UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
☒ Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
For the quarterly period ended December 31, 2020June 30, 2021
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 2900, 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"emerging growth company”company" in Rule 12b-2 of the Exchange Act.
| | | | | | | | | | | | | | | | | |
| Large accelerated filer | ☐ | | Accelerated filer | ☐ |
| Non-accelerated filer | ☒ | | Smaller reporting company | ☒ |
| | | | Emerging growth company | ☐ |
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). ☐ Yes ☒ No
As of February 8,August 6, 2021 there were 8,277,1609,445,147 shares of common stock, par value $0.50, outstanding.
BARNWELL INDUSTRIES, INC.
AND SUBSIDIARIES
INDEX
PART I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
| | | December 31, 2020 | | September 30, 2020 | | June 30,
2021 | | September 30,
2020 |
| ASSETS | ASSETS | | | | ASSETS | | | |
| Current assets: | Current assets: | | Current assets: | |
| Cash and cash equivalents | Cash and cash equivalents | $ | 5,334,000 | | | $ | 4,584,000 | | Cash and cash equivalents | $ | 9,500,000 | | | $ | 4,584,000 | |
| Accounts and other receivables, net of allowance for doubtful accounts of: $362,000 at December 31, 2020; $341,000 at September 30, 2020 | 2,034,000 | | | 2,176,000 | | |
Accounts and other receivables, net of allowance for doubtful accounts of: $398,000 at June 30, 2021; $341,000 at September 30, 2020 | | Accounts and other receivables, net of allowance for doubtful accounts of: $398,000 at June 30, 2021; $341,000 at September 30, 2020 | 1,988,000 | | | 2,176,000 | |
| Income taxes receivable | Income taxes receivable | 448,000 | | | 472,000 | | Income taxes receivable | 59,000 | | | 472,000 | |
| Asset held for sale | Asset held for sale | 699,000 | | | 699,000 | | Asset held for sale | 699,000 | | | 699,000 | |
| Deferred offering costs | | Deferred offering costs | 294,000 | | | 0 | |
| Other current assets | Other current assets | 1,464,000 | | | 1,556,000 | | Other current assets | 2,305,000 | | | 1,556,000 | |
| Total current assets | Total current assets | 9,979,000 | | | 9,487,000 | | Total current assets | 14,845,000 | | | 9,487,000 | |
| | Asset for retirement benefits | Asset for retirement benefits | 843,000 | | | 771,000 | | Asset for retirement benefits | 987,000 | | | 771,000 | |
| Investments | Investments | 88,000 | | | 901,000 | | Investments | 0 | | | 901,000 | |
| Operating lease right-of-use assets | Operating lease right-of-use assets | 227,000 | | | 249,000 | | Operating lease right-of-use assets | 173,000 | | | 249,000 | |
| Property and equipment | Property and equipment | 76,217,000 | | | 73,431,000 | | Property and equipment | 79,412,000 | | | 73,431,000 | |
| Accumulated depletion, depreciation, and amortization | (73,313,000) | | | (69,657,000) | | |
| Accumulated depletion, impairment, depreciation, and amortization | | Accumulated depletion, impairment, depreciation, and amortization | (75,595,000) | | | (69,657,000) | |
| Property and equipment, net | Property and equipment, net | 2,904,000 | | | 3,774,000 | | Property and equipment, net | 3,817,000 | | | 3,774,000 | |
| Total assets | Total assets | $ | 14,041,000 | | | $ | 15,182,000 | | Total assets | $ | 19,822,000 | | | $ | 15,182,000 | |
| | LIABILITIES AND EQUITY | LIABILITIES AND EQUITY | | LIABILITIES AND EQUITY | |
| Current liabilities: | Current liabilities: | | Current liabilities: | |
| Accounts payable | Accounts payable | $ | 1,257,000 | | | $ | 2,104,000 | | Accounts payable | $ | 2,451,000 | | | $ | 2,104,000 | |
| Accrued capital expenditures | Accrued capital expenditures | 336,000 | | | 542,000 | | Accrued capital expenditures | 562,000 | | | 542,000 | |
| Accrued compensation | Accrued compensation | 390,000 | | | 408,000 | | Accrued compensation | 904,000 | | | 408,000 | |
| Accrued operating and other expenses | Accrued operating and other expenses | 1,032,000 | | | 1,325,000 | | Accrued operating and other expenses | 1,333,000 | | | 1,325,000 | |
| | Current portion of operating lease liabilities | Current portion of operating lease liabilities | 116,000 | | | 111,000 | | Current portion of operating lease liabilities | 80,000 | | | 111,000 | |
| Current portion of asset retirement obligation | Current portion of asset retirement obligation | 605,000 | | | 647,000 | | Current portion of asset retirement obligation | 965,000 | | | 647,000 | |
| | Other current liabilities | Other current liabilities | 873,000 | | | 1,227,000 | | Other current liabilities | 215,000 | | | 1,227,000 | |
| Total current liabilities | Total current liabilities | 4,609,000 | | | 6,364,000 | | Total current liabilities | 6,510,000 | | | 6,364,000 | |
| | Long-term debt | Long-term debt | 98,000 | | | 58,000 | | Long-term debt | 48,000 | | | 58,000 | |
| Operating lease liabilities | Operating lease liabilities | 115,000 | | | 143,000 | | Operating lease liabilities | 96,000 | | | 143,000 | |
| | Liability for retirement benefits | Liability for retirement benefits | 4,858,000 | | | 4,829,000 | | Liability for retirement benefits | 2,038,000 | | | 4,829,000 | |
| Asset retirement obligation | Asset retirement obligation | 5,787,000 | | | 5,547,000 | | Asset retirement obligation | 5,966,000 | | | 5,547,000 | |
| Deferred income tax liabilities | Deferred income tax liabilities | 233,000 | | | 194,000 | | Deferred income tax liabilities | 359,000 | | | 194,000 | |
| Total liabilities | Total liabilities | 15,700,000 | | | 17,135,000 | | Total liabilities | 15,017,000 | | | 17,135,000 | |
| Commitments and contingencies | Commitments and contingencies | 0 | | 0 | Commitments and contingencies | 0 | | 0 |
| Equity: | Equity: | | Equity: | |
Common stock, par value $0.50 per share; authorized, 20,000,000 shares: 8,445,060 issued at December 31, 2020 and September 30, 2020 | 4,223,000 | | | 4,223,000 | | |
Common stock, par value $0.50 per share; authorized, 20,000,000 shares: 9,031,606 issued at June 30, 2021; 8,445,060 issued at September 30, 2020 | | Common stock, par value $0.50 per share; authorized, 20,000,000 shares: 9,031,606 issued at June 30, 2021; 8,445,060 issued at September 30, 2020 | 4,516,000 | | | 4,223,000 | |
| Additional paid-in capital | Additional paid-in capital | 1,350,000 | | | 1,350,000 | | Additional paid-in capital | 3,023,000 | | | 1,350,000 | |
| Accumulated deficit | (3,313,000) | | | (3,897,000) | | |
| Retained earnings (accumulated deficit) | | Retained earnings (accumulated deficit) | 809,000 | | | (3,897,000) | |
| Accumulated other comprehensive loss, net | Accumulated other comprehensive loss, net | (1,636,000) | | | (1,435,000) | | Accumulated other comprehensive loss, net | (1,195,000) | | | (1,435,000) | |
| Treasury stock, at cost: 167,900 shares at December 31, 2020 and September 30, 2020 | (2,286,000) | | | (2,286,000) | | |
| Total stockholders' deficit | (1,662,000) | | | (2,045,000) | | |
| Treasury stock, at cost: 167,900 shares at June 30, 2021 and September 30, 2020 | | Treasury stock, at cost: 167,900 shares at June 30, 2021 and September 30, 2020 | (2,286,000) | | | (2,286,000) | |
| Total stockholders’ equity (deficit) | | Total stockholders’ equity (deficit) | 4,867,000 | | | (2,045,000) | |
| Non-controlling interests | Non-controlling interests | 3,000 | | | 92,000 | | Non-controlling interests | (62,000) | | | 92,000 | |
| Total deficit | (1,659,000) | | | (1,953,000) | | |
| Total equity (deficit) | | Total equity (deficit) | 4,805,000 | | | (1,953,000) | |
| Total liabilities and equity | Total liabilities and equity | $ | 14,041,000 | | | $ | 15,182,000 | | Total liabilities and equity | $ | 19,822,000 | | | $ | 15,182,000 | |
See Notes to Condensed Consolidated Financial Statements
BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)
| | | Three months ended
December 31, | | Three months ended
June 30, | | Nine months ended
June 30, |
| | | 2020 | | 2019 | | 2021 | | 2020 | | 2021 | | 2020 |
| Revenues: | Revenues: | | | | Revenues: | | | | | | | |
| Oil and natural gas | Oil and natural gas | $ | 1,887,000 | | | $ | 2,141,000 | | Oil and natural gas | $ | 2,887,000 | | | $ | 830,000 | | | $ | 7,326,000 | | | $ | 4,881,000 | |
| Contract drilling | Contract drilling | 1,942,000 | | | 2,646,000 | | Contract drilling | 889,000 | | | 3,040,000 | | | 4,220,000 | | | 8,279,000 | |
| Sale of interest in leasehold land | Sale of interest in leasehold land | 485,000 | | | 0 | | Sale of interest in leasehold land | 1,253,000 | | | 0 | | | 1,738,000 | | | 0 | |
| Gas processing and other | Gas processing and other | 73,000 | | | 63,000 | | Gas processing and other | 85,000 | | | 114,000 | | | 215,000 | | | 256,000 | |
| | | 4,387,000 | | | 4,850,000 | | | 5,114,000 | | | 3,984,000 | | | 13,499,000 | | | 13,416,000 | |
| Costs and expenses: | Costs and expenses: | | | | Costs and expenses: | | | | | | | |
| Oil and natural gas operating | Oil and natural gas operating | 1,435,000 | | | 1,213,000 | | Oil and natural gas operating | 1,717,000 | | | 981,000 | | | 4,911,000 | | | 3,479,000 | |
| Contract drilling operating | Contract drilling operating | 1,108,000 | | | 1,814,000 | | Contract drilling operating | 1,026,000 | | | 1,967,000 | | | 3,599,000 | | | 5,552,000 | |
| General and administrative | General and administrative | 1,185,000 | | | 1,496,000 | | General and administrative | 2,227,000 | | | 1,248,000 | | | 5,340,000 | | | 4,775,000 | |
| Depletion, depreciation, and amortization | Depletion, depreciation, and amortization | 276,000 | | | 705,000 | | Depletion, depreciation, and amortization | 235,000 | | | 478,000 | | | 738,000 | | | 1,870,000 | |
| Impairment of assets | Impairment of assets | 630,000 | | | 0 | | Impairment of assets | 0 | | | 2,689,000 | | | 630,000 | | | 4,326,000 | |
| Interest expense | Interest expense | 1,000 | | | 0 | | Interest expense | 2,000 | | | 1,000 | | | 6,000 | | | 1,000 | |
| Gain on debt extinguishment | | Gain on debt extinguishment | (149,000) | | | 0 | | | (149,000) | | | 0 | |
| Gain on termination of post-retirement medical plan | | Gain on termination of post-retirement medical plan | (2,341,000) | | | 0 | | | (2,341,000) | | | 0 | |
| Gain on sale of asset | | Gain on sale of asset | 0 | | | 0 | | | 0 | | | (1,336,000) | |
| | | 4,635,000 | | | 5,228,000 | | | 2,717,000 | | | 7,364,000 | | | 12,734,000 | | | 18,667,000 | |
| Loss before equity in income (loss) of affiliates and income taxes | (248,000) | | | (378,000) | | |
| Earnings (loss) before equity in income (loss) of affiliates and income taxes | | Earnings (loss) before equity in income (loss) of affiliates and income taxes | 2,397,000 | | | (3,380,000) | | | 765,000 | | | (5,251,000) | |
| Equity in income (loss) of affiliates | Equity in income (loss) of affiliates | 1,054,000 | | | (43,000) | | Equity in income (loss) of affiliates | 3,348,000 | | | (111,000) | | | 5,026,000 | | | (179,000) | |
| Earnings (loss) before income taxes | Earnings (loss) before income taxes | 806,000 | | | (421,000) | | Earnings (loss) before income taxes | 5,745,000 | | | (3,491,000) | | | 5,791,000 | | | (5,430,000) | |
| Income tax provision (benefit) | Income tax provision (benefit) | 63,000 | | | (2,000) | | Income tax provision (benefit) | 191,000 | | | (24,000) | | | 288,000 | | | (26,000) | |
| Net earnings (loss) | Net earnings (loss) | 743,000 | | | (419,000) | | Net earnings (loss) | 5,554,000 | | | (3,467,000) | | | 5,503,000 | | | (5,404,000) | |
| Less: Net earnings (loss) attributable to non-controlling interests | Less: Net earnings (loss) attributable to non-controlling interests | 159,000 | | | (5,000) | | Less: Net earnings (loss) attributable to non-controlling interests | 576,000 | | | (11,000) | | | 797,000 | | | (20,000) | |
| Net earnings (loss) attributable to Barnwell Industries, Inc. | Net earnings (loss) attributable to Barnwell Industries, Inc. | $ | 584,000 | | | $ | (414,000) | | Net earnings (loss) attributable to Barnwell Industries, Inc. | $ | 4,978,000 | | | $ | (3,456,000) | | | $ | 4,706,000 | | | $ | (5,384,000) | |
| Basic and diluted net earnings (loss) per common share attributable to Barnwell Industries, Inc. stockholders | Basic and diluted net earnings (loss) per common share attributable to Barnwell Industries, Inc. stockholders | $ | 0.07 | | | $ | (0.05) | | Basic and diluted net earnings (loss) per common share attributable to Barnwell Industries, Inc. stockholders | $ | 0.59 | | | $ | (0.42) | | | $ | 0.57 | | | $ | (0.65) | |
| Weighted-average number of common shares outstanding: | Weighted-average number of common shares outstanding: | | | | Weighted-average number of common shares outstanding: | | | | | | | |
| Basic and diluted | Basic and diluted | 8,277,160 | | | 8,277,160 | | Basic and diluted | 8,398,001 | | | 8,277,160 | | | 8,317,440 | | | 8,277,160 | |
See Notes to Condensed Consolidated Financial Statements
BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Unaudited)
| | | Three months ended
December 31, | | Three months ended
June 30, | | Nine months ended
June 30, |
| | | 2020 | | 2019 | | 2021 | | 2020 | | 2021 | | 2020 |
| Net earnings (loss) | Net earnings (loss) | $ | 743,000 | | | $ | (419,000) | | Net earnings (loss) | $ | 5,554,000 | | | $ | (3,467,000) | | | $ | 5,503,000 | | | $ | (5,404,000) | |
| Other comprehensive (loss) income: | | | | |
| Other comprehensive income (loss): | | Other comprehensive income (loss): | | | | | | | |
| Foreign currency translation adjustments, net of taxes of $0 | Foreign currency translation adjustments, net of taxes of $0 | (234,000) | | | 5,000 | | Foreign currency translation adjustments, net of taxes of $0 | (74,000) | | | (125,000) | | | (393,000) | | | (36,000) | |
| Retirement plans: | Retirement plans: | | Retirement plans: | |
| Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | 33,000 | | | 60,000 | | Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | 26,000 | | | 20,000 | | | 92,000 | | | 100,000 | |
| Net actuarial gains arising during the period, net of taxes of $0 | Net actuarial gains arising during the period, net of taxes of $0 | 0 | | | 880,000 | | Net actuarial gains arising during the period, net of taxes of $0 | 0 | | | 0 | | | 0 | | | 880,000 | |
| Curtailment gain, net of taxes of $0 | Curtailment gain, net of taxes of $0 | 0 | | | 1,699,000 | | Curtailment gain, net of taxes of $0 | 0 | | | 0 | | | 0 | | | 1,699,000 | |
| Total other comprehensive (loss) income | (201,000) | | | 2,644,000 | | |
| Total comprehensive income | 542,000 | | | 2,225,000 | | |
| Gain on termination of post-retirement medical plan, net of taxes of $0 | | Gain on termination of post-retirement medical plan, net of taxes of $0 | 541,000 | | | 0 | | | 541,000 | | | 0 | |
| Total other comprehensive income (loss) | | Total other comprehensive income (loss) | 493,000 | | | (105,000) | | | 240,000 | | | 2,643,000 | |
| Total comprehensive income (loss) | | Total comprehensive income (loss) | 6,047,000 | | | (3,572,000) | | | 5,743,000 | | | (2,761,000) | |
| Less: Comprehensive (income) loss attributable to non-controlling interests | Less: Comprehensive (income) loss attributable to non-controlling interests | (159,000) | | | 5,000 | | Less: Comprehensive (income) loss attributable to non-controlling interests | (576,000) | | | 11,000 | | | (797,000) | | | 20,000 | |
| Comprehensive income attributable to Barnwell Industries, Inc. | $ | 383,000 | | | $ | 2,230,000 | | |
| Comprehensive income (loss) attributable to Barnwell Industries, Inc. | | Comprehensive income (loss) attributable to Barnwell Industries, Inc. | $ | 5,471,000 | | | $ | (3,561,000) | | | $ | 4,946,000 | | | $ | (2,741,000) | |
See Notes to Condensed Consolidated Financial Statements
BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (DEFICIT)
Three months ended December 31,June 30, 2021 and 2020 and 2019
(Unaudited)
| | | Shares
Outstanding | | Common
Stock | | Additional
Paid-In
Capital | | Retained
Earnings
(Accumulated Deficit) | | Accumulated
Other
Comprehensive
Loss | | Treasury
Stock | | Non-controlling
Interests | | Total
Equity (Deficit) | | Shares
Outstanding | | Common
Stock | | Additional
Paid-In
Capital | | Retained Earnings
(Accumulated Deficit) | | Accumulated
Other
Comprehensive Loss | | Treasury
Stock | | Non-controlling
Interests | | Total
Equity (Deficit) |
| Balance at September 30, 2019 | 8,277,160 | | | $ | 4,223,000 | | | $ | 1,350,000 | | | $ | 859,000 | | | $ | (2,917,000) | | | $ | (2,286,000) | | | $ | 100,000 | | | $ | 1,329,000 | | |
| | Balance at March 31, 2020 | | Balance at March 31, 2020 | 8,277,160 | | | $ | 4,223,000 | | | $ | 1,350,000 | | | $ | (1,069,000) | | | $ | (169,000) | | | $ | (2,286,000) | | | $ | 91,000 | | | $ | 2,140,000 | |
| Net loss | Net loss | — | | | — | | | — | | | (414,000) | | | — | | | — | | | (5,000) | | | (419,000) | | Net loss | — | | | — | | | — | | | (3,456,000) | | | — | | | — | | | (11,000) | | | (3,467,000) | |
| | Foreign currency translation adjustments, net of taxes of $0 | Foreign currency translation adjustments, net of taxes of $0 | — | | | — | | | — | | | — | | | 5,000 | | | — | | | — | | | 5,000 | | Foreign currency translation adjustments, net of taxes of $0 | — | | | — | | | — | | | — | | | (125,000) | | | — | | | — | | | (125,000) | |
| Retirement plans: | Retirement plans: | | Retirement plans: | |
| Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | — | | | — | | | — | | | — | | | 60,000 | | | — | | | — | | | 60,000 | | Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | — | | | — | | | — | | | — | | | 20,000 | | | — | | | — | | | 20,000 | |
| Net actuarial gains arising during the period, net of taxes of $0 | — | | | — | | | — | | | — | | | 880,000 | | | — | | | — | | | 880,000 | | |
| Curtailment gain, net of taxes of $0 | — | | | — | | | — | | | — | | | 1,699,000 | | | — | | | — | | | 1,699,000 | | |
| Balance at December 31, 2019 | 8,277,160 | | | $ | 4,223,000 | | | $ | 1,350,000 | | | $ | 445,000 | | | $ | (273,000) | | | $ | (2,286,000) | | | $ | 95,000 | | | $ | 3,554,000 | | |
| | Balance at September 30, 2020 | 8,277,160 | | | $ | 4,223,000 | | | $ | 1,350,000 | | | $ | (3,897,000) | | | $ | (1,435,000) | | | $ | (2,286,000) | | | $ | 92,000 | | | $ | (1,953,000) | | |
| | Balance at June 30, 2020 | | Balance at June 30, 2020 | 8,277,160 | | | $ | 4,223,000 | | | $ | 1,350,000 | | | $ | (4,525,000) | | | $ | (274,000) | | | $ | (2,286,000) | | | $ | 80,000 | | | $ | (1,432,000) | |
| | Balance at March 31, 2021 | | Balance at March 31, 2021 | 8,277,160 | | | $ | 4,223,000 | | | $ | 1,501,000 | | | $ | (4,169,000) | | | $ | (1,688,000) | | | $ | (2,286,000) | | | $ | 4,000 | | | $ | (2,415,000) | |
| Net earnings | Net earnings | — | | | — | | | — | | | 584,000 | | | — | | | — | | | 159,000 | | | 743,000 | | Net earnings | — | | | — | | | — | | | 4,978,000 | | | — | | | — | | | 576,000 | | | 5,554,000 | |
| Foreign currency translation adjustments, net of taxes of $0 | Foreign currency translation adjustments, net of taxes of $0 | — | | | — | | | — | | | — | | | (234,000) | | | — | | | — | | | (234,000) | | Foreign currency translation adjustments, net of taxes of $0 | — | | | — | | | — | | | — | | | (74,000) | | | — | | | — | | | (74,000) | |
| Distributions to non-controlling interests | Distributions to non-controlling interests | — | | | — | | | — | | | — | | | — | | | — | | | (248,000) | | (248,000) | Distributions to non-controlling interests | — | | | — | | | — | | | — | | | — | | | — | | | (642,000) | | | (642,000) | |
| Share-based compensation | | Share-based compensation | — | | | — | | | 238,000 | | — | | | — | | | — | | | — | | | 238,000 |
| Issuance of common stock, net of costs | | Issuance of common stock, net of costs | 586,546 | | | 293,000 | | | 1,284,000 | | | — | | | — | | | — | | | — | | | 1,577,000 | |
| Retirement plans: | Retirement plans: | | Retirement plans: | |
| Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | — | | | — | | | — | | | — | | | 33,000 | | | — | | | — | | | 33,000 | | Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | — | | | — | | | — | | | — | | | 26,000 | | | — | | | — | | | 26,000 | |
| Balance at December 31, 2020 | 8,277,160 | | | $ | 4,223,000 | | | $ | 1,350,000 | | | $ | (3,313,000) | | | $ | (1,636,000) | | | $ | (2,286,000) | | | $ | 3,000 | | | $ | (1,659,000) | | |
| Gain on termination of post-retirement medical plan, net of taxes of $0 | | Gain on termination of post-retirement medical plan, net of taxes of $0 | — | | | — | | | — | | | — | | | 541,000 | | | — | | | — | | | 541,000 | |
| Balance at June 30, 2021 | | Balance at June 30, 2021 | 8,863,706 | | | $ | 4,516,000 | | | $ | 3,023,000 | | | $ | 809,000 | | | $ | (1,195,000) | | | $ | (2,286,000) | | | $ | (62,000) | | | $ | 4,805,000 | |
See Notes to Condensed Consolidated Financial Statements
BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (DEFICIT)
Nine months ended June 30, 2021 and 2020
(Unaudited)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Shares
Outstanding | | Common
Stock | | Additional
Paid-In
Capital | | Retained Earnings
(Accumulated Deficit) | | Accumulated
Other
Comprehensive Loss | | Treasury
Stock | | Non-controlling
Interests | | Total
Equity (Deficit) |
