UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
[X]☒ Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
For the quarterly period ended June 30,December 31, 2020
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)
|
| | | | | | | |
DELAWAREDelaware | | 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. x☒ Yes o☐ 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). x☒ Yes o☐ 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 | o☐ | | Accelerated filer | o☐ |
| Non-accelerated filer | o☒ | (Do not check if a smaller reporting company) | Smaller reporting company | x☒ |
| | | Emerging growth company | o☐ |
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. o☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). o☐ Yes x☒ No
As of August 7, 2020February 8, 2021 there were 8,277,160 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
| | | | June 30,
2020 | | September 30,
2019 | | December 31, 2020 | | September 30, 2020 |
| ASSETS | | | | ASSETS | | | |
| Current assets: | | | | Current assets: | |
| Cash and cash equivalents | $ | 4,106,000 |
| | $ | 4,613,000 |
| Cash and cash equivalents | $ | 5,334,000 | | | $ | 4,584,000 | |
Accounts and other receivables, net of allowance for doubtful accounts of:
$329,000 at June 30, 2020; $44,000 at September 30, 2019 | 2,245,000 |
| | 1,884,000 |
| |
| Accounts and other receivables, net of allowance for doubtful accounts of: $362,000 at December 31, 2020; $341,000 at September 30, 2020 | | 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 | |
| Income taxes receivable | 468,000 |
| | 386,000 |
| Income taxes receivable | 448,000 | | | 472,000 | |
| Asset held for sale | | Asset held for sale | 699,000 | | | 699,000 | |
| Other current assets | 1,321,000 |
| | 1,821,000 |
| Other current assets | 1,464,000 | | | 1,556,000 | |
| Total current assets | 8,140,000 |
| | 8,704,000 |
| Total current assets | 9,979,000 | | | 9,487,000 | |
| Income taxes receivable, net of current portion | — |
| | 230,000 |
| |
| | Asset for retirement benefits | 1,593,000 |
| | — |
| Asset for retirement benefits | 843,000 | | | 771,000 | |
| Investments | 801,000 |
| | 980,000 |
| Investments | 88,000 | | | 901,000 | |
| Operating lease right-of-use assets | 272,000 |
| | — |
| Operating lease right-of-use assets | 227,000 | | | 249,000 | |
| Property and equipment | 73,628,000 |
| | 72,522,000 |
| Property and equipment | 76,217,000 | | | 73,431,000 | |
| Accumulated depletion, depreciation, and amortization | (68,449,000 | ) | | (64,134,000 | ) | Accumulated depletion, depreciation, and amortization | (73,313,000) | | | (69,657,000) | |
| Property and equipment, net | 5,179,000 |
| | 8,388,000 |
| Property and equipment, net | 2,904,000 | | | 3,774,000 | |
| Total assets | $ | 15,985,000 |
| | $ | 18,302,000 |
| Total assets | $ | 14,041,000 | | | $ | 15,182,000 | |
| | | | | | | |
| LIABILITIES AND EQUITY | | | | LIABILITIES AND EQUITY | |
| Current liabilities: | | | | Current liabilities: | |
| Accounts payable | $ | 1,877,000 |
| | $ | 1,223,000 |
| Accounts payable | $ | 1,257,000 | | | $ | 2,104,000 | |
| Accrued capital expenditures | 689,000 |
| | 287,000 |
| Accrued capital expenditures | 336,000 | | | 542,000 | |
| Accrued compensation | 199,000 |
| | 205,000 |
| Accrued compensation | 390,000 | | | 408,000 | |
| Accrued operating and other expenses | 1,199,000 |
| | 1,079,000 |
| Accrued operating and other expenses | 1,032,000 | | | 1,325,000 | |
| | Current portion of operating lease liabilities | 107,000 |
| | — |
| Current portion of operating lease liabilities | 116,000 | | | 111,000 | |
| Current portion of asset retirement obligation | 664,000 |
| | 330,000 |
| Current portion of asset retirement obligation | 605,000 | | | 647,000 | |
| | Other current liabilities | 1,714,000 |
| | 1,644,000 |
| Other current liabilities | 873,000 | | | 1,227,000 | |
| Total current liabilities | 6,449,000 |
| | 4,768,000 |
| Total current liabilities | 4,609,000 | | | 6,364,000 | |
| Deferred rent | — |
| | 193,000 |
| |
| Long-term debt | 83,000 |
| | — |
| Long-term debt | 98,000 | | | 58,000 | |
| Operating lease liabilities | 171,000 |
| | — |
| Operating lease liabilities | 115,000 | | | 143,000 | |
| Liability for retirement benefits | 4,675,000 |
| | 5,785,000 |
| Liability for retirement benefits | 4,858,000 | | | 4,829,000 | |
| Asset retirement obligation | 5,878,000 |
| | 6,059,000 |
| Asset retirement obligation | 5,787,000 | | | 5,547,000 | |
| Deferred income tax liabilities | 161,000 |
| | 168,000 |
| Deferred income tax liabilities | 233,000 | | | 194,000 | |
| Total liabilities | 17,417,000 |
| | 16,973,000 |
| Total liabilities | 15,700,000 | | | 17,135,000 | |
| Commitments and contingencies |
|
| |
|
| Commitments and contingencies | 0 | | 0 |
| Equity: | | | | Equity: | |
Common stock, par value $0.50 per share; authorized, 20,000,000 shares:
8,445,060 issued at June 30, 2020 and September 30, 2019 | 4,223,000 |
| | 4,223,000 |
| |
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 | | 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 | |
| Additional paid-in capital | 1,350,000 |
| | 1,350,000 |
| Additional paid-in capital | 1,350,000 | | | 1,350,000 | |
| (Accumulated deficit) retained earnings | (4,525,000 | ) | | 859,000 |
| |
| Accumulated deficit | | Accumulated deficit | (3,313,000) | | | (3,897,000) | |
| Accumulated other comprehensive loss, net | (274,000 | ) | | (2,917,000 | ) | Accumulated other comprehensive loss, net | (1,636,000) | | | (1,435,000) | |
| Treasury stock, at cost: 167,900 shares at June 30, 2020 and September 30, 2019 | (2,286,000 | ) | | (2,286,000 | ) | |
| Total stockholders’ (deficit) equity | (1,512,000 | ) | | 1,229,000 |
| |
| Treasury stock, at cost: 167,900 shares at December 31, 2020 and September 30, 2020 | | Treasury stock, at cost: 167,900 shares at December 31, 2020 and September 30, 2020 | (2,286,000) | | | (2,286,000) | |
| Total stockholders' deficit | | Total stockholders' deficit | (1,662,000) | | | (2,045,000) | |
| Non-controlling interests | 80,000 |
| | 100,000 |
| Non-controlling interests | 3,000 | | | 92,000 | |
| Total (deficit) equity | (1,432,000 | ) | | 1,329,000 |
| |
| Total deficit | | Total deficit | (1,659,000) | | | (1,953,000) | |
| Total liabilities and equity | $ | 15,985,000 |
| | $ | 18,302,000 |
| Total liabilities and equity | $ | 14,041,000 | | | $ | 15,182,000 | |
See Notes to Condensed Consolidated Financial Statements
BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)
| | | | Three months ended
June 30, | | Nine months ended
June 30, | | Three months ended
December 31, |
| | 2020 | | 2019 | | 2020 | | 2019 | | 2020 | | 2019 |
| Revenues: | |
| | |
| | | | | Revenues: | | | |
| Oil and natural gas | $ | 830,000 |
| | $ | 1,688,000 |
| | $ | 4,881,000 |
| | $ | 4,844,000 |
| Oil and natural gas | $ | 1,887,000 | | | $ | 2,141,000 | |
| Contract drilling | 3,040,000 |
| | 1,689,000 |
| | 8,279,000 |
| | 3,839,000 |
| Contract drilling | 1,942,000 | | | 2,646,000 | |
| Sale of interest in leasehold land | — |
| | — |
| | — |
| | 165,000 |
| Sale of interest in leasehold land | 485,000 | | | 0 | |
| Gas processing and other | 114,000 |
| | 32,000 |
| | 256,000 |
| | 119,000 |
| Gas processing and other | 73,000 | | | 63,000 | |
| | 3,984,000 |
| | 3,409,000 |
| | 13,416,000 |
| | 8,967,000 |
| | 4,387,000 | | | 4,850,000 | |
| Costs and expenses: | |
| | |
| | | | | Costs and expenses: | | | |
| Oil and natural gas operating | 981,000 |
| | 1,314,000 |
| | 3,479,000 |
| | 3,900,000 |
| Oil and natural gas operating | 1,435,000 | | | 1,213,000 | |
| Contract drilling operating | 1,967,000 |
| | 1,242,000 |
| | 5,552,000 |
| | 3,789,000 |
| Contract drilling operating | 1,108,000 | | | 1,814,000 | |
| General and administrative | 1,248,000 |
| | 1,352,000 |
| | 4,775,000 |
| | 4,361,000 |
| General and administrative | 1,185,000 | | | 1,496,000 | |
| Depletion, depreciation, and amortization | 478,000 |
| | 731,000 |
| | 1,870,000 |
| | 2,308,000 |
| Depletion, depreciation, and amortization | 276,000 | | | 705,000 | |
| Impairment of assets | 2,689,000 |
| | — |
| | 4,326,000 |
| | 2,413,000 |
| Impairment of assets | 630,000 | | | 0 | |
| Interest expense | 1,000 |
| | — |
| | 1,000 |
| | 4,000 |
| Interest expense | 1,000 | | | 0 | |
| Gain on sale of asset | — |
| | — |
| | (1,336,000 | ) | | — |
| |
| | 7,364,000 |
| | 4,639,000 |
| | 18,667,000 |
| | 16,775,000 |
| | 4,635,000 | | | 5,228,000 | |
| Loss before equity in loss of affiliates and income taxes | (3,380,000 | ) | | (1,230,000 | ) | | (5,251,000 | ) | | (7,808,000 | ) | |
| Equity in loss of affiliates | (111,000 | ) | | (259,000 | ) | | (179,000 | ) | | (545,000 | ) | |
| Loss before income taxes | (3,491,000 | ) | | (1,489,000 | ) | | (5,430,000 | ) | | (8,353,000 | ) | |
| Income tax benefit | (24,000 | ) | | (91,000 | ) | | (26,000 | ) | | (231,000 | ) | |
| Net loss | (3,467,000 | ) | | (1,398,000 | ) | | (5,404,000 | ) | | (8,122,000 | ) | |
| Less: Net loss attributable to non-controlling interests | (11,000 | ) | | (33,000 | ) | | (20,000 | ) | | (32,000 | ) | |
| Net loss attributable to Barnwell Industries, Inc. | $ | (3,456,000 | ) | | $ | (1,365,000 | ) | | $ | (5,384,000 | ) | | $ | (8,090,000 | ) | |
| Basic and diluted net loss per common share attributable to Barnwell Industries, Inc. stockholders | $ | (0.42 | ) | | $ | (0.16 | ) | | $ | (0.65 | ) | | $ | (0.98 | ) | |
| Loss before equity in income (loss) of affiliates and income taxes | | Loss before equity in income (loss) of affiliates and income taxes | (248,000) | | | (378,000) | |
| Equity in income (loss) of affiliates | | Equity in income (loss) of affiliates | 1,054,000 | | | (43,000) | |
| Earnings (loss) before income taxes | | Earnings (loss) before income taxes | 806,000 | | | (421,000) | |
| Income tax provision (benefit) | | Income tax provision (benefit) | 63,000 | | | (2,000) | |
| Net earnings (loss) | | Net earnings (loss) | 743,000 | | | (419,000) | |
| Less: Net earnings (loss) attributable to non-controlling interests | | Less: Net earnings (loss) attributable to non-controlling interests | 159,000 | | | (5,000) | |
| Net earnings (loss) attributable to Barnwell Industries, Inc. | | Net earnings (loss) attributable to Barnwell Industries, Inc. | $ | 584,000 | | | $ | (414,000) | |
| 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) | |
| Weighted-average number of common shares outstanding: | |
| | |
| | | | | Weighted-average number of common shares outstanding: | | | |
| Basic and diluted | 8,277,160 |
| | 8,277,160 |
| | 8,277,160 |
| | 8,277,160 |
| Basic and diluted | 8,277,160 | | | 8,277,160 | |
See Notes to Condensed Consolidated Financial Statements
BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSSINCOME
(Unaudited)
| | | | | | | | | | | | Three months ended
December 31, |
| | Three months ended
June 30, | | Nine months ended
June 30, | | 2020 | | 2019 |
| | 2020 | | 2019 | | 2020 | | 2019 | |
| Net loss | $ | (3,467,000 | ) | | $ | (1,398,000 | ) | | $ | (5,404,000 | ) | | $ | (8,122,000 | ) | |
| Net earnings (loss) | | Net earnings (loss) | $ | 743,000 | | | $ | (419,000) | |
| Other comprehensive (loss) income: | |
| | |
| |
|
| |
|
| Other comprehensive (loss) income: | | | |
| Foreign currency translation adjustments, net of taxes of $0 | (125,000 | ) | | 89,000 |
