Interest in Leasehold Land
Kaupulehu Developments was entitled to receive a percentage of the gross receipts from the sales of lots and/or residential units in Increment I by KD I.
The following table summarizes the revenues received from KD I and the amount of fees directly related to such revenues:

| Three months ended March 31, |  | Six months ended March 31,
| 2024 |  | 2023 |  | 2024 |  | 2023
Sale of interest in leasehold land: |  |  |  |  |  |  |
Revenues - sale of interest in leasehold land | $ | 500,000 |  |  | $ | — |  |  | $ | 500,000 |  |  | $ | 265,000 |
Fees - included in general and administrative expenses | (61,000) |  |  | — |  |  | (61,000) |  |  | (32,000) |
Sale of interest in leasehold land, net of fees paid | $ | 439,000 |  |  | $ | — |  |  | $ | 439,000 |  |  | $ | 233,000 |

During the three and six months ended March 31, 2024, Barnwell received $500,000 in percentage of sales payments from KD I from the sale of the last two single-family lots within Increment I.
No lots were sold during the three months ended March 31, 2023. During the six months ended March 31, 2023, Barnwell received $265,000 in percentage of sales payments from KD I from the sale of one single-family lot within Increment I.
There is an Increment II owned by KD II in which the Company has a 10.8% indirect non-controlling ownership interest. There is no assurance with regards to the amounts of future sales from Increment II 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.
Contract Drilling
Contract drilling revenues and contract drilling costs decreased $431,000 (29%) and $14,000 (1%), respectively, for the three months ended March 31, 2024, as compared to the same period in the prior year. The contract drilling segment generated a $367,000 operating loss before general and administrative expenses in the three months ended March 31, 2024, a decrease in operating results of $424,000 as compared to the $57,000 operating profit generated during the same period of the prior year. Contract drilling revenues and contract drilling costs decreased $1,386,000 (40%) and $702,000 (22%), respectively, for the six months ended March 31, 2024, as compared to the same period in the prior year. The contract drilling segment generated a $595,000 operating loss before general and administrative expenses in the six months ended March 31, 2024, a decrease in operating results of $700,000 as compared to the $105,000 operating profit generated during the same period of the prior year.
The decreases in contract drilling revenues and contract drilling costs for the three and six months ended March 31, 2024 as compared to the same periods in the prior year were due to less progress made on jobs due to drilling difficulties and increases in estimated costs to complete as a result of these drilling difficulties, and a decrease in revenues and costs recognized from materials deliveries and installations as compared to the same periods in the prior year. Also, during the quarter ended March 31, 2024, the Company commenced compensation adjustments for contract drilling segment personnel to decrease
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potential attrition of workers and enable the Company to complete its drilling obligations. These factors resulted in contract drilling expenses decreasing less than the decreases in contract drilling revenues.
On December 13, 2023, the Company entered into a stock purchase agreement with a construction company for the sale of Water Resources for gross proceeds of $2,000,000, subject to customary post-closing price adjustments and the purchaser’s completion of due diligence. On December 27, 2023, the stock purchase agreement was terminated by the buyer prior to closing.
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 to any other interested parties. If no sale of its stock or assets along with contract backlog can be secured, Water Resources will be wound down after all contracts in backlog are completed and any remaining drilling rigs and equipment will be liquidated. Management estimates that contracts in backlog will be completed in December 2024 or soon thereafter.
In January 2024, a significant well drilling contract, which previously had an estimated contract drilling revenue backlog of $2,400,000 and which had not yet started, was cancelled by mutual agreement of Water Resources and the counterparty.
General and Administrative Expenses
General and administrative expenses decreased $669,000 (33%) for the three months ended March 31, 2024 as compared to the same period in the prior year. The decrease was due to decreases of $153,000 in professional fees and $535,000 in stockholders costs primarily attributed to the cooperation and support agreement and associated fees to certain directors in the prior year period as compared to the same period in the current year.
General and administrative expenses decreased $1,514,000 (35%) for the six months ended March 31, 2024 as compared to the same period in the prior year. The decrease was due to decreases of $80,000 in share-based compensation, $847,000 in professional fees primarily related to legal and consulting services, and $545,000 in stockholders costs primarily attributed to the cooperation and support agreement and associated fees to certain directors in the prior year period as compared to the same period in the current year.