| Balance at September 30, 2019 | 8,277,160 | | | $ | 4,223,000 | | | $ | 1,350,000 | | | $ | 859,000 | | | $ | (2,917,000) | | | $ | (2,286,000) | | | $ | 100,000 | | | $ | 1,329,000 | |
| Net loss | — | | | — | | | — | | | (5,384,000) | | | — | | | — | | | (20,000) | | | (5,404,000) | |
| | | | | | | | | | | | | | | |
| Foreign currency translation adjustments, net of taxes of $0 | — | | | — | | | — | | | — | | | (36,000) | | | — | | | — | | | (36,000) | |
| Retirement plans: | | | | | | | | | | | | | | | |
| Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | — | | | — | | | — | | | — | | | 100,000 | | | — | | | — | | | 100,000 | |
| Net actuarial gains arising during the period, net of taxes of $0 | — | | | — | | | — | | | — | | | 880,000 | | | — | | | — | | | 880,000 | |
| Curtailment gain, net of taxes of $0 | — | | | — | | | — | | | — | | | 1,699,000 | | | — | | | — | | | 1,699,000 | |
| Balance at June 30, 2020 | 8,277,160 | | | $ | 4,223,000 | | | $ | 1,350,000 | | | $ | (4,525,000) | | | $ | (274,000) | | | $ | (2,286,000) | | | $ | 80,000 | | | $ | (1,432,000) | |
| | | | | | | | | | | | | | | |
| Balance at September 30, 2020 | 8,277,160 | | | $ | 4,223,000 | | | $ | 1,350,000 | | | $ | (3,897,000) | | | $ | (1,435,000) | | | $ | (2,286,000) | | | $ | 92,000 | | | $ | (1,953,000) | |
| Net earnings | — | | | — | | | — | | | 4,706,000 | | | — | | | — | | | 797,000 | | | 5,503,000 | |
| Foreign currency translation adjustments, net of taxes of $0 | — | | | — | | | — | | | — | | | (393,000) | | | — | | | — | | | (393,000) | |
| Distributions to non-controlling interests | — | | | — | | | — | | | — | | | — | | | — | | | (951,000) | | | (951,000) | |
| Share-based compensation | — | | | — | | | 389,000 | | — | | | — | | | — | | | — | | | 389,000 |
| Issuance of common stock, net of costs | 586,546 | | | 293,000 | | | 1,284,000 | | | — | | | — | | | — | | | — | | | 1,577,000 | |
| Retirement plans: | | | | | | | | | | | | | | | |
| Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | — | | | — | | | — | | | — | | | 92,000 | | | — | | | — | | | 92,000 | |
| Gain on termination of post-retirement medical plan, net of taxes of $0 | — | | | — | | | — | | | — | | | 541,000 | | | — | | | — | | | 541,000 | |
| Balance at June 30, 2021 | 8,863,706 | | | $ | 4,516,000 | | | $ | 3,023,000 | | | $ | 809,000 | | | $ | (1,195,000) | | | $ | (2,286,000) | | | $ | (62,000) | | | $ | 4,805,000 | |
See Notes to Condensed Consolidated Financial Statements
BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
| | | Three months ended
December 31, | | Nine months ended
June 30, |
| | | 2020 | | 2019 | | 2021 | | 2020 |
| Cash flows from operating activities: | Cash flows from operating activities: | | | | Cash flows from operating activities: | | | |
| Net earnings (loss) | Net earnings (loss) | $ | 743,000 | | | $ | (419,000) | | Net earnings (loss) | $ | 5,503,000 | | | $ | (5,404,000) | |
| Adjustments to reconcile net earnings (loss) to net cash | Adjustments to reconcile net earnings (loss) to net cash | | Adjustments to reconcile net earnings (loss) to net cash | | | |
| provided by (used in) operating activities: | | |
| provided by operating activities: | | provided by operating activities: | | | |
| Equity in (income) loss of affiliates | Equity in (income) loss of affiliates | (1,054,000) | | | 43,000 | | Equity in (income) loss of affiliates | (5,026,000) | | | 179,000 | |
| Depletion, depreciation, and amortization | Depletion, depreciation, and amortization | 276,000 | | | 705,000 | | Depletion, depreciation, and amortization | 738,000 | | | 1,870,000 | |
| Gain on sale of asset | | Gain on sale of asset | 0 | | | (1,336,000) | |
| Impairment of assets | Impairment of assets | 630,000 | | | 0 | | Impairment of assets | 630,000 | | | 4,326,000 | |
| Sale of interest in leasehold land, net of fees paid | Sale of interest in leasehold land, net of fees paid | (426,000) | | | 0 | | Sale of interest in leasehold land, net of fees paid | (1,526,000) | | | 0 | |
| Distributions of income from equity investees | Distributions of income from equity investees | 1,054,000 | | | 0 | | Distributions of income from equity investees | 4,278,000 | | | 0 | |
| Retirement benefits (income) expense | (8,000) | | | 71,000 | | |
| Accretion of asset retirement obligation | 137,000 | | | 134,000 | | |
| | Retirement benefits income | | Retirement benefits income | (38,000) | | | (18,000) | |
| | Non-cash rent (income) expense | Non-cash rent (income) expense | (1,000) | | | 30,000 | | Non-cash rent (income) expense | (3,000) | | | 48,000 | |
| Accretion of asset retirement obligation | | Accretion of asset retirement obligation | 432,000 | | | 415,000 | |
| Deferred income tax expense (benefit) | Deferred income tax expense (benefit) | 39,000 | | | (9,000) | | Deferred income tax expense (benefit) | 165,000 | | | (7,000) | |
| Asset retirement obligation payments | Asset retirement obligation payments | (38,000) | | | (2,000) | | Asset retirement obligation payments | (316,000) | | | (457,000) | |
| | Share-based compensation expense | | Share-based compensation expense | 389,000 | | | 0 | |
| Retirement plan contributions and payments | Retirement plan contributions and payments | (2,000) | | | (2,000) | | Retirement plan contributions and payments | (5,000) | | | (6,000) | |
| Bad debt expense | Bad debt expense | 7,000 | | | 0 | | Bad debt expense | 33,000 | | | 280,000 | |
| Decrease from changes in current assets and liabilities | (1,277,000) | | | (1,917,000) | | |
| Net cash provided by (used in) operating activities | 80,000 | | | (1,366,000) | | |
| Gain on debt extinguishment | | Gain on debt extinguishment | (149,000) | | | 0 | |
| Gain on termination of post-retirement medical plan | | Gain on termination of post-retirement medical plan | (2,341,000) | | | 0 | |
| (Decrease) increase from changes in current assets and liabilities | | (Decrease) increase from changes in current assets and liabilities | (659,000) | | | 582,000 | |
| Net cash provided by operating activities | | Net cash provided by operating activities | 2,105,000 | | | 472,000 | |
| Cash flows from investing activities: | Cash flows from investing activities: | | | | Cash flows from investing activities: | | | |
| | | Proceeds from sale of interest in leasehold land, net of fees paid | Proceeds from sale of interest in leasehold land, net of fees paid | 426,000 | | | 0 | | Proceeds from sale of interest in leasehold land, net of fees paid | 1,526,000 | | | 0 | |
| | Distribution from equity investees in excess of earnings | Distribution from equity investees in excess of earnings | 813,000 | | | 0 | | Distribution from equity investees in excess of earnings | 1,649,000 | | | 0 | |
| Proceeds from sale of oil and natural gas assets | 0 | | | 594,000 | | |
| | Proceeds from the sale of asset | | Proceeds from the sale of asset | 0 | | | 1,100,000 | |
| Proceeds from the sale of oil and natural gas assets | | Proceeds from the sale of oil and natural gas assets | 60,000 | | | 608,000 | |
| Payments to acquire oil and natural gas properties | | Payments to acquire oil and natural gas properties | (348,000) | | | 0 | |
| Capital expenditures - oil and natural gas | Capital expenditures - oil and natural gas | (364,000) | | | (1,444,000) | | Capital expenditures - oil and natural gas | (904,000) | | | (2,509,000) | |
| Capital expenditures - all other | Capital expenditures - all other | 0 | | | (13,000) | | Capital expenditures - all other | (28,000) | | | (315,000) | |
| | Net cash provided by (used in) investing activities | Net cash provided by (used in) investing activities | 875,000 | | | (863,000) | | Net cash provided by (used in) investing activities | 1,955,000 | | | (1,116,000) | |
| Cash flows from financing activities: | Cash flows from financing activities: | | | | Cash flows from financing activities: | | | |
| | Borrowings on long-term debt | Borrowings on long-term debt | 31,000 | | | 0 | | Borrowings on long-term debt | 47,000 | | | 147,000 | |
| Distributions to non-controlling interests | | Distributions to non-controlling interests | (951,000) | | | 0 | |
| Proceeds from issuance of stock, net of costs | | Proceeds from issuance of stock, net of costs | 1,736,000 | | | 0 | |
| | Distributions to non-controlling interests | (248,000) | | | 0 | | |
| Net cash used in financing activities | (217,000) | | | 0 | | |
| Net cash provided by financing activities | | Net cash provided by financing activities | 832,000 | | | 147,000 | |
| Effect of exchange rate changes on cash and cash equivalents | Effect of exchange rate changes on cash and cash equivalents | 12,000 | | | 15,000 | | Effect of exchange rate changes on cash and cash equivalents | 24,000 | | | (10,000) | |
| Net increase (decrease) in cash and cash equivalents | Net increase (decrease) in cash and cash equivalents | 750,000 | | | (2,214,000) | | Net increase (decrease) in cash and cash equivalents | 4,916,000 | | | (507,000) | |
| Cash and cash equivalents at beginning of period | Cash and cash equivalents at beginning of period | 4,584,000 | | | 4,613,000 | | Cash and cash equivalents at beginning of period | 4,584,000 | | | 4,613,000 | |
| Cash and cash equivalents at end of period | Cash and cash equivalents at end of period | $ | 5,334,000 | | | $ | 2,399,000 | | Cash and cash equivalents at end of period | $ | 9,500,000 | | | $ | 4,106,000 | |
See Notes to Condensed Consolidated Financial Statements
BARNWELL INDUSTRIES, INC.
AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Principles of Consolidation
The condensed consolidated financial statements include the accounts of Barnwell Industries, Inc. and all majority-owned subsidiaries (collectively referred to herein as “Barnwell,” “we,” “our,” “us,” or the “Company”), including a 77.6%-owned land investment general partnership (Kaupulehu Developments) and, a 75%-owned land investment partnership (KD Kona 2013 LLLP)., 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.Commission (“SEC”). 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, 2020 Annual Report on Form 10-K, as amended by our Form 10-K/A Amendment No. 1. The Condensed Consolidated Balance Sheet as of September 30, 2020 has been derived from audited consolidated financial statements.
In the opinion of management, all adjustments (which include only normal recurring adjustments) necessary to present fairly the financial position at December 31, 2020,June 30, 2021, results of operations, comprehensive income (loss), and equity (deficit) for the three and nine months ended June 30, 2021 and 2020, and cash flows for the threenine months ended December 31,June 30, 2021 and 2020, and 2019, have been made. The results of operations for the period ended December 31, 2020June 30, 2021 are not necessarily indicative of the operating results for the full year.
Use of Estimates in the Preparation of Condensed Consolidated Financial Statements
The preparation of the condensed consolidated financial statements in conformity with U.S. GAAP requires management of Barnwell to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Actual results could differ significantly from those estimates. Significant assumptions are required in the
valuation of deferred tax assets, asset retirement obligations, share-based payment arrangements, obligations for retirement plans, 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
ThereOther 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 most recently filed Annual Report on Form 10-K, as amended by our Form 10-K/A Amendment No. 1.
Share-based Compensation
Share-based compensation cost is measured at fair value. Barnwell utilizes a closed-form valuation model to determine the fair value of each option award. Expected volatilities are based on the historical volatility of Barnwell’s stock over a period consistent with that of the expected terms of the options. The expected terms of the options represent expectations of future employee exercise and are estimated based on factors such as vesting periods, contractual expiration dates, historical trends in Barnwell’s stock price, and historical exercise behavior. If the Company does not have sufficient historical data regarding employee exercise behavior, the “simplified method” as permitted by the SEC’s Staff Accounting Bulletin No. 110, Share-Based Payment is utilized to estimate the expected terms of the options. The risk-free rates for periods within the contractual life of the options are based on the yields of U.S. Treasury instruments with terms comparable to the estimated option terms. Expected dividends are based on current and historical dividend payments. The Company's policy is to recognize forfeitures as they occur.
Deferred Offering Costs
The Company will incur certain incremental costs directly associated with its at-the-market offering program (“ATM”) in which the Company can sell, from time to time, shares of its common stock (see Note 15). These costs typically include fees paid to underwriters, attorneys, accountants, and other third parties. The offering costs incurred by the Company are currently capitalized as current assets and are recorded as “Deferred offering costs” on the Company’s Condensed Consolidated Balance Sheet. Deferred costs associated with the ATM offering will be amortized to additional paid-in capital on a pro-rata basis as the Company raises funds under the ATM offering, based on the total estimated proceeds necessary for the ATM offering to be deemed successful with any remaining deferred offering costs charged to the results of operations at the end of the life of the related registration statement.
Variable Interest Entities
The consolidation of a variable interest entity (“VIE”) is required when an enterprise has a controlling financial interest and is therefore the VIE’s primary beneficiary. A controlling financial interest will have both of the following characteristics: (a) the power to direct the activities of a VIE that most significantly impact the VIE’s economic performance and (b) the obligation to absorb losses of the VIE that could potentially be significant to the VIE or the right to receive benefits from the VIE that could potentially be significant to the VIE. The determination of whether an entity is a VIE and, if so, whether the Company is the primary beneficiary, may require significant judgment.
Barnwell analyzes its entities in which it has a variable interest to determine whether the entities are VIEs and, if so, whether the Company is the primary beneficiary. This analysis includes a qualitative review based on an evaluation of the design of the entity, its organizational structure, including decision making ability and financial agreements, as well as a quantitative review. Entities that have been determined to be VIEs and for which we have a controlling financial interest and are therefore the VIE’s primary beneficiary are consolidated (see Note 5). Entities that have been determined to be VIEs and for which we do not have a controlling financial interest and are therefore not the VIE’s primary beneficiary are not consolidated. These unconsolidated entities are accounted for under the equity method (see Note 4).
Recently Adopted Accounting Pronouncements
In August 2018, the Financial Accounting Standards Board (“FASB”) issued ASU No. 2018-13, “Fair Value Measurement: Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement,” which provides changes to certain fair value disclosure requirements. The Company adopted the provisions of this Accounting Standards Update (“ASU”) effective October 1, 2020. The adoption of this update did not have an impact on Barnwell's consolidated financial statements.
In October 2018, the FASB issued ASU No. 2018-17, “Consolidation: Targeted Improvements to Related Party Guidance for Variable Interest Entities,” which modifies the guidance related to indirect interests held through related parties under common control for determining whether fees paid to decision makers and service providers are variable interest. The Company adopted the provisions of this ASU effective October 1, 2020. The adoption of this update did not have an impact on Barnwell's consolidated financial statements.
2. GOING CONCERN
The accompanying condensed consolidated financial statements have been prepared on a going concern basis, which contemplates the realization of assets and satisfaction of liabilities in the normal course of business for the twelve-month period following the date of issuance of these condensed consolidated financial statements.
Our ability to sustain our business in the future will depend on sufficientthe sufficiency of our cash on hand, oil and natural gas operating cash flows, which are highly sensitive to volatile oil and natural gas prices, sufficient contract drilling operating cash flows, which are subject to large changes in demand, and sufficient future land investment segment proceeds and distributions from the Kukio Resort Land Development Partnerships, the timing of which are both highly uncertain and not within Barnwell’s control. A sufficient level of such cash and cash inflows are necessary to fund discretionary oil and natural gas capital expenditures, which must be economically successful to provide sufficient returns, as well as fund our non-discretionary outflows such as oil and natural gas asset retirement obligations and ongoing operating and general and administrative expenses.
We have experienced In addition, as discussed in the "Asset Retirement Obligation" section of "Liquidity and Capital Resources," a trendsignificant amount of losses and negative operating cash flows in three of the last four years. Duefunds will be required to uncertainties regarding oil prices and the continuing impacts and uncertainties of the COVID-19 pandemic, we now face a greater uncertainty about our cash inflows as described above, which in turn leads to substantial doubt regarding our ability to make the required discretionary cash outflows for the capital expenditures necessary to convert our proved undeveloped reserves to proved developed reserves. Furthermore, because of the greater uncertainty about our cash inflows described above, there is substantial doubt about our abilitybe put on deposit with Canadian regulatory authorities to fund our non-discretionary cash outflowsabandonments at the Company's oil and thus substantial doubt about our ability to continue as a going concern for one year fromnatural gas properties in the date of the filing of this report.
Prior toManyberries area. Other sources and during fiscal 2021, the Company investigated potential sources of funding including non-core oil and natural gas property sales, however, no probable sources of such funding have yet been secured. Additionally, in fiscal 2020, theare discussed below.
The Company listed its corporate office on the 29th floor of a commercial office building in downtown Honolulu, Hawaii for sale to generate liquidity in order to help mitigate the substantial doubt about our ability to continue as a going concern. However,The corporate office is currently under a purchase and sales contract with a buyer with a tentative closing to occur prior to September 30, 2021. While the
Company believes the likelihood of the sale occurring as per the terms of the contract is more likely than not, the Company’s ability to successfully consummate the sale cannot be assured.
On March 16, 2021, the Company initiated an at-the-market offering program (“ATM”) pursuant to which the Company may offer and sell, from time to time, shares of its corporate office atcommon stock under price and volume guidelines set by the Company's Board of Directors and the terms and conditions described in the Registration Statement. The sale of shares under the ATM began in May 2021 and as of June 30, 2021, the Company sold 586,546 shares of common stock resulting in net proceeds of $1,860,000 after commissions and fees of $59,000. From July 1, 2021 to the date of this Quarterly Report, an appropriate time oradditional 581,441 shares of common stock were sold resulting in net proceeds of $1,924,000 after commissions and fees of $64,000.
In April 2021, the Company re-initiated the marketing of its non-core oil and natural gas properties in the Spirit River, Wood River, Medicine River, Kaybob, Bonanza, Balsam and Thornbury areas for sale. Subsequent to June 30, 2021, Barnwell entered into and completed a sufficientpurchase and sale agreement with an independent third party and sold its interests in certain natural gas and oil properties located in the Spirit River area of Alberta, Canada. The sales price is outsideper the agreement was adjusted for customary purchase price adjustments to $1,047,000 in order to, among other things, reflect an economic effective closing date of sale of July 8, 2021. $524,000 of the Company's control and is therefore not probable. Because of this uncertainty as well assales proceeds was withheld for remittance by the continuing uncertaintiesbuyers to the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes related to the sale. Negotiations regarding the potential durationsales of other non-core oil and depthnatural gas properties is ongoing, however there is no assurance that the sale of any of the other non-core properties will occur.