| | (36,000 | ) | | (194,000 | ) | Foreign currency translation adjustments, net of taxes of $0 | (234,000) | | | 5,000 | |
| Retirement plans: | | | | | | | | Retirement plans: | |
| Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | 20,000 |
| | 9,000 |
| | 100,000 |
| | 42,000 |
| Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | 33,000 | | | 60,000 | |
| Net actuarial gains arising during the period, net of taxes of $0 | — |
| | — |
| | 880,000 |
| | — |
| Net actuarial gains arising during the period, net of taxes of $0 | 0 | | | 880,000 | |
| Curtailment gain, net of taxes of $0 | — |
| | — |
| | 1,699,000 |
| | — |
| Curtailment gain, net of taxes of $0 | 0 | | | 1,699,000 | |
| Total other comprehensive (loss) income | (105,000 | ) | | 98,000 |
| | 2,643,000 |
| | (152,000 | ) | Total other comprehensive (loss) income | (201,000) | | | 2,644,000 | |
| Total comprehensive loss | (3,572,000 | ) | | (1,300,000 | ) | | (2,761,000 | ) | | (8,274,000 | ) | |
| Less: Comprehensive loss attributable to non-controlling interests | (11,000 | ) | | (33,000 | ) | | (20,000 | ) | | (32,000 | ) | |
| Comprehensive loss attributable to Barnwell Industries, Inc. | $ | (3,561,000 | ) | | $ | (1,267,000 | ) | | $ | (2,741,000 | ) | | $ | (8,242,000 | ) | |
| Total comprehensive income | | Total comprehensive income | 542,000 | | | 2,225,000 | |
| Less: Comprehensive (income) loss attributable to non-controlling interests | | Less: Comprehensive (income) loss attributable to non-controlling interests | (159,000) | | | 5,000 | |
| Comprehensive income attributable to Barnwell Industries, Inc. | | Comprehensive income attributable to Barnwell Industries, Inc. | $ | 383,000 | | | $ | 2,230,000 | |
See Notes to Condensed Consolidated Financial Statements
BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (DEFICIT)
NineThree months ended June 30,December 31, 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) |
| 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 | — | | | — | | | — | | | (414,000) | | | — | | | — | | | (5,000) | | | (419,000) | |
| | | | | | | | | | | | | | | |
| Foreign currency translation adjustments, net of taxes of $0 | — | | | — | | | — | | | — | | | 5,000 | | | — | | | — | | | 5,000 | |
| Retirement plans: | | | | | | | | | | | | | | | |
| Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | — | | | — | | | — | | | — | | | 60,000 | | | — | | | — | | | 60,000 | |
| 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) | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Net earnings | — | | | — | | | — | | | 584,000 | | | — | | | — | | | 159,000 | | | 743,000 | |
| Foreign currency translation adjustments, net of taxes of $0 | — | | | — | | | — | | | — | | | (234,000) | | | — | | | — | | | (234,000) | |
| Distributions to non-controlling interests | — | | | — | | | — | | | — | | | — | | | — | | | (248,000) | | (248,000) |
| Retirement plans: | | | | | | | | | | | | | | | |
| Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | — | | | — | | | — | | | — | | | 33,000 | | | — | | | — | | | 33,000 | |
| 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) | |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | 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, 2018 | 8,277,160 |
| | $ | 4,223,000 |
| | $ | 1,350,000 |
| | $ | 13,253,000 |
| | $ | (514,000 | ) | | $ | (2,286,000 | ) | | $ | 213,000 |
| | $ | 16,239,000 |
|
| Cumulative impact from the adoption of ASU No. 2014-09 | — |
| | — |
| | — |
| | 20,000 |
| | — |
| | — |
| | — |
| | 20,000 |
|
| Distributions to non-controlling interests | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| | (110,000 | ) | | (110,000 | ) |
| Net loss | — |
| | — |
| | — |
| | (8,090,000 | ) | | — |
| | — |
| | (32,000 | ) | | (8,122,000 | ) |
| Foreign currency translation adjustments, net of taxes of $0 | — |
| | — |
| | — |
| | — |
| | (194,000 | ) | | — |
| | — |
| | (194,000 | ) |
| Retirement plans - amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 | — |
| | — |
| | — |
| | — |
| | 42,000 |
| | — |
| | — |
| | 42,000 |
|
| Balance at June 30, 2019 | 8,277,160 |
| | $ | 4,223,000 |
| | $ | 1,350,000 |
| | $ | 5,183,000 |
| | $ | (666,000 | ) | | $ | (2,286,000 | ) | | $ | 71,000 |
| | $ | 7,875,000 |
|
| | | | | | | | | | | | | | | | |
| 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 | ) |
See Notes to Condensed Consolidated Financial Statements
BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
| | | | Nine months ended
June 30, | | Three months ended
December 31, |
| | 2020 | | 2019 | | 2020 | | 2019 |
| Cash flows from operating activities: | |
| | |
| Cash flows from operating activities: | | | |
| Net loss | $ | (5,404,000 | ) | | $ | (8,122,000 | ) | |
| Adjustments to reconcile net loss to net cash | |
| | |
| |
| Net earnings (loss) | | Net earnings (loss) | $ | 743,000 | | | $ | (419,000) | |
| 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 (used in) operating activities: | |
| Equity in loss of affiliates | 179,000 |
| | 545,000 |
| |
| Equity in (income) loss of affiliates | | Equity in (income) loss of affiliates | (1,054,000) | | | 43,000 | |
| Depletion, depreciation, and amortization | 1,870,000 |
| | 2,308,000 |
| Depletion, depreciation, and amortization | 276,000 | | | 705,000 | |
| Gain on sale of asset | (1,336,000 | ) | | — |
| |
| Impairment of assets | 4,326,000 |
| | 2,413,000 |
| Impairment of assets | 630,000 | | | 0 | |
| Sale of interest in leasehold land, net of fees paid | | Sale of interest in leasehold land, net of fees paid | (426,000) | | | 0 | |
| Distributions of income from equity investees | | Distributions of income from equity investees | 1,054,000 | | | 0 | |
| Retirement benefits (income) expense | (18,000 | ) | | 133,000 |
| Retirement benefits (income) expense | (8,000) | | | 71,000 | |
| Income tax receivable, noncurrent | — |
| | (31,000 | ) | |
| Non-cash rent expense | 48,000 |
| | 65,000 |
| |
| Accretion of asset retirement obligation | 415,000 |
| | 452,000 |
| Accretion of asset retirement obligation | 137,000 | | | 134,000 | |
| Deferred income tax benefit | (7,000 | ) | | (134,000 | ) | |
| | Non-cash rent (income) expense | | Non-cash rent (income) expense | (1,000) | | | 30,000 | |
| Deferred income tax expense (benefit) | | Deferred income tax expense (benefit) | 39,000 | | | (9,000) | |
| Asset retirement obligation payments | (457,000 | ) | | (310,000 | ) | Asset retirement obligation payments | (38,000) | | | (2,000) | |
| Share-based compensation benefit | — |
| | (31,000 | ) | |
| | Retirement plan contributions and payments | (6,000 | ) | | (121,000 | ) | Retirement plan contributions and payments | (2,000) | | | (2,000) | |
| Bad debt expense | 280,000 |
| | — |
| Bad debt expense | 7,000 | | | 0 | |
| Sale of interest in leasehold land, net of fees paid | — |
| | (124,000 | ) | |
| Increase from changes in current assets and liabilities | 582,000 |
| | 1,326,000 |
| |
| Decrease from changes in current assets and liabilities | | Decrease from changes in current assets and liabilities | (1,277,000) | | | (1,917,000) | |
| Net cash provided by (used in) operating activities | 472,000 |
| | (1,631,000 | ) | Net cash provided by (used in) operating activities | 80,000 | | | (1,366,000) | |
| Cash flows from investing activities: |
|
| | |
| Cash flows from investing activities: | | | |
| Proceeds from the maturity of certificates of deposit | — |
| | 741,000 |
| |
| | 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 | |
| | Distribution from equity investees in excess of earnings | — |
| | 352,000 |
| Distribution from equity investees in excess of earnings | 813,000 | | | 0 | |
| Net proceeds from sale of interest in leasehold land | — |
| | 124,000 |
| |
| Proceeds from sale of oil and natural gas assets | 608,000 |
| | 1,519,000 |
| Proceeds from sale of oil and natural gas assets | 0 | | | 594,000 | |
| Proceeds from the sale of asset | 1,100,000 |
| | — |
| |
| Payments to acquire oil and natural gas properties | — |
| | (355,000 | ) | |
| | Capital expenditures - oil and natural gas | (2,509,000 | ) | | (58,000 | ) | Capital expenditures - oil and natural gas | (364,000) | | | (1,444,000) | |
| Capital expenditures - all other | (315,000 | ) | | (1,221,000 | ) | Capital expenditures - all other | 0 | | | (13,000) | |
| Issuance of note receivable | — |
| | (300,000 | ) | |
| Net cash (used in) provided by investing activities | (1,116,000 | ) | | 802,000 |
| |
| Net cash provided by (used in) investing activities | | Net cash provided by (used in) investing activities | 875,000 | | | (863,000) | |
| Cash flows from financing activities: | |
| | |
| Cash flows from financing activities: | | | |
| | Borrowings on long-term debt | 147,000 |
| | — |
| Borrowings on long-term debt | 31,000 | | | 0 | |
| | Distributions to non-controlling interests | — |
| | (110,000 | ) | Distributions to non-controlling interests | (248,000) | | | 0 | |
| Net cash provided by (used in) financing activities | 147,000 |
| | (110,000 | ) | |
| Net cash used in financing activities | | Net cash used in financing activities | (217,000) | | | 0 | |
| Effect of exchange rate changes on cash and cash equivalents | (10,000 | ) | | 9,000 |
| Effect of exchange rate changes on cash and cash equivalents | 12,000 | | | 15,000 | |
| Net decrease in cash and cash equivalents | (507,000 | ) | | (930,000 | ) | |
| Net increase (decrease) in cash and cash equivalents | | Net increase (decrease) in cash and cash equivalents | 750,000 | | | (2,214,000) | |
| Cash and cash equivalents at beginning of period | 4,613,000 |
| | 5,965,000 |
| Cash and cash equivalents at beginning of period | 4,584,000 | | | 4,613,000 | |
| Cash and cash equivalents at end of period | $ | 4,106,000 |
| | $ | 5,035,000 |
| Cash and cash equivalents at end of period | $ | 5,334,000 | | | $ | 2,399,000 | |
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). 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 (“SEC”).Commission. Accordingly, certain information and footnote disclosures normally included in the annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to those rules and regulations, although the Company believes that the disclosures made are adequate to make the information not misleading. These condensed consolidated financial statements and notes should be read in conjunction with the consolidated financial statements and notes thereto included in Barnwell’s September 30, 20192020 Annual Report on Form 10-K, as amended by our Form 10-K/A Amendment No. 1 and Form 10-K/A Amendment No. 2.1. The Condensed Consolidated Balance Sheet as of September 30, 20192020 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 June 30,December 31, 2020, results of operations, and comprehensive loss for the three and nine months ended June 30, 2020 and 2019, andincome, equity (deficit) and cash flows for the ninethree months ended June 30,December 31, 2020 and 2019, have been made. The results of operations for the period ended June 30,December 31, 2020 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
Other than the accounting policies implemented in connection with the adoption of Accounting Standards Update (“ASU”) No. 2016-02, “Leases (Topic 842)” discussed in Note 13, thereThere 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 and Form 10-K/A Amendment No. 2.1.