Depletion, Depreciation, and Amortization
Depletion, depreciation, and amortization increased $631,000 (83%) and $1,302,000 (81%) for the three and six months ended March 31, 2024, respectively, as compared to the same periods in the prior year, primarily due to increases in the depletion rate for Canadian properties and also new production from those properties and due to depletion attributable to production in Texas 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. During the three and six months ended March 31, 2024, the Company incurred a non-cash ceiling test impairment for our Canadian oil and natural gas propertries of $1,677,000. There was no ceiling test impairment during the three and six months ended March 31, 2023.
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Changes in the 12-month rolling average first-day-of-the-month prices for oil, natural gas and natural gas liquids prices, 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. If oil and natural gas prices decline sufficiently from the 12-month historical rolling average first-day-of-the-month prices used in the ceiling test at March 31, 2024, it is more likely than not that the Company will incur further impairment write-downs in future periods in the absence of any offsetting factors that are not currently known or projected.
Foreign Currency Loss (Gain)
Foreign currency loss was $128,000 and $2,000 during the three and six months ended March 31, 2024, respectively, as compared to foreign currency gain of $2,000 and $80,000 during the three and six months ended March 31, 2023, respectively, due to the effects of foreign exchange rate changes on intercompany loans and advances as a result of changes in the U.S. dollar against the Canadian dollar. The foreign currency loss (gain) from intercompany balances are included in our condensed consolidated net earnings as the intercompany balances were not considered long-term in nature because management estimates that these intercompany balances will be settled in the future.
Gain on Sale of Assets
In October 2022, the Company completed the sale of a contract drilling segment drilling rig to an independent third party for proceeds of $551,000, net of related costs. The drilling rig was fully depreciated and had a net book value of zero and as a result of the sale, the Company recognized a $551,000 gain during the six months ended March 31, 2023.
Equity in Income of Affiliates
Equity in income of affiliates was $1,071,000 during the three and six months ended March 31, 2024, as compared to equity in income of affiliates of nil and $538,000 during the three and six months ended March 31, 2023, respectively. The increase in partnership income is primarily due to the Kukio Resort Land Development Partnerships' sale of the last two lots in Increment I during the current year period, as compared to one lot sale in the prior year period.
During the six months ended March 31, 2024, Barnwell received cash distributions of $1,071,000 from the Kukio Resort Land Development Partnerships resulting in a net amount of $953,000, after distributing $118,000 to non-controlling interests. During the six months ended March 31, 2023, Barnwell received cash distributions of $538,000 from the Kukio Resort Land Development Partnerships resulting in a net amount of $478,000 after distributing $60,000 to non-controlling interests.
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 Partnerships 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 Partnerships’ cumulative earnings in excess of distributions during the
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suspended period exceeds our share of the Kukio Resort Land Development Partnerships’ income recognized for the excess distributions, and during this suspended period any distributions received will be recorded as equity in income of affiliates. Accordingly, the amount of equity in income of affiliates recognized in the six months ended March 31, 2024 was equivalent to the $1,071,000 of distributions received in that period.
Cumulative distributions received from the Kukio Resort Land Development Partnerships in excess of our investment balance was $225,000 at March 31, 2024 and $708,000 at September 30, 2023.
Income Taxes
Barnwell’s effective consolidated income tax rate, after adjusting loss before income taxes for non-controlling interests, was (6)% and (7)% for the three and six months ended March 31, 2024, respectively, as compared to nil and (106)% for the three and six months ended March 31, 2023, respectively.
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.
Net Earnings Attributable to Non-controlling Interests
Earnings and losses attributable to non-controlling interests represent the non-controlling interests’ share of revenues and expenses related to the various partnerships and joint ventures in which Barnwell has controlling interests and consolidates.
Net earnings attributable to non-controlling interests totaled $222,000 and $224,000 for the three and six months ended March 31, 2024, respectively, as compared to net earnings attributable to non-controlling interests of $2,000 and $122,000 for the same periods in the prior year. The changes of $220,000 (11,000%) and $102,000 (84%) for the three and six months, respectively, are primarily due to increases in the amount of equity in income of affiliates and percentage of sales revenues received in the current year periods as compared to the same periods in the prior year.