We have experienced a trend of losses and negative operating cash flows in three of the last four years. During fiscal 2020 and 2021, continuing uncertainties regarding the impacts of the COVID-19 pandemic on our business and the sufficiency of our cash balances and future cash inflows as described above raised substantial doubt about our ability to meet our estimated cash outflows or continue as a going concern for one year from the date of the filing of this report exists. These financial statements do not include any adjustments that might resultreport. However, due to the $3,784,000 of funds raised by the ATM through the date of this Quarterly Report, as well as the $3,965,000 of net cash inflows in the quarter ended June 30, 2021 from land segment percentage of sales proceeds and distributions from the outcome of these uncertainties.Kukio Resort Land Development Partnerships, such substantial doubt has been overcome.
3. EARNINGS (LOSS) PER COMMON SHARE
Basic earnings (loss) per share is computed using the weighted-average number of common shares outstanding for the period. Diluted earnings (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. Potentially dilutive shares are excluded from the computation of diluted earnings (loss) per share if their effect is anti-dilutive.
There were 0 options outstanding at December 31, 2020. Options to purchase 615,000 and 60,000 shares of common stock were excluded from the computation of diluted shares for the three and nine months ended December 31, 2019,June 30, 2021 and 2020, respectively, as their inclusion would have been anti-dilutive.
Reconciliations between net earnings (loss) attributable to Barnwell stockholders and common shares outstanding of the basic and diluted net earnings (loss) per share computations are detailed in the following tables:
| | | | Three months ended December 31, 2020 | | Three months ended June 30, 2021 |
| | | Net Earnings
(Numerator) | | Shares
(Denominator) | | Per-Share
Amount | | Net Earnings
(Numerator) | | Shares
(Denominator) | | Per-Share
Amount |
| Basic net earnings per share | Basic net earnings per share | $ | 584,000 | | | 8,277,160 | | | $ | 0.07 | | Basic net earnings per share | $ | 4,978,000 | | | 8,398,001 | | | $ | 0.59 | |
| Effect of dilutive securities - | Effect of dilutive securities - | | | | | | Effect of dilutive securities - | | | | | |
| common stock options | common stock options | 0 | | | 0 | | | | common stock options | 0 | | | 0 | | | |
| Diluted net earnings per share | Diluted net earnings per share | $ | 584,000 | | | 8,277,160 | | | $ | 0.07 | | Diluted net earnings per share | $ | 4,978,000 | | | 8,398,001 | | | $ | 0.59 | |
| | | | | | | | | | | | | | | | | |
| | Nine months ended June 30, 2021 |
| | Net Earnings
(Numerator) | | Shares
(Denominator) | | Per-Share
Amount |
| Basic net earnings per share | $ | 4,706,000 | | | 8,317,440 | | | $ | 0.57 | |
| Effect of dilutive securities - | | | | | |
| common stock options | 0 | | | 0 | | | |
| Diluted net earnings per share | $ | 4,706,000 | | | 8,317,440 | | | $ | 0.57 | |
| | | | Three months ended December 31, 2019 | | Three months ended June 30, 2020 |
| | | Net Loss (Numerator) | | Shares
(Denominator) | | Per-Share
Amount | | Net Loss
(Numerator) | | Shares
(Denominator) | | Per-Share
Amount |
| Basic net loss per share | Basic net loss per share | $ | (414,000) | | | 8,277,160 | | | $ | (0.05) | | Basic net loss per share | $ | (3,456,000) | | | 8,277,160 | | | $ | (0.42) | |
| Effect of dilutive securities - | Effect of dilutive securities - | | | | | | Effect of dilutive securities - | | | | | |
| common stock options | common stock options | 0 | | | 0 | | | | common stock options | 0 | | | 0 | | | |
| Diluted net loss per share | Diluted net loss per share | $ | (414,000) | | | 8,277,160 | | | $ | (0.05) | | Diluted net loss per share | $ | (3,456,000) | | | 8,277,160 | | | $ | (0.42) | |
4. ASSET HELD FOR SALE
The Company's Honolulu corporate office is currently listed for sale. Accordingly, the Company has designated this property as an asset held for sale and the carrying value in the aggregate amount of $699,000 is included in “Asset held for sale” on the Company's Condensed Consolidated Balance Sheets at December 31, 2020 and September 30, 2020. | | | | | | | | | | | | | | | | | |
| | Nine months ended June 30, 2020 |
| | Net Loss
(Numerator) | | Shares
(Denominator) | | Per-Share
Amount |
| Basic net loss per share | $ | (5,384,000) | | | 8,277,160 | | | $ | (0.65) | |
| Effect of dilutive securities - | | | | | |
| common stock options | 0 | | | 0 | | | |
| Diluted net loss per share | $ | (5,384,000) | | | 8,277,160 | | | $ | (0.65) | |
5.4. INVESTMENTS
Investment in Kukio Resort Land Development Partnerships
On November 27, 2013, Barnwell, through a wholly-owned subsidiary, entered into 2 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'sBarnwell’s ownership interests in the Kukio Resort Land Development Partnerships is accounted for using the equity method of accounting. The partnerships derive income from the sale of residential parcels, of which 159 lots remain to be sold at Increment I as of December 31, 2020,June 30, 2021, as well as from commissions on real estate sales by the real estate sales office. NaN ocean front parcels approximately 2 to 3 acres in size fronting the ocean were developed within Increment II by KD II, of which 1 was sold in fiscal 2017 and 1 was sold in fiscal 2016. The remaining acreage within Increment II is not yet under development, and there is no assurance that development of such acreage will in fact occur.
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.
Barnwell has the right to receive distributions from the Kukio Resort Land Development Partnerships via its its non-controlling interestsinterest in KD Kona and KKM, based on its respective partnership sharing ratios of 75% and 34.45%, respectively. Additionally, Barnwell was entitled to a preferred return from KKM on any allocated equity in income of the Kukio Resort Land Development Partnerships in excess of its partnership sharing ratio for cumulative distributions to all of its partners in excess of $45,000,000 from those partnerships. Cumulative distributions from the Kukio Resort Land Development Partnerships have reached the $45,000,000 threshold and in the quarter ended December 31, 2020, the Kukio Resort Land Development Partnerships made distributions in excess of the threshold out of the proceeds from the sale of two lots in Increment I. Accordingly, Barnwell received a total of $459,000 in preferred return payments, which is reflected as an additional equity pickup in the "Equity in income (loss) of affiliates" line item on the accompanying Condensed Consolidated Statement of Operations for the threenine months ended December 31, 2020.June 30, 2021. The preferred return payments received duringin the quarter ended
December 31, 2020, brought the cumulative preferred return total to $656,000, which is the total amount Barnwell was entitled to, and thus there is no more preferred return outstanding as of December 31, 2020.June 30, 2021.
During the threenine months ended December 31, 2020,June 30, 2021, Barnwell received net cash distributions in the amount of $1,712,000$5,328,000 from the Kukio Resort Land Development Partnerships after distributing $155,000$599,000 to non-controlling interests. Of the $1,712,000$5,328,000 of net cash distributions received from the Kukio Resort Land Development Partnerships, $459,000 represented a payment of the preferred return from KKM, as discussed above. There were 0 cash distributions from the Kukio Resort Land Development Partnerships for the threenine months ended December 31, 2019.June 30, 2020.
Barnwell's
Barnwell’s share of the operating results of its equity affiliates was income of $1,054,000 for the three months ended December 31, 2020,$3,348,000 and $5,026,000, which includes the $459,000 payment of the preferred return from KKM discussed above, as compared to a loss of $43,000 for the three and nine months ended December 31, 2019.June 30, 2021, respectively, compared to losses of $111,000 and $179,000 for the three and nine months ended June 30, 2020, respectively. The equity in the underlying net assets of the Kukio Resort Land Development Partnerships exceeds the carrying value of the investment in affiliates by approximately $263,000$190,000 as of December 31, 2020,June 30, 2021, which is attributable to differences in the value of capitalized development costs and a note receivable. The basis difference will
be recognized as the partnerships sell lots and recognize the associated costs and sell memberships for the Kuki`o Golf and Beach Club for which the receivable relates. The basis difference adjustmentadjustments of $20,000,$94,000 and $5,000 for the threenine months ended December 31,June 30, 2021 and 2020, respectively, increased equity in income of affiliates. There was an immaterial basis difference adjustment for the three months ended December 31, 2019.
Summarized financial information for the Kukio Resort Land Development Partnerships is as follows:
| | | Three months ended
December 31, | | Three months ended June 30, |
| | 2020 | | 2019 | | 2021 | | 2020 |
| Revenue | Revenue | $ | 8,120,000 | | | $ | 1,766,000 | | Revenue | $ | 21,521,000 | | | $ | 496,000 | |
| Gross profit | Gross profit | $ | 3,998,000 | | | $ | 796,000 | | Gross profit | $ | 12,656,000 | | | $ | 140,000 | |
| Net earnings (loss) | Net earnings (loss) | $ | 2,612,000 | | | $ | (168,000) | | Net earnings (loss) | $ | 11,618,000 | | | $ | (501,000) | |
| | | | | | | | | | | |
| Nine months ended June 30, |
| 2021 | | 2020 |
| Revenue | $ | 37,220,000 | | | $ | 3,486,000 | |
| Gross profit | $ | 20,300,000 | | | $ | 1,587,000 | |
| Net earnings (loss) | $ | 16,932,000 | | | $ | (804,000) | |
AsIn the quarter ended June 30, 2021, the Company received cumulative distributions from the Kukio Resort Land Development Partnerships in excess of December 31, 2020our investment balance and in accordance with applicable accounting guidance, the Company suspended its equity method earnings recognition and reduced its Kukio Resort Land Development Partnership investment balance to 0 as of June 30, 2021. In addition, the Company recorded the distributions received in excess of our investment balance of $748,000 as equity in income of affiliates during the three and nine months ended June 30, 2021. The Company records the distributions in excess of our investment in the Kukio Resort Land Development Partnerships as income because the distributions are not refundable by agreement or by law and the Company is not liable for the obligations of or otherwise committed to provide financial support to the Kukio Resort Land Development Partnerships. The Company will record future equity method earnings only after our share of the Kukio Resort Land Development Partnership’s cumulative earnings during the suspended period exceeds our share of the Kukio Resort Land Development Partnership’s income recognized for the excess distributions.
At September 30, 2020, Barnwell's non-currentthe Company’s investment in the Kukio Resort Land Development Partnerships was $88,000 and $901,000, respectively.$901,000.
Sale of Interest in Leasehold Land
Kaupulehu Developments has the right to receive payments from KD I and KD II resulting from the sale of lots and/or residential units within Increment I and Increment II by KD I and KD II (see Note 16)18).
With respect to Increment I, Kaupulehu Developments is entitled to receive payments from KD I based on the following percentages of the gross receipts from KD I’s sales of single-family residential lots in Increment I: 10% of such aggregate gross proceeds greater than $100,000,000 up to $300,000,000; and 14% of such aggregate gross proceeds in excess of $300,000,000. The total amount of gross proceeds from single-family lotlots sales was $224,500,000$237,038,000 through December 31, 2020.June 30, 2021. NaN single-family lots were sold
during the threenine months ended December 31, 2020June 30, 2021 and 159 single-family lots, of the 80 lots developed within Increment I, remained to be sold as of December 31, 2020.June 30, 2021.
Under the terms of the Increment II agreement with KD II, Kaupulehu Developments is entitled to 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 as to the priority payout. Such interests are limited to distributions or net profits interests and Barnwell willdoes not have any partnership interests in KD II or KDK through its interest in Kaupulehu Developments. The arrangement also gives Barnwell rights to 3 single-family residential lots in Phase 2A of Increment II, and 4 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 4 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%0.2% 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, in compensation for the agreement of these parties to admit the new development partner for Increment II. Such compensation will be reflected as the obligation becomes probable and the amount of the obligation can be reasonably estimated.
The following table summarizes the Increment I revenues from KD I and the amount of fees directly related to such revenues:
| | | | Three months ended
December 31, | | Three months ended
June 30, | | Nine months ended
June 30, |
| | | 2020 | | 2019 | | 2021 | | 2020 | | 2021 | | 2020 |
| Sale of interest in leasehold land: | Sale of interest in leasehold land: | | | | Sale of interest in leasehold land: | | | | | | | |
| Revenues - sale of interest in leasehold land | Revenues - sale of interest in leasehold land | $ | 485,000 | | | $ | 0 | | Revenues - sale of interest in leasehold land | $ | 1,253,000 | | | $ | 0 | | | $ | 1,738,000 | | | $ | 0 | |
| Fees - included in general and administrative expenses | Fees - included in general and administrative expenses | (59,000) | | | 0 | | Fees - included in general and administrative expenses | (153,000) | | | 0 | | | (212,000) | | | 0 | |
| Sale of interest in leasehold land, net of fees paid | Sale of interest in leasehold land, net of fees paid | $ | 426,000 | | | $ | 0 | | Sale of interest in leasehold land, net of fees paid | $ | 1,100,000 | | | $ | 0 | | | $ | 1,526,000 | | | $ | 0 | |
There is no assurance with regards to the amounts of future payments from Increment I or Increment II to be received, or that the remaining acreage within Increment II will be developed.
Investment in Leasehold Land Interest - Lot 4C
Kaupulehu Developments holds an interest in an area of approximately 1,000 acres of vacant leasehold land zoned conservation located adjacent to Lot 4A, which currently has no development potential without both a development agreement with the lessor and zoning reclassification. The lease terminates in December 2025.
5. 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”), an entity affiliated with the Company, entered into the Limited Liability Agreement (the “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 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 Venture 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 and in March 2021, the Company made a capital contribution of $250,000 to Teton Barnwell to fund its initial oil and natural gas investment in Oklahoma.
The Company has determined that Teton Barnwell is a 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 Agreement and thus, BOK has the power to steer the decisions that most significantly impact Teton Barnwell’s economic performance and has the 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.
On July 12, 2021, Colin R. O'Farrell, who is the sole member of Four Pines Operating LLC which owns a 25% interest in Gros Ventre, became a member of the Board of Directors of 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.
| | | | | |
| June 30,
2021 |
| ASSETS | |
| Cash and cash equivalents | $ | 118,000 | |
| Accounts and other receivables | 38,000 | |
| Property and equipment, net | 584,000 | |
| Total assets | $ | 740,000 | |
| |
| LIABILITIES | |
| Accounts payable | $ | 1,000 | |
| Accrued capital expenditures | 464,000 | |
| Accrued operating and other expenses | 5,000 | |
| Total liabilities | $ | 470,000 | |
6.ASSET HELD FOR SALE
The Company's Honolulu corporate office is currently listed for sale. Accordingly, the Company has designated this property as an asset held for sale and the carrying value in the aggregate amount of $699,000 is included in “Asset held for sale” on the Company's Condensed Consolidated Balance Sheets at June 30, 2021 and September 30, 2020. In March 2021, the Company entered into a purchase and sales contract with a buyer for the sale of our corporate office with a tentative closing to occur prior to September 30, 2021.
7. OIL AND NATURAL GAS PROPERTIES
Dispositions
There On April 8, 2021, Barnwell entered into a purchase and sale agreement with an independent third party and sold its interests in properties located in the Hillsdown area of Alberta, Canada. The sales price per the agreement was adjusted for customary purchase price adjustments to $132,000 in order to, among other things, reflect an economic effective date of October 1, 2020. $72,000 of the sales proceeds was withheld by the buyers for potential amounts due for Barnwell’s Canadian income taxes related to the sale. 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 proceeds were credited to the full cost pool, with no oilgain or loss recognized, as the sale did not result in a significant alteration of the relationship between capitalized costs and natural gas property dispositions during the three months ended December 31, 2020.proved reserves.
In the quarter ended December 31, 2019, Barnwell entered into a purchase and sale agreement with an independent third party and sold its interests in properties located in the Progress area of Alberta, Canada. The sales price per the agreement was adjusted for customary purchase price adjustments to
$594,000 $594,000 in order to, among other things, reflect an economic effective date of October 1, 2019. The proceeds were credited to the full cost pool, with no gain or loss recognized, as the sale did not result in a significant alteration of the relationship between capitalized costs and proved reserves.
Acquisitions
On April 8, 2021, Barnwell acquired additional working interests in oil and natural gas properties located in the Twining area of Alberta, Canada for cash consideration of $348,000. The purchase price per the agreement was adjusted for customary purchase price adjustments to reflect the economic activity from the effective date to the closing date. 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.
There were no significant amounts paid for oil and natural gas property acquisitions during the threenine months ended December 31, 2020, and 2019.June 30, 2020.
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. There was a $630,000 ceiling test impairment during the three months ended December 31, 2020. There was 0 ceiling test impairment during the three months ended December 31, 2019.June 30, 2021 and there was a $630,000 ceiling test impairment during the nine months ended June 30, 2021. There was a ceiling test impairment of $2,689,000 and $4,326,000 during the three and nine months ended June 30, 2020, respectively.
Changes in the mandated 12-month historical 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 estimated market value of unproved properties, impact the determination of the maximum carrying value of oil and natural gas properties. The ceiling test calculation as of December 31, 2019 included management’s estimation that the Company had the ability to fund all of the future capital expenditures necessary over the next five years to develop proved undeveloped reserves in the Twining area of Alberta, Canada. However, due to the impact on oil prices and the extreme uncertainties created by the COVID-19 pandemic on the Company's financial outlook, management is no longer reasonably certain that the Company will have the financial resources necessary to make any of the capital expenditures necessary to develop the proved undeveloped reserves. Therefore, the proved undeveloped reserves have been excluded from the quarterly ceiling test calculations subsequent to December 31, 2019.
As discussed above, the ceiling test mandates the use of the 12-month historical rolling average first-day-of-the-month prices. If the 12-month historical rolling average first-day-of-the-month prices decline from the 12-month historical rolling average first-day-of-the-month prices used in the December 31, 2020 ceiling calculation, the Company could incur further impairment write-downs in future periods in the absence of any offsetting factors that are not currently known or projected.
7.8. RETIREMENT PLANS
Barnwell sponsors a noncontributory defined benefit pension plan (“Pension Plan”) covering substantially all of its U.S. employees. Additionally, Barnwell sponsors a Supplemental Executive Retirement Plan (“SERP”), a noncontributory supplemental retirement benefit plan which covers certain current and former employees of Barnwell for amounts exceeding the limits allowed under the Pension Plan, and previously sponsored a postretirementpost-retirement medical insurance benefits plan (“PostretirementPost-retirement Medical”) covering eligible U.S. employees.
In December 2019, the Company’s Board of Directors approved a resolution to freeze all future benefit accruals for all participants under the Company’s Pension Plan and SERP effective December 31, 2019. Consequently, current participants in the Pension Plan and SERP no longer accrue new benefits under the plans and new employees of the Company are no longer eligible to enter the Pension Plan and
SERP as participants after December 31, 2019. The freezing of the Pension Plan and SERP triggered a curtailment which required a remeasurement of the projected benefit obligations of the Pension Plan and SERP and resulted in an $880,000 actuarial gain in accumulated other comprehensive loss and a $1,699,000 reduction in unrecognized pension benefit costs that were previously included in accumulated other comprehensive loss, with a corresponding benefit in other comprehensive income which were recorded in the quarter ended December 31, 2019.
In June 2021, the Company terminated its Post-retirement Medical plan, which covered officers of the Company who had attained at least 20 years of service of which at least 10 years were at the position of Vice President or higher, their spouses and qualifying dependents, effective June 4, 2021. The Post-retirement Medical plan was an unfunded plan and the Company funded benefits when payments were made. As result of the plan termination, the Company recognized a non-cash gain of $2,341,000 during the three and nine months ended June 30, 2021.