Recently Adopted Accounting Pronouncements
In February 2016,August 2018, the Financial Accounting Standards Board (“FASB”) issued ASU No. 2016-02, “Leases (Topic 842),2018-13, “Fair Value Measurement: Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement,” which requires an entityprovides changes to recognize a right-of-use asset and a lease liability on the balance sheet for all leases with terms greater than 12 months at the lease commencement date.certain fair value disclosure requirements. The Company adopted the provisions of this ASUAccounting Standards Update (“ASU”) effective October 1, 2019. See Note 13 “Leases and Gain on Sale of Asset.”
In February 2018, the FASB issued ASU No. 2018-02, “Reclassification of Certain Tax Effects From Accumulated Other Comprehensive Income,” which allows a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the Tax Cuts and Jobs Act of 2017. The Company adopted the provisions of this ASU effective October 1, 2019.2020. The adoption of this update did not have an impact on Barnwell's consolidated financial statements.
In JulyOctober 2018, the FASB issued ASU No. 2018-09, “Codification2018-17, “Consolidation: Targeted Improvements to Related Party Guidance for Variable Interest Entities,” which provides further clarificationmodifies the guidance related to the codification literature.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, 2019.2020. The adoption of this update did not have an impact on Barnwell's consolidated financial statements.
Impact of COVID-19
On March 11, 2020, the World Health Organization declared the coronavirus (“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 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. The global economy, our markets and our business have been materially and adversely affected by COVID-19.
The COVID-19 outbreak has caused significant reductions in demand for oil and oil prices, which has caused the Company to suspend the development of proved undeveloped reserves and has impacted the Company’s financial condition and outlook. While the Company’s contract drilling segment continues to work, the impact of COVID-19 on the 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. Both the health and economic aspects of the COVID-19 pandemic are 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, 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 or 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.
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 sufficient oil and natural gas operating cash flows, which are highly sensitive to potentially volatile oil and natural gas prices, sufficient contract drilling operating cash flows, which are subject to potentially 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 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 a trend of losses and negative operating cash flows in recentthree of the last four years. Due to uncertainties regarding oil prices and the additionalcontinuing 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 ability to fund our non-discretionary cash outflows and thus substantial doubt about our ability to continue as a going concern for one year from the date of the filing of this report.
The
Prior to and during fiscal 2021, the Company is investigatinginvestigated potential sources of funding, including non-core oil and natural gas property sales, however, no probable sources of such funding have yet been secured. Alternatively, management hasAdditionally, in fiscal 2020, the ability to sellCompany listed its corporate office on the 29th floor of a commercial office building in downtown Honolulu, Hawaii for sale to generate liquidity without impacting operations significantly, in order to help mitigate the substantial doubt about our ability to continue as a going concern. However, the Company’s ability to sell its corporate office at an appropriate time or for a sufficient price is outside of the Company's control and is therefore not probable. Because of this uncertainty as well as the continuing uncertainties regarding the potential duration and depth of the impacts of the COVID-19 pandemic on our business as described above, substantial doubt about our ability to 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 result from the outcome of these uncertainties.
3. LOSSEARNINGS (LOSS) PER COMMON SHARE
Basic lossearnings (loss) per share is computed using the weighted-average number of common shares outstanding for the period. Diluted lossearnings (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 lossearnings (loss) per share if their effect is anti-dilutive.
There were 0 options outstanding at December 31, 2020. Options to purchase 60,000 and 318,750 shares of common stock were excluded from the computation of diluted shares for the three and nine months ended June 30, 2020 andDecember 31, 2019, respectively, as their inclusion would have been anti-dilutive.
Reconciliations between net lossearnings (loss) attributable to Barnwell stockholders and common shares outstanding of the basic and diluted net lossearnings (loss) per share computations are detailed in the following tables:
| | | | | | | | | | | | | | | | | |
| | Three months ended December 31, 2020 |
| | Net Earnings
(Numerator) | | Shares
(Denominator) | | Per-Share
Amount |
| Basic net earnings per share | $ | 584,000 | | | 8,277,160 | | | $ | 0.07 | |
| Effect of dilutive securities - | | | | | |
| common stock options | 0 | | | 0 | | | |
| Diluted net earnings per share | $ | 584,000 | | | 8,277,160 | | | $ | 0.07 | |
| | | | | | | | | | | | | | | | | |
| | Three months ended December 31, 2019 |
| | Net Loss (Numerator) | | Shares
(Denominator) | | Per-Share
Amount |
| Basic net loss per share | $ | (414,000) | | | 8,277,160 | | | $ | (0.05) | |
| Effect of dilutive securities - | | | | | |
| common stock options | 0 | | | 0 | | | |
| Diluted net loss per share | $ | (414,000) | | | 8,277,160 | | | $ | (0.05) | |
|
| | | | | | | | | | |
| | Three months ended June 30, 2020 |
| | Net Loss
(Numerator) | | Shares (Denominator) | | Per-Share Amount |
| Basic net loss per share | $ | (3,456,000 | ) | | 8,277,160 |
| | $ | (0.42 | ) |
| Effect of dilutive securities - | |
| | |
| | |
|
| common stock options | — |
| | — |
| | |
|
| Diluted net loss per share | $ | (3,456,000 | ) | | 8,277,160 |
| | $ | (0.42 | ) |
|
| | | | | | | | | | |
| | 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 | — |
| | — |
| | |
|
| Diluted net loss per share | $ | (5,384,000 | ) | | 8,277,160 |
| | $ | (0.65 | ) |
|
| | | | | | | | | | |
| | Three months ended June 30, 2019 |
| | Net Loss
(Numerator) | | Shares (Denominator) | | Per-Share Amount |
| Basic net loss per share | $ | (1,365,000 | ) | | 8,277,160 |
| | $ | (0.16 | ) |
| Effect of dilutive securities - | |
| | |
| | |
|
| common stock options | — |
| | — |
| | |
|
| Diluted net loss per share | $ | (1,365,000 | ) | | 8,277,160 |
| | $ | (0.16 | ) |
|
| | | | | | | | | | |
| | Nine months ended June 30, 2019 |
| | Net Loss
(Numerator) | | Shares (Denominator) | | Per-Share Amount |
| Basic net loss per share | $ | (8,090,000 | ) | | 8,277,160 |
| | $ | (0.98 | ) |
| Effect of dilutive securities - | |
| | |
| | |
|
| common stock options | — |
| | — |
| | |
|
| Diluted net loss per share | $ | (8,090,000 | ) | | 8,277,160 |
| | $ | (0.98 | ) |
4. INVESTMENTSASSET HELD FOR SALE
A summaryThe 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 Barnwell’s non-current investments$699,000 is as follows:included in “Asset held for sale” on the Company's Condensed Consolidated Balance Sheets at December 31, 2020 and September 30, 2020.
|
| | | | | | | |
| | June 30,
2020 | | September 30,
2019 |
| Investment in Kukio Resort Land Development Partnerships | $ | 751,000 |
| | $ | 930,000 |
|
| Investment in leasehold land interest – Lot 4C | 50,000 |
| | 50,000 |
|
| Total non-current investments | $ | 801,000 |
| | $ | 980,000 |
|
Investment in Kukio Resort Land Development Partnerships
On November 27, 2013, Barnwell, through a wholly-owned subsidiary, entered into two2 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 1915 lots remain to be sold at Increment I as of June 30,December 31, 2020, 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. Effective March 7, 2019, KDK and Replay hold ownership interests of 55% and 45%, respectively, of KD II. Accordingly,II and Barnwell has a 10.8% indirect non-controlling ownership interest in KD II through KDK, as of that date that will continue to bewhich 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.
There were no cashBarnwell has the right to receive distributions from the Kukio Resort Land Development Partnerships for the nine months ended June 30, 2020. During the nine months ended June 30, 2019, Barnwell received net cash distributions in the amount of $314,000 from the Kukio Resort Land Development Partnerships after distributing $38,000 to non-controlling interests.
Barnwell has the right to receive distributions fromvia its its non-controlling interestinterests in KD Kona and KKM, in proportion tobased on its partner capitalrespective partnership sharing ratioratios of 75% and 34.45%., respectively. Additionally, Barnwell iswas entitled to a 100% preferred return up to $1,000,000 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. However, because we havethreshold 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 three months ended December 31, 2020. The preferred return payments received during 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 control overmore preferred return outstanding as of December 31, 2020.
During the three months ended December 31, 2020, Barnwell received net cash distributions in the amount of $1,712,000 from the Kukio Resort Land Development Partnerships after distributing $155,000 to non-controlling interests. Of the $1,712,000 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 andfor the abilitythree months ended December 31, 2019.