Liquidity and Capital Resources
At March 31, 2024, Barnwell had $3,332,000 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 minimal, if any, cash flow is expected from our land investment segment.
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The Company has generated a significant amount of cash inflows from its land investment segment, however, the last lots at Increment I were sold during the quarter ended March 31, 2024 and 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 will 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. While management estimates that it is more likely than not that there is sufficient cash on hand, 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, the aforementioned factors will influence the Company’s liquidity beyond that twelve month period.
Cash Flows
Cash flows provided by operations totaled $2,262,000 for the six months ended March 31, 2024, as compared to cash flows provided by operations of $734,000 for the same period in the prior year. This $1,528,000 change in operating cash flows was due to an increase in distributions of income from the Kukio Resort Land Development Partnerships and a decrease in general and administrative costs in the current year period as compared to the prior year period, partially offset by lower operating results for the contract drilling segment in the current year period as compared to the same period in the prior year.
Cash flows used in investing activities totaled $1,186,000 during the six months ended March 31, 2024, as compared to cash flows used in investing activities of $7,370,000 during the same period of the prior year. This $6,184,000 change in investing cash flows was primarily due to a decrease of $6,163,000 in cash paid for investments in oil and natural gas properties in the current year period as compared to the same period in the prior year.
Cash flows used in financing activities totaled $223,000 for the six months ended March 31, 2024, as compared to cash flows used in financing activities of $423,000 for the six months ended March 31, 2023. The $200,000 change in financing cash flows was due to a decrease of $299,000 in payment of dividends, partially offset by an increase of $99,000 in distributions to non-controlling interests in the current year period as compared to the same period in the prior year.
Cash Dividends
No dividends were declared or paid during the six months ended March 31, 2024.
In December 2022, the Company's Board of Directors declared a cash dividend of $0.015 per share that was paid on January 11, 2023 to stockholders of record on December 27, 2022.
In February 2023, the Company's Board of Directors declared a cash dividend of $0.015 per share that was paid on March 13, 2023 to stockholders of record on February 23, 2023.
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Oil and Natural Gas Capital Expenditures
Barnwell’s oil and natural gas capital expenditures, including accrued capital expenditures and excluding acquisitions and additions and revisions to estimated asset retirement obligations, totaled $560,000 and $1,055,000 for the three and six months ended March 31, 2024, respectively, as compared to $1,752,000 and $7,680,000 for the same periods in the prior year.
The oil and natural gas capital expenditures for the six months ended March 31, 2024 were primarily for completion, improvement and equipping costs in the Twining area of Alberta, Canada.
In December 2022, Barnwell Texas, LLC (“Barnwell Texas”), a new wholly-owned subsidiary of the Company, entered into a purchase and sale agreement with an independent third party whereby Barnwell Texas acquired a 22.3% non-operated working interest in oil and natural gas leasehold acreage in the Permian Basin in Texas for cash consideration of $806,000. Additionally, in connection with the purchase of such leasehold interests, Barnwell Texas acquired a 15.4% non-operated working interest in two oil wells in the Wolfcamp Formation in Loving and Ward Counties, Texas and had paid $4,293,000 for its share of the costs to drill, complete, and equip the wells in the six months ended March 31, 2024.
In the quarter ended March 31, 2023, the Company participated in the drilling of three gross (0.9 net) non-operated wells in the Twining area of Alberta, Canada. Capital expenditures incurred for the drilling of these wells and Twining facilities in the six months ended March 31, 2023 totaled approximately $2,236,000.
Barnwell estimates that investments in oil and natural gas properties for fiscal 2024 will range from $4,000,000 to $6,000,000. 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.
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 March 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 March 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 March 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 6. EXHIBITS

Exhibit Number |  | Description
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)

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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: | May 14, 2024 | /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
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)

42