The following table detailstables detail the components of net periodic benefit income (cost)(income) cost for Barnwell’s retirement plans:
| | | | Pension Plan | | SERP | | Postretirement Medical | | Pension Plan | | SERP | | Post-retirement Medical |
| | | Three months ended December 31, | | Three months ended June 30, |
| | | 2020 | | 2019 | | 2020 | | 2019 | | 2020 | | 2019 | | 2021 | | 2020 | | 2021 | | 2020 | | 2021 | | 2020 |
| Service cost | $ | 0 | | | $ | 50,000 | | | $ | 0 | | | $ | 3,000 | | | $ | 0 | | | $ | 0 | | |
| | Interest cost | Interest cost | 65,000 | | | 83,000 | | | 13,000 | | | 18,000 | | | 18,000 | | | 20,000 | | Interest cost | $ | 64,000 | | | $ | 73,000 | | | $ | 13,000 | | | $ | 16,000 | | | $ | 12,000 | | | $ | 20,000 | |
| Expected return on plan assets | Expected return on plan assets | (137,000) | | | (163,000) | | | 0 | | | 0 | | | 0 | | | 0 | | Expected return on plan assets | (136,000) | | | (173,000) | | | — | | | — | | | — | | | — | |
| Amortization of prior service cost (credit) | 0 | | | 1,000 | | | 0 | | | (1,000) | | | 0 | | | 0 | | |
| | Amortization of net actuarial loss | Amortization of net actuarial loss | 10,000 | | | 35,000 | | | 0 | | | 5,000 | | | 23,000 | | | 20,000 | | Amortization of net actuarial loss | 10,000 | | | 0 | | | 0 | | | 0 | | | 16,000 | | | 20,000 | |
| Curtailment cost (income) | 0 | | | 53,000 | | | 0 | | | (53,000) | | | 0 | | | 0 | | |
| | Net periodic benefit (income) cost | Net periodic benefit (income) cost | $ | (62,000) | | | $ | 59,000 | | | $ | 13,000 | | | $ | (28,000) | | | $ | 41,000 | | | $ | 40,000 | | Net periodic benefit (income) cost | $ | (62,000) | | | $ | (100,000) | | | $ | 13,000 | | | $ | 16,000 | | | $ | 28,000 | | | $ | 40,000 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Pension Plan | | SERP | | Post-retirement Medical |
| | Nine months ended June 30, |
| | 2021 | | 2020 | | 2021 | | 2020 | | 2021 | | 2020 |
| Service cost | $ | 0 | | | $ | 50,000 | | | $ | 0 | | | $ | 3,000 | | | $ | 0 | | | $ | 0 | |
| Interest cost | 193,000 | | | 228,000 | | | 39,000 | | | 49,000 | | | 48,000 | | | 60,000 | |
| Expected return on plan assets | (410,000) | | | (508,000) | | | — | | | — | | | — | | | — | |
| Amortization of prior service cost (credit) | 0 | | | 1,000 | | | 0 | | | (1,000) | | | 0 | | | 0 | |
| Amortization of net actuarial loss | 30,000 | | | 35,000 | | | 0 | | | 5,000 | | | 62,000 | | | 60,000 | |
| | | | | | | | | | | |
| Curtailment cost (income) | 0 | | | 53,000 | | | 0 | | | (53,000) | | | 0 | | | 0 | |
| Net periodic benefit (income) cost | $ | (187,000) | | | $ | (141,000) | | | $ | 39,000 | | | $ | 3,000 | | | $ | 110,000 | | | $ | 120,000 | |
The net periodic benefit (income) cost, including service cost, is included in “General and administrative” expenses in the Company's Condensed Consolidated Statements of Operations.
Currently, 0 contributions are expected to be made to the Pension Plan during fiscal 2021. The SERP and Postretirement Medical plans areplan is unfunded and Barnwell funds benefits when payments are made. Expected payments under the Postretirement Medical plan and the SERP for fiscal 2021 areis not material. Fluctuations in actual equity market returns as well as changes in general interest rates will result in changes in the market value of plan assets and may result in increased or decreased retirement benefits costs and contributions in future periods.
8.9. INCOME TAXES
The components of earnings (loss) before income taxes, after adjusting the earnings (loss) for non-controlling interests, are as follows:
| | | Three months ended
December 31, | | Three months ended
June 30, | | Nine months ended
June 30, |
| | | | 2020 | | 2019 | | 2021 | | 2020 | | 2021 | | 2020 |
| United States | United States | | $ | 1,422,000 | | | $ | (147,000) | | United States | $ | 4,770,000 | | | $ | 163,000 | | | $ | 5,261,000 | | | $ | 717,000 | |
| Canada | Canada | | (775,000) | | | (269,000) | | Canada | 399,000 | | | (3,643,000) | | | (267,000) | | | (6,127,000) | |
| | | | $ | 647,000 | | | $ | (416,000) | | | $ | 5,169,000 | | | $ | (3,480,000) | | | $ | 4,994,000 | | | $ | (5,410,000) | |
The components of the income tax provision (benefit) are as follows:
| | | Three months ended
December 31, | | Three months ended
June 30, | | Nine months ended
June 30, |
| | | 2020 | | 2019 | | 2021 | | 2020 | | 2021 | | 2020 |
| Current | Current | $ | 24,000 | | | $ | 7,000 | | Current | $ | 40,000 | | | $ | (26,000) | | | $ | 123,000 | | | $ | (19,000) | |
| Deferred | Deferred | 39,000 | | | (9,000) | | Deferred | 151,000 | | | 2,000 | | | 165,000 | | | (7,000) | |
| | | $ | 63,000 | | | $ | (2,000) | | | $ | 191,000 | | | $ | (24,000) | | | $ | 288,000 | | | $ | (26,000) | |
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. Income from our non-controllingnon-
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.
On December 27, 2020, President Trump signed into law the Consolidated Appropriations Act (the “Act”), an omnibus spending bill to fund the federal government that also includes an array of COVID-related tax relief for individuals and businesses. The tax-related measures contained in the Act revise and expand provisions enacted earlier in the year by the Families First Coronavirus Response Act and the Coronavirus Aid, Relief, and Economic Security Act. The Act also extends a number of expiring tax provisions. Additionally, the Act provides for a 100% deduction for certain business meals incurred in calendar years 2021 and 2022. The Company determined that income tax effects related to the passage of the Act were not material to the financial statements for the three and nine months ended December 31, 2020.June 30, 2021.
9.10. REVENUE FROM CONTRACTS WITH CUSTOMERS
Disaggregation of Revenue
The following tables providesprovide information about disaggregated revenue by revenue streams, reportable segments, geographical region, and timing of revenue recognition for the three and nine months ended December 31, 2020June 30, 2021 and 2019.2020.
| | | Three months ended December 31, 2020 | | Three months ended June 30, 2021 |
| | Oil and natural gas | | Contract drilling | | Land investment | | Other | | Total | | Oil and natural gas | | Contract drilling | | Land investment | | Other | | Total |
| Revenue streams: | Revenue streams: | | | | | | | | | | Revenue streams: | | | | | | | | | |
| | Oil | $ | 1,380,000 | | | $ | 0 | | | $ | 0 | | | $ | 0 | | | $ | 1,380,000 | | | Oil | $ | 2,156,000 | | | $ | 0 | | | $ | 0 | | | $ | 0 | | | $ | 2,156,000 | |
| | Natural gas | 375,000 | | | 0 | | | 0 | | | 0 | | | 375,000 | | | Natural gas | 514,000 | | | 0 | | | 0 | | | 0 | | | 514,000 | |
| | Natural gas liquids | 132,000 | | | 0 | | | 0 | | | 0 | | | 132,000 | | | Natural gas liquids | 217,000 | | | 0 | | | 0 | | | 0 | | | 217,000 | |
| | Drilling and pump | 0 | | | 1,942,000 | | | 0 | | | 0 | | | 1,942,000 | | | Drilling and pump | 0 | | | 889,000 | | | 0 | | | 0 | | | 889,000 | |
| | Contingent residual payments | 0 | | | 0 | | | 485,000 | | | 0 | | | 485,000 | | | Contingent residual payments | 0 | | | 0 | | | 1,253,000 | | | 0 | | | 1,253,000 | |
| | Other | 0 | | | 0 | | | 0 | | | 73,000 | | | 73,000 | | | Other | 0 | | | 0 | | | 0 | | | 79,000 | | | 79,000 | |
| | Total revenues before interest income | $ | 1,887,000 | | | $ | 1,942,000 | | | $ | 485,000 | | | $ | 73,000 | | | $ | 4,387,000 | | | Total revenues before interest income | $ | 2,887,000 | | | $ | 889,000 | | | $ | 1,253,000 | | | $ | 79,000 | | | $ | 5,108,000 | |
| Geographical regions: | Geographical regions: | | | | | | | | | | Geographical regions: | | | | | | | | | |
| | United States | $ | 0 | | | $ | 1,942,000 | | | $ | 485,000 | | | $ | 0 | | | $ | 2,427,000 | | | United States | $ | 41,000 | | | $ | 889,000 | | | $ | 1,253,000 | | | $ | 2,000 | | | $ | 2,185,000 | |
| | Canada | 1,887,000 | | | 0 | | | 0 | | | 73,000 | | | 1,960,000 | | | Canada | 2,846,000 | | | 0 | | | 0 | | | 77,000 | | | 2,923,000 | |
| | Total revenues before interest income | $ | 1,887,000 | | | $ | 1,942,000 | | | $ | 485,000 | | | $ | 73,000 | | | $ | 4,387,000 | | | Total revenues before interest income | $ | 2,887,000 | | | $ | 889,000 | | | $ | 1,253,000 | | | $ | 79,000 | | | $ | 5,108,000 | |
| Timing of revenue recognition: | Timing of revenue recognition: | | | | | | | | | | Timing of revenue recognition: | | | | | | | | | |
| | Goods transferred at a point in time | $ | 1,887,000 | | | $ | 0 | | | $ | 485,000 | | | $ | 73,000 | | | $ | 2,445,000 | | | Goods transferred at a point in time | $ | 2,887,000 | | | $ | 0 | | | $ | 1,253,000 | | | $ | 79,000 | | | $ | 4,219,000 | |
| | Services transferred over time | 0 | | | 1,942,000 | | | 0 | | | 0 | | | 1,942,000 | | | Services transferred over time | 0 | | | 889,000 | | | 0 | | | 0 | | | 889,000 | |
| | Total revenues before interest income | $ | 1,887,000 | | | $ | 1,942,000 | | | $ | 485,000 | | | $ | 73,000 | | | $ | 4,387,000 | | | Total revenues before interest income | $ | 2,887,000 | | | $ | 889,000 | | | $ | 1,253,000 | | | $ | 79,000 | | | $ | 5,108,000 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Three months ended December 31, 2019 |
| | Oil and natural gas | | Contract drilling | | Land investment | | Other | | Total |
| Revenue streams: | | | | | | | | | |
| Oil | $ | 1,725,000 | | | $ | 0 | | | $ | 0 | | | $ | 0 | | | $ | 1,725,000 | |
| Natural gas | 322,000 | | | 0 | | | 0 | | | 0 | | | 322,000 | |
| Natural gas liquids | 94,000 | | | 0 | | | 0 | | | 0 | | | 94,000 | |
| Drilling and pump | 0 | | | 2,646,000 | | | 0 | | | 0 | | | 2,646,000 | |
| Contingent residual payments | 0 | | | 0 | | | 0 | | | 0 | | | 0 | |
| Other | 0 | | | 0 | | | 0 | | | 56,000 | | | 56,000 | |
| Total revenues before interest income | $ | 2,141,000 | | | $ | 2,646,000 | | | $ | 0 | | | $ | 56,000 | | | $ | 4,843,000 | |
| Geographical regions: | | | | | | | | | |
| United States | $ | 0 | | | $ | 2,646,000 | | | $ | 0 | | | $ | 7,000 | | | $ | 2,653,000 | |
| Canada | 2,141,000 | | | 0 | | | 0 | | | 49,000 | | | 2,190,000 | |
| Total revenues before interest income | $ | 2,141,000 | | | $ | 2,646,000 | | | $ | 0 | | | $ | 56,000 | | | $ | 4,843,000 | |
| Timing of revenue recognition: | | | | | | | | | |
| Goods transferred at a point in time | $ | 2,141,000 | | | $ | 0 | | | $ | 0 | | | $ | 56,000 | | | $ | 2,197,000 | |
| Services transferred over time | 0 | | | 2,646,000 | | | 0 | | | 0 | | | 2,646,000 | |
| Total revenues before interest income | $ | 2,141,000 | | | $ | 2,646,000 | | | $ | 0 | | | $ | 56,000 | | | $ | 4,843,000 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Three months ended June 30, 2020 |
| | Oil and natural gas | | Contract drilling | | Land investment | | Other | | Total |
| Revenue streams: | | | | | | | | | |
| Oil | $ | 624,000 | | | $ | 0 | | | $ | 0 | | | $ | 0 | | | $ | 624,000 | |
| Natural gas | 192,000 | | | 0 | | | 0 | | | 0 | | | 192,000 | |
| Natural gas liquids | 14,000 | | | 0 | | | 0 | | | 0 | | | 14,000 | |
| Drilling and pump | 0 | | | 3,040,000 | | | 0 | | | 0 | | | 3,040,000 | |
| | | | | | | | | | |
| Other | 0 | | | 0 | | | 0 | | | 113,000 | | | 113,000 | |
| Total revenues before interest income | $ | 830,000 | | | $ | 3,040,000 | | | $ | 0 | | | $ | 113,000 | | | $ | 3,983,000 | |
| Geographical regions: | | | | | | | | | |
| United States | $ | 0 | | | $ | 3,040,000 | | | $ | 0 | | | $ | 0 | | | $ | 3,040,000 | |
| Canada | 830,000 | | | 0 | | | 0 | | | 113,000 | | | 943,000 | |
| Total revenues before interest income | $ | 830,000 | | | $ | 3,040,000 | | | $ | 0 | | | $ | 113,000 | | | $ | 3,983,000 | |
| Timing of revenue recognition: | | | | | | | | | |
| Goods transferred at a point in time | $ | 830,000 | | | $ | 0 | | | $ | 0 | | | $ | 113,000 | | | $ | 943,000 | |
| Services transferred over time | 0 | | | 3,040,000 | | | 0 | | | 0 | | | 3,040,000 | |
| Total revenues before interest income | $ | 830,000 | | | $ | 3,040,000 | | | $ | 0 | | | $ | 113,000 | | | $ | 3,983,000 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Nine months ended June 30, 2021 |
| | Oil and natural gas | | Contract drilling | | Land investment | | Other | | Total |
| Revenue streams: | | | | | | | | | |
| Oil | $ | 5,469,000 | | | $ | 0 | | | $ | 0 | | | $ | 0 | | | $ | 5,469,000 | |
| Natural gas | 1,350,000 | | | 0 | | | 0 | | | 0 | | | 1,350,000 | |
| Natural gas liquids | 507,000 | | | 0 | | | 0 | | | 0 | | | 507,000 | |
| Drilling and pump | 0 | | | 4,220,000 | | | 0 | | | 0 | | | 4,220,000 | |
| Contingent residual payments | 0 | | | 0 | | | 1,738,000 | | | 0 | | | 1,738,000 | |
| Other | 0 | | | 0 | | | 0 | | | 209,000 | | | 209,000 | |
| Total revenues before interest income | $ | 7,326,000 | | | $ | 4,220,000 | | | $ | 1,738,000 | | | $ | 209,000 | | | $ | 13,493,000 | |
| Geographical regions: | | | | | | | | | |
| United States | $ | 41,000 | | | $ | 4,220,000 | | | $ | 1,738,000 | | | $ | 6,000 | | | $ | 6,005,000 | |
| Canada | 7,285,000 | | | 0 | | | 0 | | | 203,000 | | | 7,488,000 | |
| Total revenues before interest income | $ | 7,326,000 | | | $ | 4,220,000 | | | $ | 1,738,000 | | | $ | 209,000 | | | $ | 13,493,000 | |
| Timing of revenue recognition: | | | | | | | | | |
| Goods transferred at a point in time | $ | 7,326,000 | | | $ | 0 | | | $ | 1,738,000 | | | $ | 209,000 | | | $ | 9,273,000 | |
| Services transferred over time | 0 | | | 4,220,000 | | | 0 | | | 0 | | | 4,220,000 | |
| Total revenues before interest income | $ | 7,326,000 | | | $ | 4,220,000 | | | $ | 1,738,000 | | | $ | 209,000 | | | $ | 13,493,000 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Nine months ended June 30, 2020 |
| | Oil and natural gas | | Contract drilling | | Land investment | | Other | | Total |
| Revenue streams: | | | | | | | | | |
| Oil | $ | 3,827,000 | | | $ | 0 | | | $ | 0 | | | $ | 0 | | | $ | 3,827,000 | |
| Natural gas | 821,000 | | | 0 | | | 0 | | | 0 | | | 821,000 | |
| Natural gas liquids | 233,000 | | | 0 | | | 0 | | | 0 | | | 233,000 | |
| Drilling and pump | 0 | | | 8,279,000 | | | 0 | | | 0 | | | 8,279,000 | |
| | | | | | | | | | |
| Other | 0 | | | 0 | | | 0 | | | 239,000 | | | 239,000 | |
| Total revenues before interest income | $ | 4,881,000 | | | $ | 8,279,000 | | | $ | 0 | | | $ | 239,000 | | | $ | 13,399,000 | |
| Geographical regions: | | | | | | | | | |
| United States | $ | 0 | | | $ | 8,279,000 | | | $ | 0 | | | $ | 7,000 | | | $ | 8,286,000 | |
| Canada | 4,881,000 | | | 0 | | | 0 | | | 232,000 | | | 5,113,000 | |
| Total revenues before interest income | $ | 4,881,000 | | | $ | 8,279,000 | | | $ | 0 | | | $ | 239,000 | | | $ | 13,399,000 | |
| Timing of revenue recognition: | | | | | | | | | |
| Goods transferred at a point in time | $ | 4,881,000 | | | $ | 0 | | | $ | 0 | | | $ | 239,000 | | | $ | 5,120,000 | |
| Services transferred over time | 0 | | | 8,279,000 | | | 0 | | | 0 | | | 8,279,000 | |
| Total revenues before interest income | $ | 4,881,000 | | | $ | 8,279,000 | | | $ | 0 | | | $ | 239,000 | | | $ | 13,399,000 | |
Contract Balances
The following table provides information about accounts receivables, contract assets and contract liabilities from contracts with customers:
| | | December 31, 2020 | | September 30, 2020 | | June 30, 2021 | | September 30, 2020 |
| Accounts receivables from contracts with customers | Accounts receivables from contracts with customers | $ | 1,625,000 | | | $ | 1,772,000 | | Accounts receivables from contracts with customers | $ | 1,753,000 | | | $ | 1,772,000 | |
| Contract assets | Contract assets | 385,000 | | | 413,000 | | Contract assets | 810,000 | | | 413,000 | |
| Contract liabilities | Contract liabilities | 751,000 | | | 1,097,000 | | Contract liabilities | 184,000 | | | 1,097,000 | |
|
Accounts receivables from contracts with customers are included in "Accounts“Accounts and other receivables, net of allowance for doubtful accounts,"” and contract assets, which includes costs and estimated earnings in excess of billings and retainage, are included in “Other current assets.” 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 December 31, 2020June 30, 2021 and September 30, 2020, the Company had $751,000$184,000 and $1,097,000, respectively, included in “Other current liabilities” on the balance sheetsheets for those performance obligations expected to be completed in the next twelve months.
During the threenine months ended December 31,June 30, 2021 and 2020, and 2019, the amount of revenue recognized that was previously included in contract liabilities as of the beginning of the respective period was $573,000$978,000 and $1,480,000,$707,000, respectively.
Contracts are sometimes modified for a change in scope or other requirements. The Company considers contract modifications to exist when the modification either creates new or changes the existing enforceable rights and obligations. Most of the Company’s contract modifications are for goods and services that are not distinct from the existing performance obligations. The effect of a contract modification on the transaction price, and the measure of progress for the performance obligation to which it relates, is recognized as an adjustment to revenue (either as an increase or decrease) on a cumulative catchup basis.
Performance Obligations
The Company’s remaining performance obligations for drilling and pump installation contracts (hereafter referred to as “backlog”) represent the unrecognized revenue value of the Company’s contract commitments. The Company’s backlog may vary significantly each reporting period based on the timing of major new contract commitments. In addition, our customers have the right, under some infrequent circumstances, to terminate contracts or defer the timing of the Company’s services and their payments to us. Nearly all of the Company's contract drilling segment contracts have original expected durations of one year or less. At December 31, 2020,June 30, 2021, the Company had three contract drilling jobs with original expected durations of greater than one year. For these contracts, approximately 7% of the remaining performance obligation of $2,615,000$2,613,000 is expected to be recognized as revenue in the next twelve months and the remaining, thereafter.
Contract Fulfillment Costs
Preconstruction costs, which include costs such as set-up and mobilization, are capitalized and allocated across all performance obligations and deferred and amortized over the contract term on a progress towards completion basis. As of December 31, 2020June 30, 2021 and September 30, 2020, the Company had $147,000$119,000 and $145,000, respectively, in unamortized preconstruction costs related to contracts that were not completed. During the three and nine months ended December 31,June 30, 2021 and 2020, and 2019, the amortization of preconstruction costs related to contracts were not material and were included in the accompanying Condensed Consolidated Statements of Operations. Additionally, no impairment charges in connection with the Company’s preconstruction costs were recorded during the three and nine months ended December 31, 2020June 30, 2021 and 2019.2020.
Water Well Re-drill
In the quarter ended December 31, 2019, the Company experienced the failure of a hole opener which broke apart leaving pieces in the bottom of a water well being drilled in Hawaii. Efforts to remove the items from the well were unsuccessful through the quarter ended March 31, 2020 and subsequently the Company determined that the well should be abandoned and a new well drilled at no incremental cost to the customer as per the terms of the contract. Accordingly, all the costs to drill and abandon the first well, which are all wasted costs, were excluded from the measurement of progress toward contract completion and all such costs were fully accrued in the quarter ended March 31, 2020, as this contract was determined to be a loss job. In September 2020, while making progress towards the drilling of a replacement well in different location, the drill string twisted off and became lodged in the well borehole, which required a stoppage of drilling and the need to dislodge and retrieve the broken drill string. Accordingly, the estimated total rework costs to remediate the situation was accrued at September 30, 2020. In January 2021, the broken drill string was retrieved from the well borehole and drilling of the replacement well recommenced.