Barnwell's share of the Kukio Resort Land Development Partnerships to make such distributions is dependent upon their future salesoperating results of lots, we have not recorded any estimated potentialits equity affiliates was income of $1,054,000 for the three months ended December 31, 2020, which includes the $459,000 payment of the preferred return from KKM in our equity in incomediscussed above, as compared to date. However, if sufficient distributions are made by the Kukio Resort Land Development Partnerships in the future, Barnwell will have equity in income of affiliates for the recognition of the preferred return. There is no assurance that any future distributions and resulting preferred returns will occur.
Equity ina loss of affiliates was $111,000 and $179,000$43,000 for the three and nine months ended June 30, 2020, respectively, and $259,000 and $545,000 for the three and nine months ended June 30, 2019, respectively.December 31, 2019. 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 $291,000$263,000 as of June 30,December 31, 2020, 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 adjustmentsadjustment of $5,000 and $11,000$20,000, for the ninethree months ended June 30,December 31, 2020, and 2019, 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, |
| 2020 | | 2019 |
| Revenue | $ | 8,120,000 | | | $ | 1,766,000 | |
| Gross profit | $ | 3,998,000 | | | $ | 796,000 | |
| Net earnings (loss) | $ | 2,612,000 | | | $ | (168,000) | |
|
| | | | | | | |
| | Three months ended June 30, |
| | 2020 | | 2019 |
| Revenue | $ | 496,000 |
| | $ | 575,000 |
|
| Gross profit | $ | 140,000 |
| | $ | 45,000 |
|
| Net loss | $ | (501,000 | ) | | $ | (1,190,000 | ) |
As of December 31, 2020 and September 30, 2020, Barnwell's non-current investment in Kukio Resort Land Development Partnerships was $88,000 and $901,000, respectively. |
| | | | | | | |
| | Nine months ended June 30, |
| | 2020 | | 2019 |
| Revenue | $ | 3,486,000 |
| | $ | 2,894,000 |
|
| Gross profit | $ | 1,587,000 |
| | $ | 896,000 |
|
| Net loss | $ | (804,000 | ) | | $ | (2,252,000 | ) |
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).
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 lotslot sales was $216,400,000$224,500,000 through June 30,December 31, 2020. NoNaN single-family lots were sold during
the ninethree months ended June 30,December 31, 2020 and 1915 single-family lots, of the 80 lots developed within Increment I, remained to be sold as of June 30,December 31, 2020.
Under the terms of the former Increment II agreement with KD II, Kaupulehu Developments was entitled to receive payments from KD II resulting from the sale of lots and/or residential units by KD II within Increment II. Through March 6, 2019, the payments were based on a percentage of gross receipts from KD II's sales ranging from 8% to 10% of the price of improved or unimproved lots or 2.60% to 3.25% of the price of units constructed on a lot, to be determined in the future depending upon a number of variables, including whether the lots are sold prior to improvement. Two ocean front parcels approximately two to three acres in size fronting the ocean were developed within Increment II by KD II, of which one was sold in fiscal 2017 and one was sold in fiscal 2016. The remaining acreage within Increment II is not yet under development.
Through March 6, 2019, Kaupulehu Developments was also entitled to receive 50% of distributions otherwise payable from KD II to its members after the members of KD II have received distributions equal to the original basis of capital invested in the project, up to $8,000,000. Through March 6, 2019, a cumulative total of $3,500,000 was received from KD II under this arrangement, out of the $8,000,000 maximum. The former arrangement also included the rights to three single-family residential lots in Phase 2 of Increment II when developed, at no cost to Barnwell, with a commitment by Barnwell to begin to construct a residence upon each lot within six months of transfer.
Concurrent with the transaction whereby KD II admitted Replay as a new development partner, Kaupulehu Developments entered into new agreements with KD II whereby the aforementioned terms of the former Increment II arrangement were eliminated and Kaupulehu Developments will instead be 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 will not have any partnership interests in KD II or KDK through its interest in Kaupulehu Developments. The new arrangement also gives Barnwell rights to three3 single-family residential lots in Phase 2A of Increment II, and four4 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 four4 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 0.2%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, 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 new agreements also specify that Kaupulehu Developments was to be paid $1,000,000 by KD II prior to admission of Replay as a partner. This $1,000,000 payment had already been received in June 2018 and is included in the $3,500,000 cumulative total as of March 6, 2019 discussed above.
The Increment I percentage of sales arrangement between Barnwell and KD I remains unchanged.
The following table summarizes the Increment I and Increment II revenues from KD I and KD II and the amount of fees directly related to such revenues:
| | | | | | | | | | | |
| | Three months ended
December 31, |
| | 2020 | | 2019 |
| Sale of interest in leasehold land: | | | |
| Revenues - sale of interest in leasehold land | $ | 485,000 | | | $ | 0 | |
| Fees - included in general and administrative expenses | (59,000) | | | 0 | |
| Sale of interest in leasehold land, net of fees paid | $ | 426,000 | | | $ | 0 | |
|
| | | | | | | | | | | | | | | |
| | Three months ended
June 30, | | Nine months ended
June 30, |
| | 2020 | | 2019 | | 2020 | | 2019 |
| Sale of interest in leasehold land: | | | |
| | | | |
| Revenues - sale of interest in leasehold land | $ | — |
| | $ | — |
| | $ | — |
| | $ | 165,000 |
|
| Fees - included in general and administrative expenses | — |
| | — |
| | — |
| | (20,000 | ) |
| Sale of interest in leasehold land, net of fees paid | $ | — |
| | $ | — |
| | $ | — |
| | $ | 145,000 |
|
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. 6. OIL AND NATURAL GAS PROPERTIES
Dispositions
There were no oil and natural gas property dispositions during the three months ended December 31, 2020.
In Octoberthe 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 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 gain or loss recognized, as the sale did not result in a significant alteration of the relationship between capitalized costs and proved reserves.
There were no oil and natural gas property dispositions during the nine months ended June 30, 2019. The $1,519,000 of proceeds from sale of oil and natural gas properties included in the Condensed Consolidated Statement of Cash Flows for the nine months ended June 30, 2019 primarily represents the refund of income taxes previously withheld from what otherwise would have been proceeds on the previous years' oil and natural gas property sales.
Acquisitions
There were no significant amounts paid for oil and natural gas property acquisitions during the ninethree months ended June 30, 2020.
In the quarter ended December 31, 2018, Barnwell acquired additional working interests in oil2020, and natural gas properties located in the Wood River and Twining areas of Alberta, Canada for cash consideration of $355,000. The purchase prices per the agreements were adjusted for customary purchase price adjustments to reflect the economic activity from the effective date to the closing date. The customary adjustments to the purchase prices were finalized during the quarter ended June 30, 2019 and resulted in an immaterial
adjustment. There were no other oil and natural gas property acquisitions during the nine months ended June 30, 2019.
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 ceiling test impairment of $2,689,000 and $4,326,000 during the three and nine months ended June 30, 2020, respectively. There was no$630,000 ceiling test impairment during the three months ended June 30, 2019 and thereDecember 31, 2020. There was a0 ceiling test impairment of $2,413,000 during the ninethree months ended June 30,December 31, 2019.
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. Prior to the quarter ended March 31, 2020, theThe ceiling test calculation as of December 31, 2019 included management’s estimation that the Company had the ability to fund all of the approximately $12,000,000 of 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 approximately $12,000,000 of capital expenditures necessary to develop the proved undeveloped reserves. Therefore, the proved undeveloped reserves continue to behave 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 oilthe 12-month historical rolling average first-day-of-the-month prices remain at current levels or decline further, it is more likely than not thatfrom the 12-month historical rolling average first-day-of-the-month prices used in the December 31, 2020 ceiling calculation, the Company willcould incur further impairment write-downs in future periods in the absence of any offsetting factors that are not currently known or projected.
6. 7. 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 EmployeeExecutive 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 a postretirement medical insurance benefits plan (“Postretirement Medical”) covering eligible U.S. employees.
The following tables detail the components of net periodic benefit (income) cost for Barnwell’s retirement plans:
|
| | | | | | | | | | | | | | | | | | | | | | | |
| | Pension Plan | | SERP | | Postretirement Medical |
| | Three months ended June 30, |
| | 2020 | | 2019 | | 2020 | | 2019 | | 2020 | | 2019 |
| Service cost | $ | — |
| | $ | 41,000 |
| | $ | — |
| | $ | 6,000 |
| | $ | — |
| | $ | — |
|
| Interest cost | 73,000 |
| | 92,000 |
| | 16,000 |
| | 16,000 |
| | 20,000 |
| | 25,000 |
|
| Expected return on plan assets | (173,000 | ) | | (165,000 | ) | | — |
| | — |
| | — |
| | — |
|
| Amortization of prior service cost (credit) | — |
| | 2,000 |
| | — |
| | (2,000 | ) | | — |
| | — |
|
| Amortization of net actuarial loss | — |
| | (3,000 | ) | | — |
| | (1,000 | ) | | 20,000 |
| | 13,000 |
|
| Net periodic benefit (income) cost | $ | (100,000 | ) | | $ | (33,000 | ) | | $ | 16,000 |
| | $ | 19,000 |
| | $ | 40,000 |
| | $ | 38,000 |
|
|
| | | | | | | | | | | | | | | | | | | | | | | |
| | Pension Plan | | SERP | | Postretirement Medical |
| | Nine months ended June 30, |
| | 2020 | | 2019 | | 2020 | | 2019 | | 2020 | | 2019 |
| Service cost | $ | 50,000 |
| | $ | 141,000 |
| | $ | 3,000 |
| | $ | 24,000 |
| | $ | — |
| | $ | — |
|
| Interest cost | 228,000 |
| | 279,000 |
| | 49,000 |
| | 58,000 |
| | 60,000 |
| | 75,000 |
|
| Expected return on plan assets | (508,000 | ) | | (486,000 | ) | | — |
| | — |
| | — |
| | — |
|
| Amortization of prior service cost (credit) | 1,000 |
| | 5,000 |
| | (1,000 | ) | | (4,000 | ) | | — |
| | — |
|
| Amortization of net actuarial loss | 35,000 |
| | 1,000 |
| | 5,000 |
| | 1,000 |
| | 60,000 |
| | 39,000 |
|
| Curtailment cost (income) | 53,000 |
| | — |
| | (53,000 | ) | | — |
| | — |
| | — |
|
| Net periodic benefit (income) cost | $ | (141,000 | ) | | $ | (60,000 | ) | | $ | 3,000 |
| | $ | 79,000 |
| | $ | 120,000 |
| | $ | 114,000 |
|
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.
OnIn December 12, 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. Accordingly,Consequently, current participants in the Pension Plan and SERP no longer accrue new benefits under the plans and new employees of the Company remeasuredare no longer eligible to enter the projected benefit obligationPension Plan and
SERP as participants after December 31, 2019. The freezing of the Pension Plan and SERP as of December 31, 2019. Astriggered a resultcurtailment which required a remeasurement of the remeasurement,projected benefit obligations of the Company recordedPension Plan and SERP and resulted in an $880,000 actuarial gain in accumulated other comprehensive loss during the quarter ended December 31, 2019. The actuarial gain was primarily due to an increase in the market value of Pension Plan assets as well as an increase in the discount rate for both plans during the period. The impact of the Pension Plan and SERP plan freeze resulted in 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 waswere recorded in the first quarter ended December 31, 2019. No remeasurement was required
The following table details the components of net periodic benefit income (cost) for Barnwell’s retirement plans:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Pension Plan | | SERP | | Postretirement Medical |
| | Three months ended December 31, |
| | 2020 | | 2019 | | 2020 | | 2019 | | 2020 | | 2019 |
| Service cost | $ | 0 | | | $ | 50,000 | | | $ | 0 | | | $ | 3,000 | | | $ | 0 | | | $ | 0 | |
| Interest cost | 65,000 | | | 83,000 | | | 13,000 | | | 18,000 | | | 18,000 | | | 20,000 | |
| Expected return on plan assets | (137,000) | | | (163,000) | | | 0 | | | 0 | | | 0 | | | 0 | |
| Amortization of prior service cost (credit) | 0 | | | 1,000 | | | 0 | | | (1,000) | | | 0 | | | 0 | |
| Amortization of net actuarial loss | 10,000 | | | 35,000 | | | 0 | | | 5,000 | | | 23,000 | | | 20,000 | |
| Curtailment cost (income) | 0 | | | 53,000 | | | 0 | | | (53,000) | | | 0 | | | 0 | |
| Net periodic benefit (income) cost | $ | (62,000) | | | $ | 59,000 | | | $ | 13,000 | | | $ | (28,000) | | | $ | 41,000 | | | $ | 40,000 | |
The net periodic benefit (income) cost, including service cost, is included in “General and administrative” expenses in the quarters ended March 31, 2020 and June 30, 2020.Company's Condensed Consolidated Statements of Operations.
Currently, no0 contributions are expected to be made to the Pension Plan during fiscal 2020.2021. The SERP and Postretirement Medical plans are unfunded, and Barnwell funds benefits when payments are made. Expected payments under the Postretirement Medical plan and the SERP for fiscal 20202021 are 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.
7. 8. INCOME TAXES
The components of lossearnings (loss) before income taxes, after adjusting the lossearnings (loss) for non-controlling interests, are as follows:
| | | | | | | | | | | | | | |
| | Three months ended
December 31, |
| | | 2020 | | 2019 |
| United States | | $ | 1,422,000 | | | $ | (147,000) | |
| Canada | | (775,000) | | | (269,000) | |
| | | $ | 647,000 | | | $ | (416,000) | |
|
| | | | | | | | | | | | | | | |
| | Three months ended
June 30, | | Nine months ended
June 30, |
| | 2020 | | 2019 | | 2020 | | 2019 |
| United States | $ | 163,000 |
| | $ | (637,000 | ) | | $ | 717,000 |
| | $ | (3,059,000 | ) |
| Canada | (3,643,000 | ) | | (819,000 | ) | | (6,127,000 | ) | | (5,262,000 | ) |
| | $ | (3,480,000 | ) | | $ | (1,456,000 | ) | | $ | (5,410,000 | ) | | $ | (8,321,000 | ) |
The components of the income tax benefitprovision (benefit) are as follows:
| | | | | | | | | | | |
| Three months ended
December 31, |
| | 2020 | | 2019 |
| Current | $ | 24,000 | | | $ | 7,000 | |
| Deferred | 39,000 | | | (9,000) | |
| | $ | 63,000 | | | $ | (2,000) | |
|
| | | | | | | | | | | | | | | |
| | Three months ended
June 30, | | Nine months ended
June 30, |
| | 2020 | | 2019 | | 2020 | | 2019 |
| Current | $ | (26,000 | ) | | $ | (63,000 | ) | | $ | (19,000 | ) | | $ | (97,000 | ) |
| Deferred | 2,000 |
| | (28,000 | ) | | (7,000 | ) | | (134,000 | ) |
| | $ | (24,000 | ) | | $ | (91,000 | ) | | $ | (26,000 | ) | | $ | (231,000 | ) |
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-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 MarchDecember 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 (“CARES”)Act. The Act was signed into law to provide economic relief to businesses that were negatively impacted byalso extends a number of expiring tax provisions. Additionally, the COVID-19 pandemic. Key tax provisions of the CARES Act currently impacting the Company include the modification of rules related to alternative minimum tax (“AMT”) credits and net operating losses (“NOL”). Other provisions of the CARES Act are currently inapplicable to the Company and/or do not impact the Company’s U.S. federal current and deferred income taxes.
Under previous legislation, 50% of the total AMT credit carryover was refundable upon the filing of the Company's U.S. federal income tax return for the year ended September 30, 2019 and was reclassified to current taxes receivable as of September 30, 2019. The CARES Act provides for an election, which thea 100% deduction for certain business meals incurred in calendar years 2021 and 2022. The Company has made, to take the entire refundable credit in the Company’s U.S. federaldetermined that income tax return foreffects related to the year ended September 30, 2019. As such, the Company reclassified the remaining 50% from non‑current income taxes receivable to current income taxes receivable as of March 31, 2020 as a resultpassage of the CARES Act.
Under previous legislation,Act were not material to the utilization of NOLs generated in tax years beginning after December 31, 2017, which was the Company's fiscal year ended September 30, 2019, was restricted to 80% of taxable income. The CARES Act suspended this restriction through the 2020 tax year (the Company’s fiscal year ending September 30, 2021). This limitation will be reinstated effectivefinancial statements for tax years beginning on or after January 1, 2021.
In the three months ended June 30, 2020, the Government of Alberta announced a reduction of its corporate income tax rate from 10% to 8% effective July 1,December 31, 2020. However, this tax rate reduction had not been enacted as of June 30, 2020, and therefore, is not included in the Company's tax provision for the current period. Additionally, because our Canadian operations are currently generating losses and net Canadian deferred tax assets have a full valuation allowance, the reduction in the tax rate is not expected to have an impact on results of operations.
8.
9. REVENUE FROM CONTRACTS WITH CUSTOMERS
Disaggregation of Revenue
The following tables provideprovides information about disaggregated revenue by revenue streams, reportable segments, geographical region, and timing of revenue recognition for the three and nine months ended June 30,December 31, 2020 and 2019.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Three months ended December 31, 2020 |
| | Oil and natural gas | | Contract drilling | | Land investment | | Other | | Total |
| Revenue streams: | | | | | | | | | |
| Oil | $ | 1,380,000 | | | $ | 0 | | | $ | 0 | | | $ | 0 | | | $ | 1,380,000 | |
| Natural gas | 375,000 | | | 0 | | | 0 | | | 0 | | | 375,000 | |
| Natural gas liquids | 132,000 | | | 0 | | | 0 | | | 0 | | | 132,000 | |
| Drilling and pump | 0 | | | 1,942,000 | | | 0 | | | 0 | | | 1,942,000 | |
| Contingent residual payments | 0 | | | 0 | | | 485,000 | | | 0 | | | 485,000 | |
| Other | 0 | | | 0 | | | 0 | | | 73,000 | | | 73,000 | |
| Total revenues before interest income | $ | 1,887,000 | | | $ | 1,942,000 | | | $ | 485,000 | | | $ | 73,000 | | | $ | 4,387,000 | |
| Geographical regions: | | | | | | | | | |
| United States | $ | 0 | | | $ | 1,942,000 | | | $ | 485,000 | | | $ | 0 | | | $ | 2,427,000 | |
| Canada | 1,887,000 | | | 0 | | | 0 | | | 73,000 | | | 1,960,000 | |
| Total revenues before interest income | $ | 1,887,000 | | | $ | 1,942,000 | | | $ | 485,000 | | | $ | 73,000 | | | $ | 4,387,000 | |
| Timing of revenue recognition: | | | | | | | | | |
| Goods transferred at a point in time | $ | 1,887,000 | | | $ | 0 | | | $ | 485,000 | | | $ | 73,000 | | | $ | 2,445,000 | |
| Services transferred over time | 0 | | | 1,942,000 | | | 0 | | | 0 | | | 1,942,000 | |
| Total revenues before interest income | $ | 1,887,000 | | | $ | 1,942,000 | | | $ | 485,000 | | | $ | 73,000 | | | $ | 4,387,000 | |
|
| | | | | | | | | | | | | | | | | | | | |
| | | Three months ended June 30, 2020 |
| | | Oil and natural gas | | Contract drilling | | Land investment | | Other | | Total |
| Revenue streams: | | | | | | | | | |
| | Oil | $ | 624,000 |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | 624,000 |
|
| | Natural gas | 192,000 |
| | — |
| | — |
| | — |
| | 192,000 |
|
| | Natural gas liquids | 14,000 |
| | — |
| | — |
| | — |
| | 14,000 |
|
| | Drilling and pump | — |
| | 3,040,000 |
| | — |
| | — |
| | 3,040,000 |
|
| | Other | — |
| | — |
| | — |
| | 113,000 |
| | 113,000 |
|
| | Total revenues before interest income | $ | 830,000 |
| | $ | 3,040,000 |
| | $ | — |
| | $ | 113,000 |
| | $ | 3,983,000 |
|
| Geographical regions: | | | | | | | | | |
| | United States | $ | — |
| | $ | 3,040,000 |
| | $ | — |
| | $ | — |
| | $ | 3,040,000 |
|
| | Canada | 830,000 |
| | — |
| | — |
| | 113,000 |
| | 943,000 |
|
| | Total revenues before interest income | $ | 830,000 |
| | $ | 3,040,000 |
| | $ | — |
| | $ | 113,000 |
| | $ | 3,983,000 |
|
| Timing of revenue recognition: | | | | | | | | | |
| | Goods transferred at a point in time | $ | 830,000 |
| | $ | — |
| | $ | — |
| | $ | 113,000 |
| | $ | 943,000 |
|
| | Services transferred over time | — |
| | 3,040,000 |
| | — |
| | — |
| | 3,040,000 |
|
| | Total revenues before interest income | $ | 830,000 |
| | $ | 3,040,000 |
| | $ | — |
| | $ | 113,000 |
| | $ | 3,983,000 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | 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, 2019 |
| | | Oil and natural gas | | Contract drilling | | Land investment | | Other | | Total |
| Revenue streams: | | | | | | | | | |
| | Oil | $ | 1,419,000 |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | 1,419,000 |
|
| | Natural gas | 152,000 |
| | — |
| | — |
| | — |
| | 152,000 |
|
| | Natural gas liquids | 117,000 |
| | — |
| | — |
| | — |
| | 117,000 |
|
| | Drilling and pump | — |
| | 1,689,000 |
| | — |
| | — |
| | 1,689,000 |
|
| | Other | — |
| | — |
| | — |
| | 15,000 |
| | 15,000 |
|
| | Total revenues before interest income | $ | 1,688,000 |
| | $ | 1,689,000 |
| | $ | — |
| | $ | 15,000 |
| | $ | 3,392,000 |
|
| Geographical regions: | | | | | | | | | |
| | United States | $ | — |
| | $ | 1,689,000 |
| | $ | — |
| | $ | — |
| | $ | 1,689,000 |
|
| | Canada | 1,688,000 |
| | — |
| | — |
| | 15,000 |
| | 1,703,000 |
|
| | Total revenues before interest income | $ | 1,688,000 |
| | $ | 1,689,000 |
| | $ | — |
| | $ | 15,000 |
| | $ | 3,392,000 |
|
| Timing of revenue recognition: | | | | | | | | | |
| | Goods transferred at a point in time | $ | 1,688,000 |
| | $ | — |
| | $ | — |
| | $ | 15,000 |
| | $ | 1,703,000 |
|
| | Services transferred over time | — |
| | 1,689,000 |
| | — |
| | — |