10.11. SEGMENT INFORMATION
Barnwell operates the following segments: 1) acquiring, developing, producing and selling oil and natural gas in Canada and Oklahoma (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 0 intersegment sales or transfers.
| | | | | | | | | | | |
| Three months ended
December 31, |
| | 2020 | | 2019 |
| Revenues: | | | |
| Oil and natural gas | $ | 1,887,000 | | | $ | 2,141,000 | |
| Contract drilling | 1,942,000 | | | 2,646,000 | |
| Land investment | 485,000 | | | 0 | |
| Other | 73,000 | | | 56,000 | |
| Total before interest income | 4,387,000 | | | 4,843,000 | |
| Interest income | 0 | | | 7,000 | |
| Total revenues | $ | 4,387,000 | | | $ | 4,850,000 | |
| Depletion, depreciation, and amortization: | | | |
| Oil and natural gas | $ | 195,000 | | | $ | 606,000 | |
| Contract drilling | 76,000 | | | 85,000 | |
| Other | 5,000 | | | 14,000 | |
| Total depletion, depreciation, and amortization | $ | 276,000 | | | $ | 705,000 | |
| Impairment: | | | |
| Oil and natural gas | $ | 630,000 | | | $ | 0 | |
| Total impairment | $ | 630,000 | | | $ | 0 | |
| Operating profit (loss) (before general and administrative expenses): | | | |
| Oil and natural gas | $ | (373,000) | | | $ | 322,000 | |
| Contract drilling | 758,000 | | | 747,000 | |
| Land investment | 485,000 | | | 0 | |
| Other | 68,000 | | | 42,000 | |
| Total operating profit | 938,000 | | | 1,111,000 | |
| Equity in income (loss) of affiliates: | | | |
| Land investment | 1,054,000 | | | (43,000) | |
| General and administrative expenses | (1,185,000) | | | (1,496,000) | |
| Interest expense | (1,000) | | | 0 | |
| Interest income | 0 | | | 7,000 | |
| Earnings (loss) before income taxes | $ | 806,000 | | | $ | (421,000) | |
| | | | | | | | | | | | | | | | | | | | | | | |
| Three months ended
June 30, | | Nine months ended
June 30, |
| | 2021 | | 2020 | | 2021 | | 2020 |
| Revenues: | | | | | | | |
| Oil and natural gas | $ | 2,887,000 | | | $ | 830,000 | | | $ | 7,326,000 | | | $ | 4,881,000 | |
| Contract drilling | 889,000 | | | 3,040,000 | | | 4,220,000 | | | 8,279,000 | |
| Land investment | 1,253,000 | | | 0 | | | 1,738,000 | | | 0 | |
| Other | 79,000 | | | 113,000 | | | 209,000 | | | 239,000 | |
| Total before interest income | 5,108,000 | | | 3,983,000 | | | 13,493,000 | | | 13,399,000 | |
| Interest income | 6,000 | | | 1,000 | | | 6,000 | | | 17,000 | |
| Total revenues | $ | 5,114,000 | | | $ | 3,984,000 | | | $ | 13,499,000 | | | $ | 13,416,000 | |
| Depletion, depreciation, and amortization: | | | | | | | |
| Oil and natural gas | $ | 155,000 | | | $ | 372,000 | | | $ | 496,000 | | | $ | 1,562,000 | |
| Contract drilling | 76,000 | | | 96,000 | | | 229,000 | | | 272,000 | |
| Other | 4,000 | | | 10,000 | | | 13,000 | | | 36,000 | |
| Total depletion, depreciation, and amortization | $ | 235,000 | | | $ | 478,000 | | | $ | 738,000 | | | $ | 1,870,000 | |
| Impairment: | | | | | | | |
| Oil and natural gas | $ | 0 | | | $ | 2,689,000 | | | $ | 630,000 | | | $ | 4,326,000 | |
| | | | | | | |
| | | | | | | |
| Total impairment | $ | 0 | | | $ | 2,689,000 | | | $ | 630,000 | | | $ | 4,326,000 | |
| Operating profit (loss) (before general and administrative expenses): | | | | | | | |
| Oil and natural gas | $ | 1,015,000 | | | $ | (3,212,000) | | | $ | 1,289,000 | | | $ | (4,486,000) | |
| Contract drilling | (213,000) | | | 977,000 | | | 392,000 | | | 2,455,000 | |
| Land investment | 1,253,000 | | | 0 | | | 1,738,000 | | | 0 | |
| Other | 75,000 | | | 103,000 | | | 196,000 | | | 203,000 | |
| Gain on sale of asset | 0 | | | 0 | | | 0 | | | 1,336,000 | |
| Total operating profit (loss) | 2,130,000 | | | (2,132,000) | | | 3,615,000 | | | (492,000) | |
| Equity in income (loss) of affiliates: | | | | | | | |
| Land investment | 3,348,000 | | | (111,000) | | | 5,026,000 | | | (179,000) | |
| General and administrative expenses | (2,227,000) | | | (1,248,000) | | | (5,340,000) | | | (4,775,000) | |
| Interest expense | (2,000) | | | (1,000) | | | (6,000) | | | (1,000) | |
| Interest income | 6,000 | | | 1,000 | | | 6,000 | | | 17,000 | |
| Gain on debt extinguishment | 149,000 | | | 0 | | | 149,000 | | | 0 | |
| Gain on termination of post-retirement medical plan | 2,341,000 | | | 0 | | | 2,341,000 | | | 0 | |
| Earnings (loss) before income taxes | $ | 5,745,000 | | | $ | (3,491,000) | | | $ | 5,791,000 | | | $ | (5,430,000) | |
11.12. ACCUMULATED OTHER COMPREHENSIVE LOSS
The changes in each component of accumulated other comprehensive loss were as follows:
| | | Three months ended
December 31, | | Three months ended
June 30, | | Nine months ended
June 30, |
| | | 2020 | | 2019 | | 2021 | | 2020 | | 2021 | | 2020 |
| Foreign currency translation: | Foreign currency translation: | | | | Foreign currency translation: | | | | | | | |
| Beginning accumulated foreign currency translation | Beginning accumulated foreign currency translation | $ | 545,000 | | | $ | 691,000 | | Beginning accumulated foreign currency translation | $ | 226,000 | | | $ | 780,000 | | | $ | 545,000 | | | $ | 691,000 | |
| Change in cumulative translation adjustment before reclassifications | Change in cumulative translation adjustment before reclassifications | (234,000) | | | 5,000 | | Change in cumulative translation adjustment before reclassifications | (74,000) | | | (125,000) | | | (393,000) | | | (36,000) | |
| | Income taxes | Income taxes | 0 | | | 0 | | Income taxes | 0 | | | 0 | | | 0 | | | 0 | |
| Net current period other comprehensive (loss) income | (234,000) | | | 5,000 | | |
| Net current period other comprehensive loss | | Net current period other comprehensive loss | (74,000) | | | (125,000) | | | (393,000) | | | (36,000) | |
| Ending accumulated foreign currency translation | Ending accumulated foreign currency translation | 311,000 | | | 696,000 | | Ending accumulated foreign currency translation | 152,000 | | | 655,000 | | | 152,000 | | | 655,000 | |
| Retirement plans: | Retirement plans: | | | | Retirement plans: | | | | | | | |
| Beginning accumulated retirement plans benefit cost | Beginning accumulated retirement plans benefit cost | (1,980,000) | | | (3,608,000) | | Beginning accumulated retirement plans benefit cost | (1,914,000) | | | (949,000) | | | (1,980,000) | | | (3,608,000) | |
| Amortization of net actuarial loss and prior service cost | Amortization of net actuarial loss and prior service cost | 33,000 | | | 60,000 | | Amortization of net actuarial loss and prior service cost | 26,000 | | | 20,000 | | | 92,000 | | | 100,000 | |
| Net actuarial gains arising during the period | Net actuarial gains arising during the period | 0 | | | 2,579,000 | | Net actuarial gains arising during the period | 0 | | | 0 | | | 0 | | | 2,579,000 | |
| Gain on termination of post-retirement medical plan | | Gain on termination of post-retirement medical plan | 541,000 | | | 0 | | | 541,000 | | | 0 | |
| Income taxes | Income taxes | 0 | | | 0 | | Income taxes | 0 | | | 0 | | | 0 | | | 0 | |
| Net current period other comprehensive income | Net current period other comprehensive income | 33,000 | | | 2,639,000 | | Net current period other comprehensive income | 567,000 | | | 20,000 | | | 633,000 | | | 2,679,000 | |
| Ending accumulated retirement plans benefit cost | Ending accumulated retirement plans benefit cost | (1,947,000) | | | (969,000) | | Ending accumulated retirement plans benefit cost | (1,347,000) | | | (929,000) | | | (1,347,000) | | | (929,000) | |
| Accumulated other comprehensive loss, net of taxes | Accumulated other comprehensive loss, net of taxes | $ | (1,636,000) | | | $ | (273,000) | | Accumulated other comprehensive loss, net of taxes | $ | (1,195,000) | | | $ | (274,000) | | | $ | (1,195,000) | | | $ | (274,000) | |
The amortization of net actuarial loss and prior service cost 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 78 for additional details).
12.13. 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 significant Level 3 assumptions used in the calculation of estimated discounted cash flows included future commodity prices, projections of estimated quantities of oil and natural gas reserves, expectations for timing and amount of future development, operating and asset retirement costs, projections of future rates of production, expected recovery rates and risk adjusted discount rates.
Barnwell estimates the fair value of asset retirement obligations based on the projected discounted future cash outflows required to settle abandonment and restoration liabilities. Such an estimate requires assumptions and judgments regarding the existence of liabilities, the amount and timing of cash outflows required to settle the liability, what constitutes adequate restoration, inflation factors, credit adjusted discount rates, and consideration of changes in legal, regulatory, environmental and political environments. Abandonment and restoration cost estimates are determined in conjunction with Barnwell’s
reserve engineers based on historical information regarding costs incurred to abandon and restore similar 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.
13.14. DEBT
Paycheck Protection Program Loan
On April 28, 2020, the Company, as obligor, entered into a promissory note evidencing an unsecured loan in the approximate amount of $147,000 under the Paycheck Protection Program (“PPP”) pursuant to the Coronavirus Aid, Relief, and Economic Security Act (“CARES”) Act that was signed into law in March 2020. The note matureswas to mature two years after the date of the loan disbursement and bearswith interest at a fixed annual rate of 1%1.00%, and with the principal and interest payments deferred until ten months after the last day of the covered period. UnderIn April 2021, the terms of the CARES Act, as amendedCompany was notified by the Paycheck Protection Program Flexibility Actlender of 2020,our PPP loan that the entire PPP loan amount and related accrued interest was forgiven by the PPP, the Company can apply for and be granted forgiveness for all orSmall Business Administration. As a portionresult of the loan issued under the PPP and the loan is expected to be forgiven to the extent the proceeds are used in accordance with the PPP to cover payroll, mortgage interest, rent, and utility costs incurred byforgiveness, the Company overrecognized a gain on debt extinguishment of $149,000 during the 24-week period following the loan disbursement date. As of the date of this filing, the Company is in the process of applying for forgivenessthree and believes that its use of the loan proceeds will meet the conditions for forgiveness under the PPP and expects the loan to be recorded as income when legal forgiveness is obtained. As of December 31, 2020, the current and long-term portions of the loan were $81,000 and $66,000, respectively, and the current portion is included in “Other current liabilities” in the Company's Condensed Consolidated Balance Sheet.nine months ended June 30, 2021.
Canada Emergency Business Account Loan
DuringIn the quarter ended December 31, 2020, the Company’s Canadian subsidiary, Barnwell of Canada, received a loan of approximately $31,000 (CAD$40,000)CAD$40,000 (in Canadian dollars) under the Canada Emergency Business Account (“CEBA”) loan program for small businesses. In the quarter ended March 31, 2021, the Company applied for an increase to our CEBA loan and received an additional CAD$20,000 for a total loan amount received of CAD$60,000 ($47,000) under the program. The CEBA loan is interest-free with no principal payments required until December 31, 2022, after which the remaining loan balance is converted to a three year term loan at 5% annual interest paid monthly. If the Company repays 75%66.6% of the principal amount prior to December 31, 2022, there will be loan forgiveness of 25%33.3% up to a maximum of CAD$10,000.20,000.
14.15.STOCKHOLDERS' EQUITY (DEFICIT)
Share-based Compensation
2018 Equity Incentive Plan
The Company’s stock option plans are administered by the Compensation Committee of the Board of Directors. The stockholder-approved 2018 Equity Incentive Plan provides for the issuance of incentive stock options, nonstatutory stock options, stock options with stock appreciation rights, restricted stock, restricted stock units and performance units, qualified performance-based awards, and stock grants to employees, consultants and non-employee members of the Board of Directors. 800,000 shares of Barnwell common stock have been reserved for issuance and as of June 30, 2021, a total of 135,000 share options
remain available for grant.
Barnwell currently has a policy of issuing new shares to satisfy share option exercises when the optionee requests shares.
Equity-classified Awards
On February 9, 2021, the Board of Directors of the Company granted options to purchase 665,000 shares of common stock, 310,000 shares to independent directors and 355,000 shares to employees. 605,000 shares of the stock options granted have an exercise price equal to the closing market price of Barnwell’s stock on the date of grant of $3.33, vest annually over three years, and expire in ten years from the date of grant. 60,000 shares of the stock options granted have an exercise price of $3.66 (110% of the closing market price on the date of grant for options granted to affiliates), vest annually over three years, and expire in five years from the date of grant.
A summary of the activity in Barnwell’s equity-classified share options from October 1, 2020 through June 30, 2021 is presented below:
| | | | | | | | | | | | | | | | | | | | | | | |
| Options | Shares | | Weighted-
Average
Exercise Price | | Weighted-
Average
Remaining
Contractual Term | | Aggregate
Intrinsic Value |
| Outstanding at October 1, 2020 | 0 | | | $ | 0 | | | | | |
| Granted | 665,000 | | | 3.36 | | | | | |
| Exercised | 0 | | | 0 | | | | | |
| Expired/Forfeited | (50,000) | | | 3.33 | | | | | |
| Outstanding at June 30, 2021 | 615,000 | | | $ | 3.36 | | | 9.1 | | $ | 0 | |
| Exercisable at June 30, 2021 | 0 | | | $ | 0 | | | — | | | $ | 0 | |
The following assumptions were used in estimating the fair value of the equity-classified share options granted on February 9, 2021:
| | | | | | | | | | | |
| > 10% Owner-Employee | | Others |
| Number of shares | 60,000 | | 605,000 |
| Expected volatility | 127.4% | | 105.8% |
| Expected dividends | NaN | | NaN |
| Expected term (in years) | 3.5 | | 6.0 |
| Risk-free interest rate | 0.19% | | 0.82% |
| Expected forfeitures | NaN | | NaN |
| Fair value per share | $2.51 | | $2.70 |
The application of alternative assumptions could produce significantly different estimates of the fair value of share-based compensation, and consequently, the related costs reported in the Condensed Consolidated Statements of Operations.
Compensation cost for equity-classified awards is measured at the grant date based on the fair value of the award and is recognized as an expense over the requisite service period. As of June 30, 2021, the total remaining unrecognized compensation cost related to nonvested share options was $1,259,000, which is expected to be recognized over the weighted-average remaining requisite service period of 2.6 years. During the three and nine months ended June 30, 2021, the Company recognized total share-based compensation expense of $238,000 and $389,000, respectively. There was 0 share-based compensation expense recognized during the three and nine months ended June 30, 2020.
At The Market Offering
On March 16, 2021, the Company entered into a Sales Agreement (the “Sales Agreement”) with A.G.P./Alliance Global Partners (“A.G.P,”), with respect to the ATM pursuant to which the Company may offer and sell, from time to time, shares of its common stock, par value $0.50 per share, having an aggregate sales price of up to $25 million (subject to certain limitations at any time our public float remains under $75 million), through or to A.G.P as the Company’s sales agent or as principal. Sales of our common stock under the ATM, if any, will be made by any methods deemed to be “at the market offerings” as defined in Rule 415(a)(4) under the Securities Act, including sales made directly on the NYSE American, on any other existing trading market for our Common Stock, or to or through a market maker. Shares of common stock sold under the ATM are offered pursuant to the Company’s Registration Statement on Form S-3 (File No. 333-254365), filed with the Securities and Exchange Commission on March 16, 2021, and declared effective on March 26, 2021 (the "Registration Statement”), and the prospectus dated March 26, 2021, included in the Registration Statement.
The sale of shares under the ATM began in May 2021 and as of June 30, 2021, the Company sold 586,546 shares of common stock resulting in net proceeds of $1,860,000 after commissions and fees of $59,000. From July 1, 2021 to the date of this Quarterly Report, an additional 581,441 shares of common stock were sold resulting in net proceeds of $1,924,000 after commissions and fees of $64,000.
In connection with our ATM offering, the Company incurred approximately $577,000 of incremental costs, which include legal, accounting, and underwriting fees, of which $283,000 has been recorded in stockholders’ equity as a reduction of additional paid-in capital generated from the offering and $294,000 has been capitalized as a current asset and recorded in “Deferred offering costs” on the Company’s Condensed Consolidated Balance Sheet as of June 30, 2021.
16. 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 year ended September 30, 2019, 2 of the water wells drilled by the contract drilling segment for 1 customer were determined to not meet the contract specifications for plumbness. Subsequently, in the quarter ended March 31, 2020, the Company executed a separate five-year warranty agreement with the customer for 1 of the wells that did not meet plumbness. Under the terms of the agreement, if the lack of plumbness is determined to be the cause of a pump failure within the warranty
period, the Company would be obligated to replace the pump at no cost to the customer. If the Company is unable to replace the pump using industry-standard methods, or if there are 2 or more pump failures attributable to lack of plumbness within the five-year warranty period, the Company would be obligated to drill a new well at no cost to the customer. Negotiations with the customer are currently ongoing for the other well that the customer claims did not meet plumbness despite the fact that the independent consulting engineer for the job concluded that the most recent plumbness test, completed after the well was cased with casing cemented into place as per the contract, showed that the well meets the plumbness specifications of the contract. Management believes the degrees of deviation for both wells are not impactful to the performance of the submersible pumps that will be installed in those wells. Accordingly, no accruals have been recorded as of December 31, 2020June 30, 2021 as there is no probable or estimable contingent liability.
In July 2020, the Staff of the State of Hawaii’s Commission on Water Resource Management (“Commission”) circulated a draft of a proposed recommendation to the Commission under which the Company, the water utility, the water utility's independent hydrologist firm and the owner of the land on which the 2 aforementioned water wells were drilled would be assessed penalty fines because each of the wells were calculated to have been drilled beyond the depth permitted by the permit. The wells were drilled to a depth to penetrate certain layers of impermeable rock necessary to access the aquifer at the instructions and on the advice of the hydrologist hired by the owner of the well. The Company’s share of the proposed penalties and fines was originally calculated to approximately $1,200,000. Subsequently, the Staff of the Commission acknowledged that one well had not been drilled to a depth beyond its permitted depth and the fines on that well were eliminated. Additionally, the fines applicable to the depth of the second well were dropped in lieu of the parties entering into an agreement to turnperform a water quality study and repurpose a current well into a monitoring well. The Commission and the aforementioned four parties have worked on this proposed alternative whereby the named parties would be responsible for providing the Commission with assistance to monitor the aquifer, at no cost to the Commission, to aid in the Commission’s efforts to monitor water quality in the subject area. The Company and the other three parties are currently evaluating proposals that it believes would likely satisfy the Commission's request under the proposed alternative settlement but it is currently uncertain as to whether or not they will be acceptable to the Commission. Additionally, it is uncertain as to how the cost of the alternative settlement would be allocated to the named parties of the subject violations. Accordingly, the Company recorded a contingent liability of approximately $300,000 at September 30, 2020 and there has been no change to the accrual as of December 31, 2020. June 30, 2021.
15.17. INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
| | | | | | | | | | | |
| | Nine months ended
June 30, |
| | 2021 | | 2020 |
| Supplemental disclosure of cash flow information: | | | |
| Cash paid (received) during the year for: | | | |
| | | |
| Income taxes refunded, net | $ | (290,000) | | | $ | (166,000) | |
| Supplemental disclosure of non-cash investing and financing activities: | | | |
| Canadian income tax withholdings on proceeds from the sale of oil and natural gas properties | $ | 72,000 | | | $ | 0 | |
| Accrued offering costs included in deferred offering costs, additional paid-in capital, and accounts payable | $ | 453,000 | | | $ | 0 | |
Capital expenditure accruals related to oil and natural gas exploration and development decreased $225,000$7,000 during the threenine months ended December 31, 2020June 30, 2021 and increased $1,661,000$635,000 during the threenine months ended December 31, 2019.June 30, 2020. Additionally, capital expenditure accruals related to oil and natural gas asset retirement obligations decreased $176,000increased $463,000 and $545,000 during the threenine months ended December 31,June 30, 2021 and 2020, and increased $323,000 during the three months ended December 31, 2019.respectively.
16.18. 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 5.4.
During the threenine months ended December 31, 2020,June 30, 2021, Barnwell received $485,000$1,738,000 in percentage of sales payments from KD I1 from the sale of 28 single-family lots within Phase II of Increment I. No lots were sold during the threenine months ended December 31, 2019.June 30, 2020.