| | 1,689,000 |
|
| | Total revenues before interest income | $ | 1,688,000 |
| | $ | 1,689,000 |
| | $ | — |
| | $ | 15,000 |
| | $ | 3,392,000 |
|
|
| | | | | | | | | | | | | | | | | | | | |
| | | Nine months ended June 30, 2020 |
| | | Oil and natural gas | | Contract drilling | | Land investment | | Other | | Total |
| Revenue streams: | | | | | | | | | |
| | Oil | $ | 3,827,000 |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | 3,827,000 |
|
| | Natural gas | 821,000 |
| | — |
| | — |
| | — |
| | 821,000 |
|
| | Natural gas liquids | 233,000 |
| | — |
| | — |
| | — |
| | 233,000 |
|
| | Drilling and pump | — |
| | 8,279,000 |
| | — |
| | — |
| | 8,279,000 |
|
| | Other | — |
| | — |
| | — |
| | 239,000 |
| | 239,000 |
|
| | Total revenues before interest income | $ | 4,881,000 |
| | $ | 8,279,000 |
| | $ | — |
| | $ | 239,000 |
| | $ | 13,399,000 |
|
| Geographical regions: | | | | | | | | | |
| | United States | $ | — |
| | $ | 8,279,000 |
| | $ | — |
| | $ | 7,000 |
| | $ | 8,286,000 |
|
| | Canada | 4,881,000 |
| | — |
| | — |
| | 232,000 |
| | 5,113,000 |
|
| | Total revenues before interest income | $ | 4,881,000 |
| | $ | 8,279,000 |
| | $ | — |
| | $ | 239,000 |
| | $ | 13,399,000 |
|
| Timing of revenue recognition: | | | | | | | | | |
| | Goods transferred at a point in time | $ | 4,881,000 |
| | $ | — |
| | $ | — |
| | $ | 239,000 |
| | $ | 5,120,000 |
|
| | Services transferred over time | — |
| | 8,279,000 |
| | — |
| | — |
| | 8,279,000 |
|
| | Total revenues before interest income | $ | 4,881,000 |
| | $ | 8,279,000 |
| | $ | — |
| | $ | 239,000 |
| | $ | 13,399,000 |
|
|
| | | | | | | | | | | | | | | | | | | | |
| | | Nine months ended June 30, 2019 |
| | | Oil and natural gas | | Contract drilling | | Land investment | | Other | | Total |
| Revenue streams: | | | | | | | | | |
| | Oil | $ | 3,792,000 |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | 3,792,000 |
|
| | Natural gas | 650,000 |
| | — |
| | — |
| | — |
| | 650,000 |
|
| | Natural gas liquids | 402,000 |
| | — |
| | — |
| | — |
| | 402,000 |
|
| | Drilling and pump | — |
| | 3,839,000 |
| | — |
| | — |
| | 3,839,000 |
|
| | Contingent residual payments | — |
| | — |
| | 165,000 |
| | — |
| | 165,000 |
|
| | Other | — |
| | — |
| | — |
| | 69,000 |
| | 69,000 |
|
| | Total revenues before interest income | $ | 4,844,000 |
| | $ | 3,839,000 |
| | $ | 165,000 |
| | $ | 69,000 |
| | $ | 8,917,000 |
|
| Geographical regions: | | | | | | | | | |
| | United States | $ | — |
| | $ | 3,839,000 |
| | $ | 165,000 |
| | $ | 1,000 |
| | $ | 4,005,000 |
|
| | Canada | 4,844,000 |
| | — |
| | — |
| | 68,000 |
| | 4,912,000 |
|
| | Total revenues before interest income | $ | 4,844,000 |
| | $ | 3,839,000 |
| | $ | 165,000 |
| | $ | 69,000 |
| | $ | 8,917,000 |
|
| Timing of revenue recognition: | | | | | | | | | |
| | Goods transferred at a point in time | $ | 4,844,000 |
| | $ | — |
| | $ | 165,000 |
| | $ | 69,000 |
| | $ | 5,078,000 |
|
| | Services transferred over time | — |
| | 3,839,000 |
| | — |
| | — |
| | 3,839,000 |
|
| | Total revenues before interest income | $ | 4,844,000 |
| | $ | 3,839,000 |
| | $ | 165,000 |
| | $ | 69,000 |
| | $ | 8,917,000 |
|
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 |
| Accounts receivables from contracts with customers | $ | 1,625,000 | | | $ | 1,772,000 | |
| Contract assets | 385,000 | | | 413,000 | |
| Contract liabilities | 751,000 | | | 1,097,000 | |
| | | |
| | | |
| | | |
|
| | | | | | | |
| | June 30, 2020 | | September 30, 2019 |
| Accounts receivables from contracts with customers | $ | 2,017,000 |
| | $ | 1,322,000 |
|
| Contract assets | 324,000 |
| | 344,000 |
|
| Contract liabilities | 1,638,000 |
| | 1,633,000 |
|
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 June 30,December 31, 2020 and September 30, 2019,2020, the Company had $1,638,000$751,000 and $1,633,000,$1,097,000, respectively, included in “Other current liabilities” on the balance sheetssheet for those performance obligations expected to be completed in the next twelve months.
During the ninethree months ended June 30,December 31, 2020 and 2019, the amount of revenue recognized that was previously included in contract liabilities as of the beginning of the respective period was $707,000$573,000 and $25,000,$1,480,000, 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 June 30,December 31, 2020, the Company had three contract drilling jobs with original expected durations of greater than one year. For these contracts, approximately 21%7% of the remaining performance obligation of $2,427,000$2,615,000 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 June 30,December 31, 2020 and September 30, 2019,2020, the Company had $216,000$147,000 and $296,000,$145,000, respectively, in unamortized preconstruction costs related to contracts that were not completed. During the three and nine months ended June 30,December 31, 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. During the three and nine months ended June 30, 2019, the amortization of preconstruction costs related to contracts was $80,000 and $129,000, respectively. Additionally, no impairment charges in connection with the Company’s preconstruction costs were recorded during the three and nine months ended June 30,December 31, 2020 and 2019.
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. AsIn September 2020, while making progress towards the drilling of a result, $733,000 of revenue previously recognized was reversedreplacement well in different location, the drill string twisted off and became lodged in the nine months ended June 30, 2020well borehole, which required a stoppage of drilling and the Company recognized a decrease of approximately $670,000 inneed to dislodge and retrieve the broken drill string. Accordingly, the estimated margintotal 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 this contract in the nine months ended June 30, 2020.replacement well recommenced.
9.
10. SEGMENT INFORMATION
Barnwell operates the following segments: 1) acquiring, developing, producing and selling oil and natural gas in Canada (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 no0 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, |
| | 2020 | | 2019 | | 2020 | | 2019 |
| Revenues: |
|
| |
|
| | | | |
| Oil and natural gas | $ | 830,000 |
| | $ | 1,688,000 |
| | $ | 4,881,000 |
| | $ | 4,844,000 |
|
| Contract drilling | 3,040,000 |
| | 1,689,000 |
| | 8,279,000 |
| | 3,839,000 |
|
| Land investment | — |
| | — |
| | — |
| | 165,000 |
|
| Other | 113,000 |
| | 15,000 |
| | 239,000 |
| | 69,000 |
|
| Total before interest income | 3,983,000 |
| | 3,392,000 |
| | 13,399,000 |
| | 8,917,000 |
|
| Interest income | 1,000 |
| | 17,000 |
| | 17,000 |
| | 50,000 |
|
| Total revenues | $ | 3,984,000 |
| | $ | 3,409,000 |
| | $ | 13,416,000 |
| | $ | 8,967,000 |
|
| Depletion, depreciation, and amortization: | |
| | |
| | | | |
| Oil and natural gas | $ | 372,000 |
| | $ | 639,000 |
| | $ | 1,562,000 |
| | $ | 2,072,000 |
|
| Contract drilling | 96,000 |
| | 78,000 |
| | 272,000 |
| | 195,000 |
|
| Other | 10,000 |
| | 14,000 |
| | 36,000 |
| | 41,000 |
|
| Total depletion, depreciation, and amortization | $ | 478,000 |
| | $ | 731,000 |
| | $ | 1,870,000 |
| | $ | 2,308,000 |
|
| Impairment: | | | | | | | |
| Oil and natural gas | $ | 2,689,000 |
| | $ | — |
| | $ | 4,326,000 |
| | $ | 2,413,000 |
|
| Total impairment | $ | 2,689,000 |
| | $ | — |
| | $ | 4,326,000 |
| | $ | 2,413,000 |
|
| Operating (loss) profit (before general and administrative expenses): | |
| | |
| | | | |
| Oil and natural gas | $ | (3,212,000 | ) | | $ | (265,000 | ) | | $ | (4,486,000 | ) | | $ | (3,541,000 | ) |
| Contract drilling | 977,000 |
| | 369,000 |
| | 2,455,000 |
| | (145,000 | ) |
| Land investment | — |
| | — |
| | — |
| | 165,000 |
|
| Other | 103,000 |
| | 1,000 |
| | 203,000 |
| | 28,000 |
|
| Gain on sale of asset | — |
| | — |
| | 1,336,000 |
| | — |
|
| Total operating (loss) profit | (2,132,000 | ) | | 105,000 |
| | (492,000 | ) | | (3,493,000 | ) |
| Equity in loss of affiliates: | |
| | |
| | | | |
| Land investment | (111,000 | ) | | (259,000 | ) | | (179,000 | ) | | (545,000 | ) |
| General and administrative expenses | (1,248,000 | ) | | (1,352,000 | ) | | (4,775,000 | ) | | (4,361,000 | ) |
| Interest expense | (1,000 | ) | | — |
| | (1,000 | ) | | (4,000 | ) |
| Interest income | 1,000 |
| | 17,000 |
| | 17,000 |
| | 50,000 |
|
| Loss before income taxes | $ | (3,491,000 | ) | | $ | (1,489,000 | ) | | $ | (5,430,000 | ) | | $ | (8,353,000 | ) |
10. 11. ACCUMULATED OTHER COMPREHENSIVE LOSS
The changes in each component of accumulated other comprehensive loss were as follows:
| | | | Three months ended
June 30, | | Nine months ended
June 30, | | Three months ended
December 31, |
| | 2020 | | 2019 | | 2020 | | 2019 | | 2020 | | 2019 |
| Foreign currency translation: | |
| | |
| | | | | Foreign currency translation: | | | |
| Beginning accumulated foreign currency translation | $ | 780,000 |
| | $ | 642,000 |
| | $ | 691,000 |
| | $ | 925,000 |
| Beginning accumulated foreign currency translation | $ | 545,000 | | | $ | 691,000 | |
| Change in cumulative translation adjustment before reclassifications | (125,000 | ) | | 89,000 |
| | (36,000 | ) | | (194,000 | ) | Change in cumulative translation adjustment before reclassifications | (234,000) | | | 5,000 | |
| Income taxes | — |
| | — |
| | — |
| | — |
| Income taxes | 0 | | | 0 | |
| Net current period other comprehensive (loss) income | (125,000 | ) | | 89,000 |
| | (36,000 | ) | | (194,000 | ) | Net current period other comprehensive (loss) income | (234,000) | | | 5,000 | |
| Ending accumulated foreign currency translation | 655,000 |
| | 731,000 |
| | 655,000 |
| | 731,000 |
| Ending accumulated foreign currency translation | 311,000 | | | 696,000 | |
| Retirement plans: |
|
| | |
| |
|
| | |
| Retirement plans: | | | |
| Beginning accumulated retirement plans benefit cost | (949,000 | ) | | (1,406,000 | ) | | (3,608,000 | ) | | (1,439,000 | ) | Beginning accumulated retirement plans benefit cost | (1,980,000) | | | (3,608,000) | |
| Amortization of net actuarial loss and prior service cost | 20,000 |
| | 9,000 |
| | 100,000 |
| | 42,000 |
| Amortization of net actuarial loss and prior service cost | 33,000 | | | 60,000 | |
| Net actuarial gains arising during the period | — |
| | — |
| | 2,579,000 |
| | — |
| Net actuarial gains arising during the period | 0 | | | 2,579,000 | |
| Income taxes | — |
| | — |
| | — |
| | — |
| Income taxes | 0 | | | 0 | |
| Net current period other comprehensive income | 20,000 |
| | 9,000 |
| | 2,679,000 |
| | 42,000 |
| Net current period other comprehensive income | 33,000 | | | 2,639,000 | |
| Ending accumulated retirement plans benefit cost | (929,000 | ) | | (1,397,000 | ) | | (929,000 | ) | | (1,397,000 | ) | Ending accumulated retirement plans benefit cost | (1,947,000) | | | (969,000) | |
| Accumulated other comprehensive loss, net of taxes | $ | (274,000 | ) | | $ | (666,000 | ) | | $ | (274,000 | ) | | $ | (666,000 | ) | Accumulated other comprehensive loss, net of taxes | $ | (1,636,000) | | | $ | (273,000) | |
The amortization of accumulated other comprehensivenet actuarial loss componentsand 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 67 for additional details).
11. 12. FAIR VALUE MEASUREMENTS
The carrying values of cash and cash equivalents, accounts and other receivables, accounts payable and accrued current liabilities approximate their fair values due to the short-term nature of the instruments.
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
The estimated fair values of oil and natural gas properties and the asset retirement obligation incurred in the drilling of oil and natural gas wells or assumed in the acquisitions of additional oil and natural gas working interests are based on an estimated discounted cash flow model and market assumptions. The 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.
12.13. 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 CARESCoronavirus Aid, Relief, and Economic Security Act (“CARES”) Act that was signed into law in March 2020. The note matures two years after the date of the loan disbursement and bears interest at a fixed annual rate of 1.00%1%, with the first six months of principal and interest deferred.payments deferred until ten months after the last day of the covered period. Under the terms of the CARES Act, as amended by the Paycheck Protection Program Flexibility Act of 2020, and the PPP, the Company can apply for and be granted forgiveness for all or a portion 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 by the Company over the 24-week period following the loan disbursement date. AtAs of the date of this time,filing, the Company is in the process of applying for forgiveness 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 June 30,December 31, 2020, the current and long-term portions of the loan were $64,000$81,000 and $83,000,$66,000, respectively, and the current portion is included in “Other current liabilities” in the Company's Condensed Consolidated Balance Sheet.
Canada Emergency Business Account Loan 13. LEASES AND GAIN ON SALE OF ASSET
On October 1, 2019, the Company adopted ASU No. 2016-02, “Leases (Topic 842),” using the modified retrospective transition approach and applied the new standard to leases in place as of the adoption date. Results for reporting periods prior to October 1, 2019 have not been adjusted. The Company elected the package of practical expedients allowed upon adoption of Accounting Standards Codification (“ASC”) 842 which, among other things, allowed us to (1) not reassess whether any expired or existing contracts contain leases, (2) carry forward the historical lease classification, and (3) not have to reassess any initial direct cost of any expired or existing leases.
As a result of the adoption of ASC 842, the Company recorded operating lease right-of-use (“ROU”) assets of $2,589,000 and corresponding total operating lease liabilities of $2,589,000 in the Condensed Consolidated Balance Sheets as of October 1, 2019. There was no impact to retained earnings or the Condensed Consolidated Statements of Operations.
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 a result of the sale transaction, the Company recognized a gain of $1,336,000, inclusive of a $236,000 gain from the reversal of the storage yard's lease liability in excess of the right-of-use asset, inDuring the quarter ended MarchDecember 31, 2020.
2020, the Company’s Canadian subsidiary, Barnwell of Canada, received a loan of approximately $31,000 (CAD$40,000) under the Canada Emergency Business Account loan program for small businesses. The Company’sloan is interest-free with no principal payments required until December 31, 2022, after which the remaining ROU assets and lease liabilitiesloan balance is converted to a three year term loan at June 30, 2020, primarily relate to non-cancelable operating leases for our Canadian office space and our leasehold land5% annual interest for Lot 4C held by Kaupulehu Developments. Management determines if a contract is or contains a lease at inception ofpaid monthly. If the
contract or modification Company repays 75% of the contract. A contract is or containsprincipal amount prior to December 31, 2022, there will be loan forgiveness of 25% up to a lease if the contract conveys the right to control the usemaximum of the asset for a period in exchange for consideration.CAD$10,000.
Operating lease ROU assets and liabilities are recognized based on the present value of future minimum lease payments over the expected lease term at commencement date. The Company’s leases do not provide a readily determinable implicit rate; therefore, management uses the Company’s incremental borrowing rate to discount lease payments based on information available at lease commencement. Our lease terms may include options to extend or terminate the lease when it is reasonably certain we will exercise that potion. Lease expense for minimum lease payments is recognized on a straight-line basis over the expected lease terms.
The Company has lease agreements with lease and non-lease components and the non-lease components are excluded in the calculation of the ROU asset and lease liability and expensed as incurred. None of the Company’s lease agreements contain material residual value guarantees or material restrictions or covenants.
A ROU asset and corresponding lease liability is not recorded for leases with an initial term of 12 months or less (short-term leases) as the Company recognizes lease expense for these leases as incurred over the lease term.
Leases recorded on the balance sheet consist of the following:
|
| | | | |
| | | June 30,
2020 |
| Assets: | |
| | Operating lease right-of-use assets | $ | 272,000 |
|
| | Total right-of-use assets | $ | 272,000 |
|
| Liabilities: | |
| | Current portion of operating lease liabilities | $ | 107,000 |
|
| | Operating lease liabilities | 171,000 |
|
| | Total lease liabilities | $ | 278,000 |
|
The components of lease expenses are as follows: |
| | | | | | | |
| | Three months ended
June 30, 2020 | | Nine months ended
June 30, 2020 |
| Operating lease cost | $ | 68,000 |
| | $ | 271,000 |
|
| Short-term lease cost | 17,000 |
| | 52,000 |
|
| Total lease cost | $ | 85,000 |
| | $ | 323,000 |
|
Supplemental information related to leases is as follows:
|
| | | | |
| | | June 30,
2020 |
| Cash paid for amounts included in the measurement of lease liabilities: | |
| | Operating cash flows for operating leases | $ | 158,000 |
|
| Operating leases: | |
| | Weighted-average remaining lease term (in years) | 3.6 |
| | Weighted-average discount rate | 5.84% |
The remaining lease payments for our operating leases as of June 30, 2020, are as follows:
|
| | | |
| Fiscal year ending: | |
| Remainder of 2020 | $ | 30,000 |
|
| 2021 | 121,000 |
|
| 2022 | 60,000 |
|
| 2023 | 30,000 |
|
| 2024 | 30,000 |
|
| Thereafter through 2026 | 38,000 |
|
| Total lease payments | 309,000 |
|
| Less: amounts representing interest | (31,000 | ) |
| Present value of lease liabilities | $ | 278,000 |
|
14.CONTINGENCIES
Legal and Regulatory Matters
Barnwell is routinely involved in disputes with third parties that occasionally require litigation. In addition, Barnwell is required to maintain compliance with all current governmental controls and regulations in the ordinary course of business. Barnwell’s management is not aware of any claims or litigation involving Barnwell that are likely to have a material adverse effect on its results of operations, financial position or liquidity.
In the year ended September 30, 2019, two2 of the water wells drilled by the contract drilling segment for one1 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 one1 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 two2 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 June 30,December 31, 2020 as there is no probable or estimable contingent liability.
OnIn July 28, 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 two2 aforementioned water wells were drilled would be assessed penalty fines because each of the wells waswere calculated to have been drilled beyond the depth permitted by the permit. The wells were drilled beyond permittedto a depth to penetrate certain layers of impermeable rock necessary to access the aquifer at the instructions and on the advice of the hydrologist.hydrologist hired by the owner of the well. The Company’s share of the proposed penalties and fines calculateswas originally calculated to approximately $1,200,000. TheSubsequently, the Staff of the Commission also providedacknowledged that one well had not been drilled to a proposed alternative settlementdepth 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 penaltiesparties entering into an agreement to turn a current well into a monitoring well. The Commission and finesthe aforementioned four parties have worked on this proposed alternative whereby the named parties would be responsible for the drilling of two monitor wells in locations and with specifications that are subject to approval ofproviding 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 potential sites for monitoring wellsproposals 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 would accept the site locations and specifications of the monitor wells currently being considered.Commission. Additionally, it is uncertain as to how the cost of the two monitoring wells under the alternative settlement would be allocated to the named parties of the subject violations. Accordingly, the Company recorded a contingent liability of approximately $250,000$300,000 at JuneSeptember 30, 2020 and there has been no change to the accrual as of December 31, 2020.
15. INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
|
| | | | | | | |
| | Nine months ended
June 30, |
| | 2020 | | 2019 |
| Supplemental disclosure of cash flow information: | | | |
| Cash paid (received) during the year for: | | | |
| Income taxes refunded, net | $ | (166,000 | ) | | $ | (2,298,000 | ) |
Capital expenditure accruals related to oil and natural gas exploration and development increased $635,000decreased $225,000 during the ninethree months ended June 30,December 31, 2020 and decreased $93,000increased $1,661,000 during the ninethree months ended June 30,December 31, 2019. Additionally, capital expenditure accruals related to oil and natural gas asset retirement obligations increased $545,000 and $95,000decreased $176,000 during the ninethree months ended June 30,December 31, 2020 and 2019, respectively.increased $323,000 during the three months ended December 31, 2019.
16. RELATED PARTY TRANSACTIONS
Kaupulehu Developments is entitled to receive payments from the sales of lots and/or residential units by KD I and KD II. Through March 6, 2019, Kaupulehu Developments was also entitled to receive 50% of distributions otherwise payable from KD II to its members up to $8,000,000, of which $3,500,000 was received. 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 and percentage of distribution payments are part of transactions which took place in 2004 and 2006 where Kaupulehu Developments sold its leasehold interests in Increment I and Increment II to KD I's and KD II's predecessors in interest, respectively, which was prior to Barnwell’s affiliation with KD I and KD II which commenced on November 27, 2013, the acquisition date of our ownership interest in the Kukio Resort Land Development Partnerships. Changes to the arrangement above, effective March 7, 2019, are discussed in Note 4.5.