Colin R. O'Farrell, a member of the Board of Directors of the Company effective July 12, 2021, is the sole member of Four Pines Operating LLC which owns a 25% interest in Gros Ventre. In February 2021, Gros Ventre and BOK, a wholly-owned subsidiary of Barnwell, entered into the Agreement of Teton Barnwell, an entity formed for the purpose of directly investing in oil and natural gas exploration and development in Oklahoma. Under the terms of the Agreement, Gros Ventre makes no capital contributions and receives 2% of the profits of Teton Barnwell. Additionally, as the manager of Teton Barnwell, Gros Venture 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.
17.19. SUBSEQUENT EVENTS
In January 2021, the Company entered into a cooperation and support agreement with MRMP-Managers LLC, Ned L. Sherwood Revocable Trust, Ned L. Sherwood and Bradley M. Tirpak (collectively, the “MRMP Stockholders”), with respect to the potential proxy contest pertaining to the election of directors to our Board of Directors (the “Board”). Pursuant to the terms of the agreement, among other things, the Company will nominate its current slate of directors, which includes three of the MRMP nominees and two new independent directors elected in 2020, to stand for reelection to the Board at the upcoming 2021 annual meeting of stockholders. The MRMP Stockholders have agreed to withdraw their proposed slate of directors and to vote their shares of common stock of the Company in favor of the election of the designated slate. In exchange for this arrangement, the Company has agreed to reimburse the MRMP Stockholders for their reasonable, documented out-of-pocket fees and expenses (including legal expenses) in connection with the MRMP Stockholders’ election contest at the Company’s 2020 annual meeting of stockholders and the negotiation of this agreement incurred through the filing of an amended Schedule 13D promptly after the date of this agreement, in an amount not to exceed $300,000 in the aggregate. One-half of such expenses shall be paid promptly following the execution of the agreement and one-half of such expenses shall be paid within ninety (90) days of the date of the agreement. The financial statement impacts of this agreement will be reflected in the Company’s quarter ending March 31, 2021.Kukio Resort Land Development Partnerships
Additionally, in JanuarySubsequent to June 30, 2021, Barnwell received a net cash distributiondistributions in the amount of $199,000$683,000 from the Kukio Resort Land Development Partnerships. Financial results of this distribution will be reflected in Barnwell's quarter ending March 31,September 30, 2021.
On February 9,Oil and Natural Gas Property Dispositions
Subsequent to June 30, 2021, 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 BoardSpirit River area of DirectorsAlberta, Canada. The sales price per the agreement was adjusted for customary purchase price adjustments to $1,047,000 in order to, among other things, reflect an economic effective closing date of sale of July 8, 2021. $524,000 of the Company granted optionssales proceeds was withheld for remittance by the buyers to purchase 665,000the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes related to the sale. Barnwell expects to report a gain on this transaction which will be recognized in its quarter ending September 30, 2021.
At The Market Offering
From July 1, 2021 to the date of this Quarterly Report, an additional 581,441 shares of common stock 310,000 shares to independent directorswere sold under the ATM resulting in net proceeds of $1,924,000 after commissions and 355,000 shares to employees. 605,000 sharesfees of the stock options granted have an exercise price equal to the closing market price of Barnwell’s stock on the date of grant of $3.33, vest annually over three years, and expire in ten years from the date of grant. 60,000 shares of the stock options granted have an exercise price of $3.66 (110% of the closing market price on the date of grant for options granted to affiliates), vest annually over three years, and expire in five years from the date of grant.
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 Annual Report on Form 10-K for the year ended September 30, 2020. 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 Annual Report on Form 10-K, as amended by our Form 10-K/A Amendment No. 1,No.1, for the fiscal year ended September 30, 2020. There have been no significant changes to these critical accounting policies and estimates during the three and nine months ended December 31, 2020.June 30, 2021. We continue to monitor our accounting policies to ensure proper application of current rules and regulations.
Current Outlook
Impact of COVID-19
In March 2020, the World Health Organization declared the COVID-19 outbreak a global pandemic and the United States and Canadian governments declared the virus a national emergency shortly thereafter. As a result,The ongoing global health crisis (including resurgences) resulting from the pandemic have, and may continue to, disrupt the normal operations of many businesses, have been disrupted, including the temporary closure or scale-back of business operations and/or the imposition of either quarantine or remote work or meeting requirements for employees, either by government order or on a voluntary basis. While the outbreak recently appeared to be trending downward, the emergence of new variants of COVID-19, including the highly transmissible Delta variant, has spread throughout the U.S. and globally and caused
significant uncertainty. The global economy, our markets and our business have been, and may continue to be, materially and adversely affected by COVID-19.
The COVID-19 outbreak has causedmaterially and continues to cause significant reductions inadversely affected our business operations and financial condition as a result of the deteriorating market outlook, the global economic recession and weakened liquidity. Although demand for oil and oil prices which has causedrecovered from the Company to suspendlows of March through May of the development of proved undeveloped reserves andprior year, uncertainty regarding future oil prices has impacted and continues to impact the Company’s financial condition and outlook. While the Company’s contract drilling segment remained operational throughout fiscal 2020 and continues to work, the continuing potential impact of COVID-19 on the health of our contract drilling segment's crews and ability or desire for customers to continue such work is uncertain, and any discontinuation of contracts currently in backlog would result in a material adverse impact to the Company’s financial condition and outlook. Though availability of vaccines and reopening of state and local economies has improved the outlook for recovery from COVID-19's impacts, the impact of the Delta variant or other new, more contagious or lethal variants that may emerge, the effectiveness of COVID-19 vaccines against the Delta variant or such other variants and the related responses by governments, including reinstated government-imposed lockdowns or other measures, cannot be predicted at this time. Both the health and economic aspects of the COVID-19 pandemic remain highly fluid and the future course of each is uncertain. We cannot foresee whether the outbreak of COVID-19 will be effectively contained on a sustained basis, nor can we predict the severity and duration of its impact. If the outbreak of COVID-19 is not effectively and timely controlled on a sustained basis going forward, our business operations and financial condition may continue to be materially and adversely affected as a result of the deteriorating market outlook, the global economic recession, weakened liquidity orby factors that we cannot foresee. Any of these factors and other factors beyond our control could have an adverse effect on the overall business environment, cause uncertainties in the regions where we conduct business, cause our business to suffer in ways that we cannot predict and materially and adversely impact our business, financial condition and results of operations.
Going Concern
The accompanying condensed consolidated financial statements have been prepared on a going concern basis, which contemplates the realization of assets and satisfaction of liabilities in the normal course of business for the twelve-month period following the date of issuance of these condensed consolidated financial statements.
Our ability to sustain our business in the future will depend on sufficientthe sufficiency of our cash on hand, oil and natural gas operating cash flows, which are highly sensitive to volatile oil and natural gas prices, sufficient contract drilling operating cash flows, which are subject to large changes in demand, and sufficient future land investment segment proceeds and distributions from the Kukio Resort Land Development Partnerships, the timing of which are both highly uncertain and not within Barnwell’s control. A sufficient level of such cash and cash inflows are necessary to fund discretionary oil and natural gas capital expenditures, which must be economically successful to provide sufficient returns, as well as fund our non-discretionary outflows such as oil and natural gas asset retirement obligations and ongoing operating and general and administrative expenses.
We have experienced In addition, as discussed in the "Asset Retirement Obligation" section of "Liquidity and Capital Resources," a trendsignificant amount of losses and negative operating cash flows in three of the last four years. Duefunds will be required to uncertainties regarding oil prices and the continuing impacts and uncertainties of the COVID-19 pandemic, we now face a greater uncertainty about our cash inflows as described above, which in turn leads to substantial doubt regarding our ability to make the required discretionary cash outflows for the capital expenditures necessary to convert our proved undeveloped reserves to proved developed reserves. Furthermore, because of the greater uncertainty about our cash inflows described above, there is substantial doubt about our abilitybe put on deposit with Canadian regulatory authorities to fund our non-discretionary cash outflowsabandonments at the Company's oil and thus substantial doubt about our ability to continue as a going concern for one year fromnatural gas properties in the date of the filing of this report.
Prior toManyberries area. Other sources and during fiscal 2021, the Company investigated potential sources of funding including non-core oil and natural gas property sales, however, no probable sources of such funding have yet been secured. Additionally, in fiscal 2020, theare discussed below.
The Company listed its corporate office on the 29th floor of a commercial office building in downtown Honolulu, Hawaii for sale to generate liquidity in order to help mitigate the substantial doubt about our ability to continue as a going concern. However,The corporate office is currently under a purchase and
sales contract with a buyer with a tentative closing to occur prior to September 30, 2021. While the Company believes the likelihood of the sale occurring as per the terms of the contract is more likely than not, the Company’s ability to successfully consummate the sale cannot be assured.
On March 16, 2021, the Company initiated an at-the-market offering program (“ATM”) pursuant to which the Company may offer and sell, from time to time, shares of its corporate office atcommon stock under price and volume guidelines set by the Company's Board of Directors and the terms and conditions described in the Registration Statement. The sale of shares under the ATM began in May 2021 and as of June 30, 2021, the Company sold 586,546 shares of common stock resulting in net proceeds of $1,860,000 after commissions and fees of $59,000. From July 1, 2021 to the date of this Quarterly Report, an appropriate time oradditional 581,441 shares of common stock were sold resulting in net proceeds of $1,924,000 after commissions and fees of $64,000.
In April 2021, the Company re-initiated the marketing of its non-core oil and natural gas properties in the Spirit River, Wood River, Medicine River, Kaybob, Bonanza, Balsam and Thornbury areas for sale. Subsequent to June 30, 2021, Barnwell entered into and completed a sufficientpurchase and sale agreement with an independent third party and sold its interests in certain natural gas and oil properties located in the Spirit River area of Alberta, Canada. The sales price is outsideper the agreement was adjusted for customary purchase price adjustments to $1,047,000 in order to, among other things, reflect an economic effective closing date of sale of July 8, 2021. $524,000 of the Company's control and is therefore not probable. Because of this uncertainty as well assales proceeds was withheld for remittance by the continuing uncertaintiesbuyers to the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes related to the sale. Negotiations regarding the potential durationsales of other non-core oil and depthnatural gas properties is ongoing, however there is no assurance that the sale of any of the other non-core properties will occur.
We have experienced a trend of losses and negative operating cash flows in three of the last four years. During fiscal 2020 and 2021, continuing uncertainties regarding the impacts of the COVID-19 pandemic on our business and the sufficiency of our cash balances and future cash inflows as described above raised substantial doubt about our ability to meet our estimated cash outflows or continue as a going concern for one year from the date of the filing of this report exists.
report. However, due to the $3,784,000 of funds raised by the ATM through the date of this Quarterly Report, as well as the $3,965,000 of net cash inflows in the quarter ended June 30, 2021 from land segment percentage of sales proceeds and distributions from the Kukio Resort Land Development Partnerships, such substantial doubt has been overcome.
Impact of Recently Issued Accounting Standards on Future Filings
In June 2016, the FASB issued 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. This ASU is effective for annual reporting periods beginning after December 15, 2022, and interim periods within those annual periods. The FASB has subsequently issued other related ASUs which amend ASU 2016-13 to provide clarification and additional guidance. The Company is currently evaluating the impact of these standards.
In August 2018, the FASB issued ASU No. 2018-14, “Compensation - Retirement Benefits-Defined Benefit Plans - General: Disclosure Framework-Changes to the Disclosure Requirements for Defined Benefit Plans,” which provides changes to certain pension and postretirementpost-retirement plan disclosures. This ASU is effective for annual reporting periods ending after December 15, 2020, with early adoption
permitted. The adoption of this update is not expected to have a material impact on Barnwell's consolidated financial statements.
In December 2019, the FASB issued ASU No. 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes,” which enhances and simplifies various aspects of the income tax accounting guidance in ASC 740. This ASU is effective for annual reporting periods beginning after December 15, 2020 and interim periods within those annual periods, with early adoption permitted. The adoption of this update is not expected to have a material impact 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 Oklahoma (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 such exploratory and developmental operations elsewhere. Additionally, through its wholly-owned subsidiary BOK, Barnwell is indirectly involved in several oil and natural gas investments in Oklahoma.
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 approximately 870 acres of the Kaupulehu Lot 4A area located in the North Kona District of the island of Hawaii. Kaupulehu
Developments is entitled to receive payments from KD I based on the following percentages of the gross receipts from KD I’s sales at Increment I: 10% of such aggregate gross proceeds greater than $100,000,000 up to $300,000,000; and 14% of such aggregate gross proceeds in excess of $300,000,000. Increment I is an area zoned for approximately 80 single-family lots, of which 15nine remained to be sold at December 31, 2020,June 30, 2021, and a beach club on the portion of the property bordering the Pacific Ocean, and is partially developed.
•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 now also obligated to pay an amount equal to 0.72% and 0.20% of the cumulative net profits of KD II to KD Development, LLC and a pool of various individuals, respectively, all of whom are partners of KKM and are unrelated to Barnwell. The remaining acreage within Increment II is not yet under development, and there is no assurance that development of such acreage will in fact occur.
•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 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 as well as from commissioncommissions on real estate sales by the real estate sales office.office and revenues resulting from the sale of private club memberships.
•Approximately 1,000 acres of vacant leasehold land zoned conservation in the Kaupulehu Lot 4C area located adjacent to the 870-acre Lot 4A described above, which currently has no development potential without both a development agreement with the lessor and zoning reclassification.
Contract Drilling Segment
Barnwell 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.
Results of Operations
Summary
The net incomeearnings attributable to Barnwell for the three months ended December 31, 2020June 30, 2021 totaled $584,000, a $998,000 increase$4,978,000, an $8,434,000 improvement in operating results from a net loss of $414,000$3,456,000 for the three months ended December 31, 2019.June 30, 2020. The following factors affected the results of operations for the three months ended December 31, 2020June 30, 2021 as compared to the same period in the prior year:
•A $1,097,000 increase in equity in income from affiliates as a result of increased operating results of the Kukio Resort Land Development Partnerships;year period:
•A $485,000 increase in land investment segment operating results, before income taxes and non-controlling interests' share of such profits, due to the sale of two lots in the current period, whereas there were no lot sales in the same period in the prior year; and
•A $695,000 decrease$4,227,000 improvement in oil and natural gas segment operating results, before income taxes, due primarily to a ceiling test impairment of $630,000$2,689,000 in the currentprior year period, whereas there was no such ceiling test impairment in the current year period. Also contributing to the increase was a significant increase in oil and natural gas prices in the current period as compared to the same period in the prior year;
•A $3,459,000 increase in equity in income from affiliates as a result of increased operating results of the Kukio Resort Development Partnerships;
•A $1,253,000 increase in land investment segment operating results, before non-controlling interests’ share of such profits, due to the sale of six lots in the current period, whereas there were no lot sales in the same period in the prior year;
•A $2,341,000 gain recognized in the current year period from the termination of the Company's Post-retirement Medical plan;
•A $1,190,000 decrease in contract drilling operating results, before income taxes, primarily resulting from decreased activity attributable to a significant well drilling contract as this contract was essentially completed as of December 31, 2020; and
•A $979,000 increase in general and administrative expenses primarily due to increases in compensation costs and accrued bonuses, share-based compensation expense, and professional fees in the current year period as compared to the same period in the prior year.
The net earnings attributable to Barnwell for the nine months ended June 30, 2021 totaled $4,706,000, a $10,090,000 improvement in operating results from a net loss of $5,384,000 for the nine months ended June 30, 2020. The following factors affected the results of operations for the nine months ended June 30, 2021 as compared to the prior year period:
•A $5,775,000 improvement in oil and natural gas segment operating results, before income taxes, primarily attributable to a decrease in the ceiling test impairment which was $4,326,000 in the prior year period, compared to a ceiling test impairment of $630,000 in the current year period. Also contributing to the increase was a significant increase in oil and natural gas prices in the current period as compared to the same period in the prior year;
•A $5,205,000 increase in equity in income from affiliates as a result of increased operating results of the Kukio Resort Development Partnerships;
•A $1,738,000 increase in land investment segment operating results, before non-controlling interests’ share of such profits, due to the sale of eight lots in the current period, whereas there were no lot sales in the same period in the prior year;
•A $2,341,000 gain recognized in the current year period from the termination of the Company's Post-retirement Medical plan;
•An $2,063,000 decrease in contract drilling segment operating results, before income taxes, primarily resulting from decreased activity attributable to a significant well drilling contract as this contract was essentially completed as of December 31, 2020;
•A $565,000 increase in general and administrative expenses primarily due to increases in accrued bonuses, share-based compensation expense, and costs related to the cooperation and support agreement with the MRMP Stockholders in the current year period as compared to the same period in the prior year, partially offset by a reduction in professional fees in the current year period as compared to the same period in the prior year; and
•A $1,336,000 gain recognized in the prior year period from the sale of the Company's leasehold interest in a three-quarter of an acre contract drilling segment maintenance and storage yard in Honolulu, Hawaii, whereas there was no such gain in 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.
The average exchange rate of the Canadian dollar to the U.S. dollar increased 1%13% and 7% in the three and nine months ended December 31, 2020June 30, 2021, respectively, as compared to the same periodperiods in the prior year, and theyear. The exchange rate of the Canadian dollar to the U.S. dollar increased 4%7% at December 31, 2020June 30, 2021, as compared to September 30, 2020. 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. Barnwell’s Canadian dollar assetsliabilities are greater than its Canadian dollar liabilities;assets; therefore, increases or decreases in the value of the Canadian dollar to the U.S. dollar generate other comprehensive incomeloss or loss,income, respectively. Other comprehensive income and losses are not included in net earnings (loss).and net loss. Other comprehensive loss due to foreign currency translation adjustments, net of taxes, for the three months ended December 31, 2020June 30, 2021 was $234,000,$74,000, a $239,000$51,000 change from other comprehensive incomeloss due to foreign currency translation adjustments, net of taxes, of $5,000$125,000 for the same period in the prior year. Other comprehensive loss due to foreign currency translation adjustments, net of taxes, for the nine months ended June 30, 2021 was $393,000, a $357,000 change from other comprehensive loss due to foreign currency translation adjustments, net of taxes, of $36,000 for the same period in the prior year. There were no taxes on other comprehensive income (loss)loss due to foreign currency translation adjustments in the three and nine months ended December 31,June 30, 2021 and 2020 and 2019 due to a full valuation allowance on the related deferred tax assets.asset.
Oil and natural gasNatural Gas
The following tables set forth Barnwell’s average prices per unit of production and net production volumes. Production amounts reported are net of royalties.
| | | | | | | | | | | | | | | | | | | | | | | |
| | Average Price Per Unit |
| | Three months ended | | Increase |
| | December 31, | | (Decrease) |
| | 2020 | | 2019 | | $ | | % |
| Natural Gas (Mcf)* | $ | 2.12 | | | $ | 1.84 | | | $ | 0.28 | | | 15 | % |
| Oil (Bbls)** | $ | 35.48 | | | $ | 48.76 | | | $ | (13.28) | | | (27 | %) |
| Liquids (Bbls)** | $ | 21.96 | | | $ | 18.71 | | | $ | 3.25 | | | 17 | % |
| | | | Net Production | | Average Price Per Unit |
| | | Three months ended | | Increase | | Three months ended | | Increase |
| | | December 31, | | (Decrease) | | June 30, | | (Decrease) |
| | | 2020 | | 2019 | | Units | | % | | 2021 | | 2020 | | $ | | % |
| Natural Gas (Mcf)* | Natural Gas (Mcf)* | 171,000 | | | 168,000 | | | 3,000 | | | 2 | % | Natural Gas (Mcf)* | $ | 2.70 | | | $ | 1.42 | | | $ | 1.28 | | | 90 | % |
| Oil (Bbls)** | Oil (Bbls)** | 39,000 | | | 35,000 | | | 4,000 | | | 11 | % | Oil (Bbls)** | $ | 61.31 | | | $ | 17.24 | | | $ | 44.07 | | | 256 | % |
| Liquids (Bbls)** | Liquids (Bbls)** | 6,000 | | | 5,000 | | | 1,000 | | | 20 | % | Liquids (Bbls)** | $ | 36.17 | | | $ | 4.67 | | | $ | 31.50 | | | 675 | % |
| | | | | | | | | | | | | | | | | | | | | | | |
| | Average Price Per Unit |
| | Nine months ended | | Increase |
| | June 30, | | (Decrease) |
| | 2021 | | 2020 | | $ | | % |
| Natural Gas (Mcf)* | $ | 2.47 | | | $ | 1.62 | | | $ | 0.85 | | | 52 | % |
| Oil (Bbls)** | $ | 48.49 | | | $ | 33.62 | | | $ | 14.87 | | | 44 | % |
| Liquids (Bbls)** | $ | 29.82 | | | $ | 16.64 | | | $ | 13.18 | | | 79 | % |
| | | | | | | | | | | | | | | | | | | | | | | |
| | Net Production |
| | Three months ended | | Increase |
| | June 30, | | (Decrease) |
| | 2021 | | 2020 | | Units | | % |
| Natural Gas (Mcf)* | 185,000 | | | 125,000 | | | 60,000 | | | 48 | % |
| Oil (Bbls)** | 35,000 | | | 34,000 | | | 1,000 | | | 3 | % |
| Liquids (Bbls)** | 6,000 | | | 3,000 | | | 3,000 | | | 100 | % |
| | | | | | | | | | | | | | | | | | | | | | | |
| | Net Production |
| | Nine months ended | | Increase |
| | June 30, | | (Decrease) |
| | 2021 | | 2020 | | Units | | % |
| Natural Gas (Mcf)* | 531,000 | | | 480,000 | | | 51,000 | | | 11 | % |
| Oil (Bbls)** | 112,000 | | | 113,000 | | | (1,000) | | | (1 | %) |
| Liquids (Bbls)** | 17,000 | | | 14,000 | | | 3,000 | | | 21 | % |
* 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 $373,000 ofa $1,015,000 operating lossprofit before general and administrative expenses in the three months ended December 31, 2020, a decreaseJune 30, 2021, an increase in operating results of $695,000$4,227,000 as compared to the $3,212,000 operating loss before general and administrative expenses generated during the same period of the prior year. The oil and natural gas segment generated a $322,000$1,289,000 operating profit before general and administrative expenses in the nine months ended June 30, 2021, an increase in operating results of $5,775,000 as compared to the $4,486,000 operating loss before general and administrative expenses generated during the same period of the prior year. There was no ceiling test impairment during the three months ended June 30, 2021 and there was a $630,000 ceiling test impairment included in the operating loss inprofit for the current year, whereas there was nonine months ended June 30, 2021. The operating losses for the three months and nine months ended June 30, 2020 include a ceiling test impairment in the prior year period.of $2,689,000 and $4,326,000, respectively.
Oil and natural gas revenues decreased $254,000 (12%increased $2,057,000 (248%) and $2,445,000 (50%) for the three and nine months ended June 30, 2021, respectively, as compared to the same periods in the prior year, primarily due to significant increases in oil and natural gas prices as compared to the same periods in the prior as prior year's commodity prices were impacted by the COVID-19 pandemic.
Oil and natural gas operating expenses increased $736,000 (75%) for the three months ended December 31, 2020,June 30, 2021 as compared to the same period in the prior year primarily due to a 27% decreasethe temporary shut-in of wells with high operating costs in oilthe prior year period because of the low commodity prices which was partially offsetcaused by a 11%the COVID pandemic. Additionally, the increase in oil productionoperating expenses in the current period was due to the addition of new wells acquired in April 2021 in the Twining area, increases in workovers and electricity costs, and carbon taxes whereas there was no such costs in the prior year period. Oil and natural gas operating expenses increased $1,432,000 (41%) for the nine months ended June 30, 2021 as compared to the same period in the prior year. Oilyear, primarily due to equalization of operating costs related to processing facilities and natural gas operating expenses increased $222,000 (18%) forworkovers in the three months ended December 31, 2020, as comparedcurrent year period and to a lesser degree due to carbon taxes, whereas there were no such costs in the prior year period, primarilyas well as due to an increase in oil productionthe aforementioned lower operating costs in the currentprior year period. period due to low commodity prices.
Oil and natural gas segment depletion decreased $411,000$217,000 (58%) and $1,066,000 (68%) for the three and nine months ended December 31, 2020,June 30, 2021, respectively, as compared to the same periods in the prior year, period, primarily due to a decreasedecreases in the depletion raterates for the current year periods, as a result of ceiling testcompared to the same periods in prior year, due primarily to impairment write-downs in the prior fiscal year.
While oil prices have recovered somewhat from the significant lows of March through May of the prior year, the Company is unable to reasonably predict future oil prices and the impacts future oil prices will have on the Company.
Sale of interestInterest in leasehold landLeasehold Land
Kaupulehu Developments is 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
December 31, | | Three months ended
June 30, | | Nine months ended
June 30, |
| | | | 2020 | | 2019 | | 2021 | | 2020 | | 2021 | | 2020 |
| Sale of interest in leasehold land: | Sale of interest in leasehold land: | | | | | Sale of interest in leasehold land: | | | | | | | |
| Revenues – sale of interest in leasehold land | | $ | 485,000 | | | $ | — | | |
| Revenues - sale of interest in leasehold land | | Revenues - sale of interest in leasehold land | $ | 1,253,000 | | | $ | — | | | $ | 1,738,000 | | | $ | — | |
| Fees - included in general and administrative expenses | Fees - included in general and administrative expenses | | (59,000) | | | — | | Fees - included in general and administrative expenses | (153,000) | | | — | | | (212,000) | | | — | |
| Sale of interest in leasehold land, net of fees paid | Sale of interest in leasehold land, net of fees paid | | $ | 426,000 | | | $ | — | | Sale of interest in leasehold land, net of fees paid | $ | 1,100,000 | | | $ | — | | | $ | 1,526,000 | | | $ | — | |
During the three months ended December 31, 2020,June 30, 2021, Barnwell received $485,000$1,253,000 in percentage of sales payments from KD I from the sale of twosix single-family lots within Phase II of Increment I. During the nine months ended June 30, 2021, Barnwell received $1,738,000 in percentage of sales payments from KD I from the sale of eight single-family lots within Phase II of Increment I. No lots were sold during the three and nine months ended December 31, 2019.June 30, 2020.
As of December 31, 2020, 15June 30, 2021, nine single-family lots of the 80 lots developed within Increment I remained to be sold. The Company does not have a controlling interest in Increments I and II, and there is no assurance with regards to the amounts of future sales from Increments I and II, or that the remaining acreage within Increment II will be developed.
Contract drillingDrilling
Contract drilling revenues and contract drilling costs decreased $704,000 (27%$2,151,000 (71%) and $706,000 (39%$941,000 (48%), respectively, for the three months ended December 31, 2020,June 30, 2021, as compared to the same period in the prior year. The contract drilling segment generated a $758,000$213,000 operating profitloss before general and administrative expenses in the three months ended December 31, 2020, an increaseJune 30, 2021, a decrease in operating results of $11,000$1,190,000 as compared to a $747,000the $977,000 operating profit generated during the same period of the prior year.
Contract drilling revenues and contract drilling costs decreased $4,059,000 (49%) and $1,953,000 (35%), respectively, for the nine months ended June 30, 2021, as compared to the same period in the prior
year. The contract drilling segment generated a $392,000 operating profit before general and administrative expenses in the nine months ended June 30, 2021, a decrease in operating results of $2,063,000 as compared to the $2,455,000 operating profit generated during the same period of the prior year.
The decreasedecreases in contract drilling revenues and contract drilling costs for the three and nine months ended December 31, 2020June 30, 2021 as compared to the same periodperiods in the prior year is primarily due to a significant well drilling contract in the prior year period.periods. The significant well drilling contract was for multiple wells and was based on a fixed rate per day or fixed rate per hour, depending upon the activity, as opposed to the Company's typical contracts that are based on a fixed price per lineal foot drilled. Up to three drilling rigs were being used at this job during the prior year period with crews working extended hours. However, operational activity related to this contract has been winding downwas essentially completed in the quarter ended December 31, 2020 and thus contract drilling revenues and costs have decreased in the current year periodperiods as compared to the same periodperiods of the prior year. This significant well drilling contract was essentially complete as of December 31, 2020. Accordingly, contract drilling revenues and costs for the remaining quartersquarter of fiscal 2021 are expected to be lower as compared to the same periodsperiod in fiscal 2020.
In the quarter ended December 31, 2019, the Company experienced the failure of a hole opener which broke apart leaving pieces in the bottom of a water well being drilled in Hawaii. Efforts to remove the items from the well were unsuccessful through the quarter ended March 31, 2020 and subsequently the Company determined that the well should be abandoned and a new well drilled at no incremental cost to the customer as per the terms of the contract. Accordingly, all the costs to drill and abandon the first well, which are all wasted costs, were excluded from the measurement of progress toward contract completion and all such costs were fully accrued in the quarter ended March 31, 2020, as this contract was determined to be a loss job. In September 2020, while making progress towards the drilling of a replacement well in different location, the drill string twisted off and became lodged in the well borehole, which required a
stoppage of drilling and the need to dislodge and retrieve the broken drill string. Accordingly, the estimated total rework costs to remediate the situation was accrued at September 30, 2020. In January 2021, the broken drill string was retrieved from the well borehole and drilling of the replacement well recommenced.
In the year ended September 30, 2019, two of the water wells drilled by the contract drilling segment for one customer were determined to not meet the contract specifications for plumbness. Subsequently, in the quarter ended March 31, 2020, the Company executed a separate five-year warranty agreement with the customer for one of the wells that did not meet plumbness. Under the terms of the agreement, if the lack of plumbness is determined to be the cause of a pump failure within the warranty period, the Company would be obligated to replace the pump at no cost to the customer. If the Company is unable to replace the pump using industry-standard methods, or if there are two or more pump failures attributable to lack of plumbness within the five-year warranty period, the Company would be obligated to drill a new well at no cost to the customer. Negotiations with the customer are currently ongoing for the other well that the customer claims did not meet plumbness despite the fact that the independent consulting engineer for the job concluded that the most recent plumbness test, completed after the well was cased with casing cemented into place as per the contract, showed that the well meets the plumbness specifications of the contract. Management believes the degrees of deviation for both wells are not impactful to the performance of the submersible pumps that will be installed in those wells. Accordingly, no accruals have been recorded as of December 31, 2020June 30, 2021 as there is no probable or estimable contingent liability.
In July 2020, the Staff of the State of Hawaii’s Commission on Water Resource Management (“Commission”) circulated a draft of a proposed recommendation to the Commission under which the Company, the water utility, the water utility's independent hydrologist firm and the owner of the land on which the two aforementioned water wells were drilled would be assessed penalty fines because each of the wells were calculated to have been drilled beyond the depth permitted by the permit. The wells were drilled to a depth to penetrate certain layers of impermeable rock necessary to access the aquifer at the instructions and on the advice of the hydrologist hired by the owner of the well. The Company’s share of the proposed penalties and fines was originally calculated to approximately $1,200,000. Subsequently, the Staff of the Commission acknowledged that one well had not been drilled to a depth beyond its permitted depth and the fines on that well were eliminated. Additionally, the fines applicable to the depth of the second well were dropped in lieu of the parties entering into an agreement to turnperform a water quality study and repurpose a current well into a monitoring well. The Commission and the aforementioned four parties have worked on this proposed alternative whereby the named parties would be responsible for providing the Commission with assistance to monitor the aquifer, at no cost to the Commission, to aid in the Commission’s efforts to monitor water quality in the subject area. The Company and the other three parties are currently evaluating proposals that it believes would likely satisfy the Commission's request under the proposed alternative settlement but it is currently uncertain as to whether or not they will be acceptable to the Commission. Additionally, it is uncertain as to how the cost of the alternative settlement would be allocated to the named parties of the subject violations. Accordingly, the Company recorded a contingent liability of approximately $300,000 at September 30, 2020 and no subsequent accruals have been recorded as of December 31, 2020.June 30, 2021.
There has been a significant decrease in demand for water well drilling contracts in recent years that has generally led to increased competition for available contracts and lower margins on awarded contracts. The Company is unable to predict the near-term and long-term availability of water well drilling and pump installation and repair contracts as a result of this volatility in demand. While the Company’s contract drilling segment remained operational throughout fiscal 2020 and continues to work, the continuing potential impact of COVID-19 on the health of our contract drilling segment's crew and ability or desire for
customers to continue such work is uncertain, and any discontinuation of contracts currently in backlog for any reason would result in a material adverse impact to the Company’s financial condition and outlook.
General and administrative expensesAdministrative Expenses
General and administrative expenses decreased $311,000 (21%increased $979,000 (78%) for the three months ended December 31, 2020,June 30, 2021 as compared to the same period in the prior year. The decreaseincrease was primarily due to a decreaseincreases in compensation costs and accrued bonuses, share-based compensation expense, and professional fees related to auditland investment segment proceeds and legal services in the current year period as compared to the same period in the prior year period.year. General and administrative expenses increased $565,000 (12%) for the nine months ended June 30, 2021 as compared to the same period in the prior year. The decreaseincrease was partially offset by increasedprimarily due to increases in accrued bonuses, share-based compensation expense, professional fees related to land investment segment proceeds, and costs related to the cooperation and support agreement with the MRMP Stockholders as discussed below, in the current year period as compared to the same period in the prior year. The increase was partially offset by a reduction in professional fees related to audit services, legal services, proxy solicitation, proxy advisory, and public relation costs in the current year period as compared to the same period in the prior year.
In January 2021, the Company entered into a cooperation and support agreement with MRMP-Managers LLC, Ned L. Sherwood Revocable Trust, Ned L. Sherwood and Bradley M. Tirpak (collectively, the “MRMP Stockholders”), with respect to the potential proxy contest pertaining to the election of directors to our Board of Directors. Pursuant to the terms of the agreement, among other things, the Company and the MRMP Stockholders agreed on certain nominations and voting with respect to the directors nominated to stand for reelection to the Board of Directors at the 2021 annual meeting of stockholders, which was held on April 20, 2021. The Company agreed to reimburse the MRMP Stockholders for their reasonable, documented out-of-pocket fees and expenses (including legal expenses) of up to a maximum of $300,000 in connection with the MRMP Stockholders’ election contest at the
Company’s 2020 annual meeting of stockholders and the negotiation of this agreement. Accordingly, the Company incurred approximately $296,000 in expenses related to this agreement in the nine months ended June 30, 2021.
Depletion, depreciation,Depreciation, and amortizationAmortization
Depletion, depreciation, and amortization decreased $429,000$243,000 (51%) and $1,132,000 (61%) for the three and nine months ended December 31, 2020,June 30, 2021, respectively, as compared to the same periodperiods in the prior year, primarily due to a decrease in the oil and natural gas depletion raterates as a result of ceiling test impairment write-downs in the prior fiscal year as discussed in the “Oil and natural gas” section above.
Impairment of assetsAssets
Under the full cost method of accounting, the Company performs quarterly oil and natural gas ceiling test calculations. There was a $630,000 ceiling test impairment during the three months ended December 31, 2020. There was no ceiling test impairment during the three months ended December 31, 2019.June 30, 2021 and there was a $630,000 ceiling test impairment during the nine months ended June 30, 2021. There was a ceiling test impairment of $2,689,000 and $4,326,000 during the three and nine months ended June 30, 2020, respectively.
Changes in the mandated 12-month historical 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 estimated market value of unproved properties, impact the determination of the maximum carrying value of oil and natural gas properties. The ceiling test calculation at December 31, 2019 included management’s estimation that
Gain on Termination of Post-retirement Medical Plan
In June 2021, the Company had the ability to fund allterminated its Post-retirement Medical plan, which covered officers of the future capital expenditures necessary overCompany who had attained at least 20 years of service of which at least 10 years were at the next five years to develop proved undeveloped reserves in the Twining areaposition of Alberta, Canada. However, due to the impact on oil pricesVice President or higher, their spouses and qualifying dependents, effective June 4, 2021. The Post-retirement Medical plan was an unfunded plan and the extreme uncertainties created byCompany funded benefits when payments were made. As result of the COVID-19 pandemic on the Company's financial outlook, management is no longer reasonably certain thatplan termination, the Company will haverecognized a non-cash gain of $2,341,000 during the financial resources necessary to make anythree and nine months ended June 30, 2021.
Gain on Sale of the capital expenditures necessary to develop the proved undeveloped reserves. Therefore, the proved undeveloped reserves have been excluded from the quarterly ceiling test calculations subsequent to December 31, 2019.Asset
In March 2020, the Company sold its leasehold interest in a three-quarter of an acre contract drilling segment maintenance and storage yard in Honolulu, Hawaii to an unrelated third party for a $1,100,000 cash payment. As discussed above, the ceiling test mandates the usea result of the 12-month historical rolling average first-day-of-the-month prices. Ifsale transaction, the 12-month historical rolling average first-day-of-the-month prices declineCompany recognized a gain of $1,336,000, inclusive of a $236,000 gain from the 12-month historical rolling average first-day-of-the-month prices usedreversal of the storage yard's lease liability in excess of the right-of-use asset, in the December 31, 2020 ceiling calculation, the Company could incur further impairment write-downs in future periods in the absence of any offsetting factors that are not currently known or projected.
nine months ended June 30, 2020.
Equity in income (loss)Income (Loss) of affiliatesAffiliates
Barnwell’s investment in the Kukio Resort Land Development Partnerships is accounted for using the equity method of accounting. Barnwell was allocated partnership income of $1,054,000$3,348,000 and $5,026,000 during the three and nine months ended December 31, 2020,June 30, 2021, respectively, as compared to allocated losses of $43,000$111,000 and $179,000 during the three and nine months December 31, 2019.ended June 30, 2020, respectively. The increase in the allocated partnership income is primarily due to the Kukio Resort Land Development
Partnerships' sale of twoeight lots during the current year, period,of which six lots were sold in the quarter ended June 30, 2021, whereas there was no lot sales in the prior year period, as well asyear. In addition, there was a significant increase in real estate resale activity in the current year periodperiods for which the Kukio Resort Land Development Partnerships' real estate sales office earns commissions revenue. Additionally,revenue, as well as an increase in the Kukio Resort Land Development Partnerships' revenues related to an increase in club memberships sold. The increase is also attributed to distributions received from the Kukio Resort Land Development Partnerships in excess of our investment balance of $748,000 which was recorded as income during the three and nine months ended June 30, 2021 (see Note 4) and $459,000 in preferred return payments received from KKM in the nine months ended June 30, 2021, as discussed below.
Barnwell has the right to receive distributions from the Kukio Resort Land Development Partnerships via its its non-controlling interests in KD Kona and KKM, based on its respective partnership sharing ratios of 75% and 34.45%, respectively. Additionally, Barnwell was entitled to a preferred return from KKM on any allocated equity in income of the Kukio Resort Land Development Partnerships in excess of its partnership sharing ratio for cumulative distributions to all of its partners in excess of $45,000,000 from those partnerships. Cumulative distributions from the Kukio Resort Land Development Partnerships have reached the $45,000,000 threshold and in the quarter ended December 31, 2020, the Kukio Resort Land Development Partnerships made distributions in excess of the threshold out of the proceeds from the sale of two lots in Increment I. Accordingly, Barnwell received a total of $459,000 in preferred return payments, which is reflected as an additional equity pickup in the "Equity in income (loss) of affiliates" line item on the accompanying Condensed Consolidated Statement of Operations for the threenine months ended December 31, 2020.June 30, 2021. The preferred return payments received duringin the quarter ended December 31, 2020 brought the cumulative preferred return total to $656,000, which is the total amount Barnwell was entitled to, and thus there is no more preferred return outstanding as of December 31, 2020.June 30, 2021.
During the threenine months ended December 31, 2020,June 30, 2021, Barnwell received net cash distributions in the amount of $1,712,000$5,328,000 from the Kukio Resort Land Development Partnerships after distributing $155,000$599,000 to non-controlling interests. Of the $1,712,000$5,328,000 of net cash distributions received from the Kukio Resort Land Development Partnerships, $459,000 represented a payment of the preferred return from KKM, as discussed above. There were no cash distributions from the Kukio Resort Land Development Partnerships for the threenine months ended December 31, 2019.June 30, 2020.
Income taxesTaxes
Barnwell’s effective consolidated income tax rate, for the three months ended December 31, 2020, after adjusting earnings (loss) before income taxes for non-controlling interests, was 10%,4% and 6% for the three and nine months ended June 30, 2021, respectively, as compared to an effective income tax benefit rate of nil1% for the three months ended December 31, 2019.June 30, 2020 and nil for the nine months ended June 30, 2020.
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. 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.
Net earnings (loss) attributableEarnings (Loss) 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 $576,000 and $797,000 for the three and nine months ended December 31, 2020 totaled $159,000,June 30, 2021, respectively, as compared to net loss attributable to non-controlling interests of $5,000$11,000 and $20,000 for the same periodperiods in the prior year. The increasechanges of $164,000 is$587,000 (5,336%) and $817,000 (4,085%) for the three and nine months, respectively, are primarily due to percentage of sales proceeds received in the current period, whereas there were no percentage of sale proceeds received in the prior year period, and an increase in the amount of Kukio Resort Land Development Partnerships' income in the current year periodperiods as compared to the same periodperiods in the prior year. Additionally, the increases are also due to percentage of sales proceeds received in the current year periods, whereas there were no percentage of sale proceeds received in the prior year periods.
Liquidity and Capital Resources
Barnwell’s primary sources of liquidity are cash on hand, cash flow generated by operations, and land investment segment proceeds. At December 31, 2020,June 30, 2021, Barnwell had $5,370,000$8,335,000 in working capital.
Cash Flows
Cash flows provided by operating activitiesoperations totaled $80,000$2,105,000 for the threenine months ended December 31, 2020,June 30, 2021, as compared to cash flows used in operating activities of $1,366,000$472,000 for the same period in the prior year. This $1,446,000$1,633,000 change in operating cash flows was primarily due to distributions of income from the Kukio Resort Land Development Partnerships in the current year period, as compared to none in the same period of the prior year, and higher operating results, before non-cash impairment expenses, for the oil and natural gas segment, which was partially offset by significantly lower operating results for the contract drilling segment in the current year period as compared to the prior year period. The change was also due to fluctuations in working capital.capital in the current period as compared to the prior year period.
Cash flows provided by investing activities totaled $875,000$1,955,000 during the threenine months ended December 31, 2020,June 30, 2021, as compared to cash flows used in investing activities of $863,000$1,116,000 during the same period of the prior year. This $1,738,000$3,071,000 increase in investing cash flows was primarily due to a decrease of $1,080,000$1,605,000 in cash paid for oil and natural gas capital expenditures, a $426,000$1,526,000 increase in percentage of sales proceeds received, net of fees, and an increase of $813,000$1,649,000 received in distributions from equity investees in excess of earnings in the current year period as compared to none in the prior year period,period. These changes were partially offset by a $594,000$348,000 increase in payments to acquire oil and natural gas properties in the current year period, a $548,000 decrease in proceeds from the sale oil and natural gas properties in the current period as compared to the prior year period.period, and a decrease of $1,100,000 in proceeds from the sale of the Company's leasehold interest in a three-quarter of an acre contract drilling segment maintenance and storage yard in Honolulu, Hawaii, from sales in the prior year as compared to no sales of similar assets in the current year.
Cash flows used inNet cash provided by financing activities totaled $217,000 during$832,000 for the threenine months ended December 31, 2020. There was no cash flows from financing activitiesJune 30, 2021, as compared to $147,000 for the threenine months ended December 31, 2019.June 30, 2020. The $217,000$685,000 change in financing cash flows was primarily attributed to $248,000$1,736,000 in proceeds from issuance of stock, net of costs, related to the Company's ATM offering in the current year period as compared to none in the prior
year period, which was partially offset by $951,000 in distributions to non-controlling interests in the current year which was partially offset by an increase of $31,000period as compared to none in long-term debt borrowings attributed to the Canada Emergency Business Account Loan received duringsame period in the current year period.prior year.
Paycheck Protection Program Loan
On April 28, 2020, the Company, as obligor, entered into a promissory note evidencing an unsecured loan in the approximate amount of $147,000 under the Paycheck Protection Program (“PPP”) pursuant to the Coronavirus Aid, Relief, and Economic Security Act (“CARES”) Act that was signed into law in March 2020. The note matureswas to mature two years after the date of the loan disbursement and bearswith interest at a
fixed annual rate of 1%1.00%, and with the principal and interest payments deferred until ten months after the last day of the covered period. UnderIn April 2021, the terms of the CARES Act, as amendedCompany was notified by the Paycheck Protection Program Flexibility Actlender of 2020,our PPP loan that the entire PPP loan amount and related accrued interest was forgiven by the PPP, the Company can apply for and be granted forgiveness for all orSmall Business Administration. As a portionresult of the loan issued under the PPP and the loan is expected to be forgiven to the extent the proceeds are used in accordance with the PPP to cover payroll, mortgage interest, rent, and utility costs incurred byforgiveness, the Company overrecognized a gain on debt extinguishment of $149,000 during the 24-week period following the loan disbursement date. As of the date of this filing, the Company is in the process of applying for forgivenessthree and believes that its use of the loan proceeds will meet the conditions for forgiveness under the PPP and expects the loan to be recorded as income when legal forgiveness is obtained.nine months ended June 30, 2021.
Canada Emergency Business Account Loan
DuringIn the quarter ended December 31, 2020, the Company’s Canadian subsidiary, Barnwell of Canada, received a loan of approximately $31,000 (CAD$40,000)CAD$40,000 under the Canada Emergency Business Account (“CEBA”) loan program for small businesses. In the quarter ended March 31, 2021, the Company applied for an increase to our CEBA loan and received an additional CAD$20,000 for a total loan amount received of CAD$60,000 ($47,000) under the program. The CEBA loan is interest-free with no principal payments required until December 31, 2022, after which the remaining loan balance is converted to a three year term loan at 5% annual interest paid monthly. If the Company repays 75%66.6% of the principal amount prior to December 31, 2022, there will be loan forgiveness of 25%33.3% up to a maximum of CAD$10,000.20,000.
At The Market Offering
On March 16, 2021, the Company entered into a Sales Agreement with A.G.P., with respect to the ATM pursuant to which the Company may offer and sell, from time to time, shares of its common stock, par value $0.50 per share, having an aggregate sales price of up to $25 million (subject to certain limitations at any time our public float remains under $75 million), through or to A.G.P as the Company’s sales agent or as principal. Sales of our common stock under the ATM, if any, will be made by any methods deemed to be “at the market offerings” as defined in Rule 415(a)(4) under the Securities Act, including sales made directly on the NYSE American, on any other existing trading market for our Common Stock, or to or through a market maker. Shares of common stock sold under the ATM are offered pursuant to the Company’s Registration Statement on Form S-3 (File No. 333-254365), filed with the Securities and Exchange Commission on March 16, 2021, and declared effective on March 26, 2021 (the "Registration Statement”), and the prospectus dated March 26, 2021, included in the Registration Statement.
The sale of shares under the ATM began in May 2021 and as of June 30, 2021, the Company sold 586,546 shares of common stock resulting in net proceeds of $1,860,000 after commissions and fees of $59,000. From July 1, 2021 to the date of this Quarterly Report, an additional 581,441 shares of common stock were sold resulting in net proceeds of $1,924,000 after commissions and fees of $64,000.
Going Concern
The accompanying condensed consolidated financial statements have been prepared on a going concern basis, which contemplates the realization of assets and satisfaction of liabilities in the normal course of business for the twelve-month period following the date of issuance of these condensed consolidated financial statements.
Our ability to sustain our business in the future will depend on sufficientthe sufficiency of our cash on hand, oil and natural gas operating cash flows, which are highly sensitive to volatile oil and natural gas prices, sufficient contract drilling operating cash flows, which are subject to large changes in demand, and sufficient future land investment segment proceeds and distributions from the Kukio Resort Land Development Partnerships, the timing of which are both highly uncertain and not within Barnwell’s control. A sufficient level of such cash and cash inflows are necessary to fund discretionary oil and natural gas capital expenditures, which must be economically successful to provide sufficient returns, as well as fund our non-discretionary outflows such as oil and natural gas asset retirement obligations and ongoing operating and general and administrative expenses.
We have experienced In addition, as discussed in the "Asset Retirement Obligation" section of "Liquidity and Capital Resources," a trendsignificant amount of losses and negative operating cash flows in three of the last four years. Duefunds will be required to uncertainties regarding oil prices and the continuing impacts and uncertainties of the COVID-19 pandemic, we now face a greater uncertainty about our cash inflows as described above, which in turn leads to substantial doubt regarding our ability to make the required discretionary cash outflows for the capital expenditures necessary to convert our proved undeveloped reserves to proved developed reserves. Furthermore, because of the greater uncertainty about our cash inflows described above, there is substantial doubt about our abilitybe put on deposit with Canadian regulatory authorities to fund our non-discretionary cash outflowsabandonments at the Company's oil and thus substantial doubt about our ability to continue as a going concern for one year fromnatural gas properties in the date of the filing of this report.
Prior toManyberries area. Other sources and during fiscal 2021, the Company investigated potential sources of funding including non-core oil and natural gas property sales, however, no probable sources of such funding have yet been secured. Additionally, in fiscal 2020, theare discussed below.
The Company listed its corporate office on the 29th floor of a commercial office building in downtown Honolulu, Hawaii for sale to generate liquidity in order to help mitigate the substantial doubt about our ability to continue as a going concern. However,The corporate office is currently under a purchase and sales contract with a buyer with a tentative closing to occur prior to September 30, 2021. While the Company believes the likelihood of the sale occurring as per the terms of the contract is more likely than not, the Company’s ability to successfully consummate the sale cannot be assured.
On March 16, 2021, the Company initiated an at-the-market offering program (“ATM”) pursuant to which the Company may offer and sell, from time to time, shares of its corporate office atcommon stock under price and volume guidelines set by the Company's Board of Directors and the terms and conditions described in the Registration Statement. The sale of shares under the ATM began in May 2021 and as of June 30, 2021, the Company sold 586,546 shares of common stock resulting in net proceeds of $1,860,000 after commissions and fees of $59,000. From July 1, 2021 to the date of this Quarterly Report, an appropriate time oradditional 581,441 shares of common stock were sold resulting in net proceeds of $1,924,000 after commissions and fees of $64,000.
In April 2021, the Company re-initiated the marketing of its non-core oil and natural gas properties in the Spirit River, Wood River, Medicine River, Kaybob, Bonanza, Balsam and Thornbury areas for sale. Subsequent to June 30, 2021, Barnwell entered into and completed a sufficientpurchase and sale agreement with an independent third party and sold its interests in certain natural gas and oil properties located in the Spirit River area of Alberta, Canada. The sales price is outsideper the agreement was adjusted for customary purchase price adjustments to $1,047,000 in order to, among other things, reflect an economic effective closing date of sale of July 8, 2021. $524,000 of the Company's controlsales proceeds was withheld for remittance by the buyers to the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes related to the sale. Negotiations regarding the potential sales of other non-core oil and natural gas properties is therefore not probable. Becauseongoing, however there is no assurance that the sale of this uncertainty as well asany of the other non-core properties will occur.
We have experienced a trend of losses and negative operating cash flows in three of the last four years. During fiscal 2020 and 2021, continuing uncertainties regarding the potential duration and depth of the impacts of the COVID-19 pandemic on our
pandemic on our business and the sufficiency of our cash balances and future cash inflows as described above raised substantial doubt about our ability to meet our estimated cash outflows or continue as a going concern for one year from the date of the filing of this report exists.report. However, due to the $3,784,000 of funds raised by the ATM through the date of this Quarterly Report, as well as the $3,965,000 of net cash inflows in the quarter ended June 30, 2021 from land segment percentage of sales proceeds and distributions from the Kukio Resort Land Development Partnerships, such substantial doubt has been overcome.
NYSE American Continued Listing Standard
On January 13, 2020, the Company received a letternotice from the NYSE American staff (the “Exchange Staff”) indicating that the Company was not in compliance with Part 10, SectionsSection 1003(a)(i) and (a)Section 1003(a)(ii) of the NYSE American Company Guide (the “Guide”), which respectively require an issuer to have (i) stockholders’ equity of $2.0 million or more if such issuer reported losses from continuing operations and/or net losses in two of its three most recent fiscal years and (ii) stockholders’ equity of $4.0 million or more if such issuer reported losses from continuing operations and/or net losses in three of its four most recent fiscal years, since itwe reported stockholders’ equity of $1.2 million as of September 30, 2019 and net losses in three of the last four most recent fiscal years then ended, September 30, 2019, September 30, 2018 and September 30, 2016. Thethat the Company’s failure to meet the NYSE American’s stockholders’ equity requirements and the exceptions resulted in a risk that our common stock maycould be at risk of being delisted.
In accordance with the NYSE American’s policies and procedures, the Companywe subsequently submitted a plan (the “Plan”) addressing howto the Company intendedNYSE American detailing the steps we planned to take to raise our stockholders’ equity above $4.0 million and regain compliance with Part 10, Section 10031003(a)(i) and Section 1003(a)(ii) of the Guide. On April 2, 2020, the NYSE American notified the Company that it accepted the Company’s Plan and granted the Company an extension for its continued listing until July 13, 2021.
On July 13, 2021, (the “Plan Period”). Thethe Company has beenfiled a Form 8-K report with the Securities and will continueExchange Commission announcing that the Company’s pro forma stockholders’ equity (unaudited) as of July 13, 2021 was projected to be subjectabove the $4.0 million required to periodic review by Exchange Staff duringcomply with Section 1003(a)(i) and Section 1003(a)(ii) of the Plan Period. The Plan was submitted toGuide. Accordingly, in a letter dated July 14, 2021, the NYSE American beforedetermined the startCompany had resolved the continued listing deficiency with respect to Section 1003(a)(i) and Section 1003(a)(ii) of the COVID-19 pandemic-related low commodity price environment, the oil price war between Saudi ArabiaGuide and Russia and other macroeconomic pressures that have impacted our businesses and the U.S. economy in general. The magnitude and duration of these factors have and will adversely affect the Company’s ability to achieve the Plan’s goals and to return to compliance with the NYSE American’s listing standards. Ifnotified the Company does not regain compliance by the end of the Plan Period, or if the Company does not make ongoing progress consistent with its Plan, the NYSE American may initiate delisting procedures as appropriate.
The Company’s reported stockholders’ equity fell from $2,049,000 at March 31, 2020 to a stockholders’ deficit of $2,045,000 at September 30, 2020. At December 31, 2020, the Company reported a stockholders' deficit of $1,662,000, as disclosed in the accompanying condensed consolidated financial statements of this report. Thus, the Company may fail to be inthat it had successfully regained compliance with the NYSE American continued listing standards relating to stockholders’ equity to which the Plan relates; specifically Section 1003(a)(i) and Section 1003(a)(ii). The Company submitted updates to the Plan, as required or requested by the NYSE American with the most recent Plan update submitted January 2021. The January 2021 Plan updates presented initiatives which, if all of them are achieved, could result in the amount of stockholders’ equity required by the NYSE American at the end of the Plan Period and accordingly result in the Company regaining compliance with the NYSE American’s continued listing standards. There is no assurance that the presented initiatives will in fact be achieved. The Company has not yet received any correspondence from the NYSE American regarding the January 2021 Plan updates. If the NYSE American delists our common stock, investors may face material adverse consequences, including, but not limited to, a lack of a trading market for our common stock, reduced liquidity, and an inability for us to obtain financing to fund our operations.
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 $139,000$726,000 and $897,000 for the three and nine months ended December 31, 2020,June 30, 2021, respectively, as compared to $3,105,000$26,000 and $3,144,000 for the same periodperiods in the prior year.
Due to The Company participated in the uncertainties createddrilling of six gross (0.19 net) non-operated wells in Oklahoma during the three and nine months ended June 30, 2021, of which one gross well (0.04 net well) was completed and five gross wells (0.15 net wells) were in progress as of June 30, 2021. Capital expenditures incurred by the COVID-19 pandemic, investmentsCompany for these Oklahoma wells totaled $588,000 for the three and nine months ended June 30, 2021. The completed well began flowback production in late May 2021 and the Company’s share of net production, after royalties, from this well was 463 barrels of oil, and1,240 MCF of natural gas properties have been suspended pending suitable market opportunities and sufficient sources172 barrels of funding.natural gas liquids through June 30, 2021.
The Company did not drill or participate in the drilling of wells in Canada during the three and nine months ended June 30, 2021. Drilling opportunities in the Company's core Twining area are being investigated for potential investment in the forthcoming months.
Oil and Natural Gas PropertiesProperty Acquisitions and Dispositions
Dispositions
ThereOn April 8, 2021, Barnwell entered into a purchase and sale agreement with an independent third party and sold its interests in properties located in the Hillsdown area of Alberta, Canada. The sales price per the agreement was adjusted for customary purchase price adjustments to $132,000 in order to, among other things, reflect an economic effective date of October 1, 2020. $72,000 of the sales proceeds was withheld by the buyers for potential amounts due for Barnwell’s Canadian income taxes related to the sale. 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 proceeds were credited to the full cost pool, with no oilgain or loss recognized, as the sale did not result in a significant alteration of the relationship between capitalized costs and natural gas property dispositions during the three months ended December 31, 2020.proved reserves.
In the quarter ended December 31, 2019, Barnwell entered into a purchase and sale agreement with an independent third party and sold its interests in properties located in the Progress area of Alberta, Canada. The sales price per the agreement was adjusted for customary purchase price adjustments to $594,000 in order to, among other things, reflect an economic effective date of October 1, 2019. The proceeds were credited to the full cost pool, with no gain or loss recognized, as the sale did not result in a significant alteration of the relationship between capitalized costs and proved reserves.
In April 2021, the Company re-initiated the marketing of its non-core oil and natural gas properties in the Spirit River, Wood River, Medicine River, Kaybob, Bonanza, Balsam and Thornbury areas for sale. Subsequent to June 30, 2021, 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 Spirit River area of Alberta, Canada. The sales price per the agreement was adjusted for customary purchase price adjustments to $1,047,000 in order to, among other things, reflect an economic effective closing date of sale of July 8, 2021. $524,000 of the sales proceeds was withheld for remittance by the buyers to the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes related to the sale. Barnwell expects to report a gain on this transaction which will be recognized in its quarter ending September 30, 2021.
Negotiations regarding the potential sales of other non-core oil and natural gas properties is ongoing, however there is no assurance that the sale of any of the other non-core properties will occur.
Acquisitions
On April 8, 2021, Barnwell acquired additional working interests in oil and natural gas properties located in the Twining area of Alberta, Canada for cash consideration of $348,000. The purchase price per the agreement was adjusted for customary purchase price adjustments to reflect the economic activity from the effective date to the closing date. 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.
There were no significant amounts paid for oil and natural gas property acquisitions during the threenine months ended December 31, 2020,June 30, 2020.
Asset Retirement Obligation
In September 2019, the Alberta Energy Regulator (“AER”) issued an abandonment/closure order for all wells and 2019.facilities in the Manyberries area which had been largely operated by LGX Oil & Gas Ltd. (“LGX”), an operating company that went into receivership in 2016. The estimated asset retirement obligation for the Company's wells and facilities in the Manyberries area is included in “Asset retirement obligation” (“ARO”) in the Condensed Consolidated Balance Sheets. Many 100% LGX owned wells are to be reclaimed by the Orphan Well Association (“OWA”). However, as next largest interest holder in 82 of the wells and 7 facilities formerly operated by LGX, averaging 11%, the Company is required to take care and custody of those properties and to coordinate their closure. This area has unique access issues as a result of an Emergency Protection Order to protect the Sage Grouse under the Canadian Government’s Species at Risk Act. Access is limited to a window of mid-September to the end of November each year.
Recently, the OWA has created a Working Interest Partners (“WIP”) program for specific areas where there are a significant number of orphaned wells to abandon. The OWA has the ability and expertise to abandon wells using its internal resources and network of service providers resulting in efficiencies that companies such as Barnwell, would not be able to obtain on its own. Under the WIP program, the Company would be required to provide payment for only Barnwell’s working interest share, however, all WIP’s would have to participate in the program for the OWA to begin its work. In March 2021, the Company was notified by the OWA that Barnwell’s Manyberries wells were confirmed to be in the WIP program and in June 2021, the Company executed an agreement committing to its participation.
Under the agreement with the OWA, the Company is required to pay the abandonment and reclamation costs in advance through a cash deposit. The total cash deposit amount was calculated to be approximately $1,568,000 and the Company will need to pay $913,000 of the total deposit by August 2021 and will need to pay the remaining balance of $655,000 by August 2022. The Company revised its Manyberries ARO liability based on the OWA’s revised abandonment and reclamation estimates, which resulted in an increase of approximately $213,000 in the current year period. The increase in the ARO liability was a result of higher reclamation and remediation costs than anticipated, partially offset by lower abandonment estimates. Based on a review of the details of the cash deposit calculation provided by the OWA, which includes amounts added for possible contingencies, the Company believes the required cash deposit amount by the OWA is higher than the actual costs of the asset retirement obligation for the Manyberries wells and that any excess of the deposit over actual asset retirement costs for the first phase of the work would be credited toward the second phase of the work. Any remaining excess deposit would ultimately be refunded to the Company upon completion of all of the work. It is anticipated that the OWA’s abandonment program for the Manyberries area wells will commence and be completed in the fall of 2021 with the reclamation to begin the following fall of 2022.
ITEM 4. CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
We have established disclosure controls and procedures to ensure that material information relating to Barnwell, including its consolidated subsidiaries, is made known to the officers who certify Barnwell’s financial reports and to other members of executive management and the Board of Directors.
As of December 31, 2020,June 30, 2021, an evaluation was carried out by Barnwell’s Chief Executive Officer and Chief Financial Officer of the effectiveness of Barnwell’s disclosure controls and procedures. Based on
that evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that Barnwell’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) were effective as of December 31, 2020June 30, 2021 to ensure that information required to be disclosed by Barnwell in the reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the Securities Exchange Act of 1934 and the rules thereunder.
Changes in Internal Control Over Financial Reporting
There was no change in Barnwell’s internal control over financial reporting during the quarter ended December 31, 2020June 30, 2021 that materially affected, or is reasonably likely to materially affect, Barnwell’s internal control over financial reporting.
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 | | XBRL Instance Document |
| | | |
| 101.SCH | | XBRL Taxonomy Extension Schema Document |
| | | |
| 101.CAL | | XBRL Taxonomy Extension Calculation Linkbase Document |
| | | |
| 101.DEF | | XBRL Taxonomy Extension Definition Linkbase Document |
| | | |
| 101.LAB | | XBRL Taxonomy Extension Label Linkbase Document |
| | | |
| 101.PRE | | XBRL Taxonomy Extension Presentation Linkbase Document |
| | |
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
| | | | | | | | |
| | BARNWELL INDUSTRIES, INC. |
| | (Registrant) |
| | |
| | |
| Date: | February 16,August 13, 2021 | /s/ Russell M. Gifford |
| | Russell M. Gifford |
| | Chief Financial Officer, |
| | Executive Vice President, |
| | Treasurer and Secretary |
INDEX TO EXHIBITS
| | | | | | | | |
Exhibit
Number | | Description |
| | |
| 31.1 | | |
| | | |
| 31.2 | | |
| | | |
| 32 | | |
| | | |
| 101.INS | | XBRL Instance Document |
| | | |
| 101.SCH | | XBRL Taxonomy Extension Schema Document |
| | | |
| 101.CAL | | XBRL Taxonomy Extension Calculation Linkbase Document |
| | | |
| 101.DEF | | XBRL Taxonomy Extension Definition Linkbase Document |
| | | |
| 101.LAB | | XBRL Taxonomy Extension Label Linkbase Document |
| | | |
| 101.PRE | | XBRL Taxonomy Extension Presentation Linkbase Document |
| | |