There were no payments made to Kaupulehu Developments by KD I or KD II duringDuring the ninethree months ended June 30, 2020. During the nine months ended June 30, 2019,December 31, 2020, Barnwell received $165,000$485,000 in percentage of sales payments from KD I from the sale of one lot within Phase II of Increment I.
17.SUBSEQUENT EVENTS
In early August 2020, Kaupulehu Developments received two percentage of sales payments totaling $325,000 from the sale of two2 single-family lots within Phase II of Increment I. Financial results fromNo lots were sold during the receiptthree months ended December 31, 2019.
17. 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 these paymentsdirectors 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.
Additionally, in January 2021, Barnwell received a net cash distribution in the amount of $199,000 from the Kukio Resort Land Development Partnerships. Financial results of this distribution will be reflected in Barnwell's quarter ending March 31, 2021.
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 quarterstock on the date of grant of $3.33, vest annually over three years, and year ending September 30, 2020.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, 2019,“Risk Factors” section of Barnwell's Quarterly Report on Form 10-Q for the periods ended December 31, 2019 and March 31, 2020,“Other Events” section of Barnwell's Current Report on Form 8-K dated May 14, 2020, and “Risk Factors” section of this Quarterly Report filed on Form 10-Q.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 and Form 10-K/A Amendment No.2,No. 1, for the fiscal year ended September 30, 2019.2020. There have been no significant changes to these critical accounting policies and estimates during the three and nine months ended June 30,December 31, 2020. We continue to monitor our accounting policies to ensure proper application of current rules and regulations.
Current Outlook
Impact of COVID-19
OnIn March 11, 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 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. The global economy, our markets and our business have been materially and adversely affected by COVID-19.
The COVID-19 outbreak has caused and continues to cause significant reductions in demand for oil and oil prices, which has caused the Company to suspend the development of proved undeveloped reserves and 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 impact of COVID-19 on the 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. Both the health and economic aspects of the COVID-19 pandemic areremain 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, 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 or 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
Our ability to sustain our business in the future will depend on sufficient oil and natural gas operating cash flows, which are highly sensitive to potentially volatile oil and natural gas prices, sufficient contract drilling operating cash flows, which are subject to potentially 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 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 a trend of losses and negative operating cash flows in recentthree of the last four years. Due to uncertainties regarding oil prices and the additionalcontinuing 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 ability to fund our non-discretionary cash outflows and thus substantial doubt about our ability to continue as a going concern for one year from the date of the filing of this report.
ThePrior to and during fiscal 2021, the Company is investigatinginvestigated potential sources of funding, including non-core oil and natural gas property sales, however, no probable sources of such funding have yet been secured. Alternatively, management hasAdditionally, in fiscal 2020, the ability to sellCompany listed its corporate office on the 29th floor of a commercial office building in downtown Honolulu, Hawaii for sale to generate liquidity without impacting operations significantly, in order to help mitigate the substantial doubt about our ability to continue as a going concern. However, the Company’s ability to sell its corporate office at an appropriate time or for a sufficient price is outside of the Company's control and is therefore not probable. Because of this uncertainty as well as the continuing uncertainties regarding the potential duration and depth of the impacts of the COVID-19 pandemic on our business as described above,
substantial doubt about our ability to continue as a going concern for one year from the date of the filing of this report exists.
Impact of Recently Issued Accounting Standards on Future Filings
In June 2016, the Financial Accounting Standards Board (“FASB”)FASB issued Accounting Standards Update (“ASU”)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. 2018-13, “Fair Value Measurement: Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement,” which provides changes to certain fair value disclosure requirements. This ASU is effective for annual reporting periods beginning after December 15, 2019 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.
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 postretirement 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 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. This ASU is effective for annual reporting periods beginning after December 15, 2019 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.
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 (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.
Land Investment Segment
Through Barnwell’s 77.6% interest in Kaupulehu Developments, a Hawaii general partnership, 75% interest in KD Kona, 2013 LLLP, a Hawaii limited liability limited partnership, and 34.45% non-controlling interest in KKM a Hawaii limited liability limited partnership,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 1915 remained to be sold at June 30,December 31, 2020, and a beach club on the portion of the property bordering the Pacific Ocean.
Prior to March 7, 2019, the right to receive percentage of sales payments from KD II resulting from the sale of lots and/or residential units by KD II, within Increment II of Kaupulehu Lot 4A. Increment II is the remaining portion of the approximately 870-acre propertyOcean, and is zoned for single-family and multi-family residential units and a golf course and clubhouse. Kaupulehu Developments was entitled to receive payments from KD II based on a percentage of the gross receipts from KD II’s sales ranging from 8% to 10% of the price of improved or unimproved lots or 2.60% to 3.25% of the price of units constructed on a lot, to be determined in the future depending upon a number of variables, including whether the lots are sold prior to improvement. Kaupulehu Developments was also entitled to receive 50% of any distributions otherwise payable from KD II to it members up to $8,000,000, of which $3,500,000 had been received. Two ocean front parcels approximately two to three acres in size fronting the ocean were developed and sold within Increment II by KD II, and Kaupulehu Developments received percentage of sales payments from those sales. The remaining acreage within Increment II is not yetpartially developed. In February 2019, KD II was granted a 20-year time extension of the allowed zoning for the project that would have otherwise expired in April 2019.
As of March 7, 2019, with the admission of Replay as a new development partner of Increment II, the ownership interests in KD II of KDK and Replay were changed to 55% and 45%, respectively. Additionally, Kaupulehu Developments has the•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,Barnwell. The remaining acreage within Increment II is not yet under development, and there is no assurance that development of such acreage will in compensation for the agreement of these parties to admit the new development partner for Increment II.fact occur.
Prior to March 7, 2019, we had an•An indirect 19.6% non-controlling ownership interest in KD Kukio Resorts, LLLP, KD Maniniowali, LLLP and KDK. As of March 7, 2019, with the admission of Replay as a new development partner of Increment II, we now haveKD I and an indirect 10.8% non-controlling ownership interest in KD II through KDK. Our indirect interest in the other entities remains unchanged. 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 commission on real estate sales by the real estate sales office. KD I has engaged Replay as a consultant to assist with the sales and marketing strategy of Increment I. Replay does not have an ownership interest in KD I.
•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. The lease terminates in December 2025.
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 lossincome attributable to Barnwell for the three months ended June 30,December 31, 2020 totaled $3,456,000,$584,000, a $2,091,000 decrease$998,000 increase in operating results from a net loss of $1,365,000$414,000 for the three months ended June 30,December 31, 2019. The following factors affected the results of operations for the three months ended June 30,December 31, 2020 as compared to the same period in the prior year period:year:
•A $2,947,000$1,097,000 increase in equity in income from affiliates as a result of increased operating results of the Kukio Resort Land Development Partnerships;
•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 in oil and natural gas segment operating results, before income taxes, due primarily attributable to a $2,689,000 ceiling test impairment of $630,000 in the current year period, primarily due to lower 12-month rolling average first-day-of-the-month prices, whereas there was no such ceiling test impairment in the prior year period; partially offset byperiod.
A $608,000 increase in contract drilling segment operating results, before income taxes, primarily resulting from increased activity attributable to a significant well drilling contract.
The net loss attributable to Barnwell for the nine months ended June 30, 2020 totaled $5,384,000, a $2,706,000 improvement in operating results from a net loss of $8,090,000 for the nine months ended June 30, 2019. The following factors affected the results of operations for the nine months ended June 30, 2020 as compared to the prior year period:
A $1,336,000 gain recognized in the current 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;
A $2,600,000 increase in contract drilling segment operating results, before income taxes, primarily resulting from increased activity attributable to a significant well drilling contract;
A $945,000 decrease in oil and natural gas segment operating results, before income taxes, primarily attributable to a $1,913,000 higher ceiling test impairment in the current year period, partially offset by a $421,000 decrease in oil and natural gas operating expenses and a $510,000 decrease in oil and natural gas depletion in the current year period as compared to the same period in the prior year as the prior year period; and
A $414,000 increase in general and administrative expenses primarily due to increased legal, proxy solicitation, proxy advisory, public relations costs and bad debt expense in the current year period as compared to the same period in the prior year, partially offset by lower compensation costs as compared to the same period in the prior year.
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 decreased 3% andincreased 1% in the three and nine months ended June 30,December 31, 2020, respectively, as compared to the same periodsperiod in the prior year. Theyear, and the exchange rate of the Canadian dollar to the U.S. dollar decreased 3%increased 4% at June 30,December 31, 2020, as compared to September 30, 2019.2020. 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 assets are greater than its Canadian dollar liabilities; therefore, increases or decreases in the value of the Canadian dollar to the U.S. dollar generate other comprehensive income or loss, respectively. Other comprehensive income and losses are not included in net loss.earnings (loss). Other comprehensive loss due to foreign currency translation adjustments, net of taxes, for the three months ended June 30,December 31, 2020 was $125,000,$234,000, a $214,000$239,000 change from other comprehensive income due to foreign currency translation adjustments, net of taxes, of $89,000 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, 2020 was $36,000, a $158,000 change from other comprehensive loss due to foreign currency translation adjustments, net of taxes, of $194,000$5,000 for the same period in the prior year. There were no taxes on other comprehensive income (loss) due to foreign currency translation adjustments in the three and nine months ended June 30,December 31, 2020 and 2019 due to a full valuation allowance on the related deferred tax asset.assets.
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 | % |
|
| | | | | | | | | | | | | | |
| | Average Price Per Unit |
| | Three months ended | | Increase |
| | June 30, | | (Decrease) |
| | 2020 | | 2019 | | $ | | % |
| Natural Gas (Mcf)* | $ | 1.42 |
| | $ | 0.87 |
| | $ | 0.55 |
| | 63 | % |
| Oil (Bbls)** | $ | 17.24 |
| | $ | 52.56 |
| | $ | (35.32 | ) | | (67 | %) |
| Liquids (Bbls)** | $ | 4.67 |
| | $ | 23.40 |
| | $ | (18.73 | ) | | (80 | %) |
|
| | | | | | | | | | | | | | |
| | Average Price Per Unit |
| | Nine months ended | | Increase |
| | June 30, | | (Decrease) |
| | 2020 | | 2019 | | $ | | % |
| Natural Gas (Mcf)* | $ | 1.62 |
| | $ | 1.31 |
| | $ | 0.31 |
| | 24 | % |
| Oil (Bbls)** | $ | 33.62 |
| | $ | 39.92 |
| | $ | (6.30 | ) | | (16 | %) |
| Liquids (Bbls)** | $ | 16.64 |
| | $ | 28.70 |
| | $ | (12.06 | ) | | (42 | %) |
|
| | | | | | | | | | | |
| | Net Production |
| | Three months ended | | Increase |
| | June 30, | | (Decrease) |
| | 2020 | | 2019 | | Units | | % |
| Natural Gas (Mcf)* | 125,000 |
| | 170,000 |
| | (45,000 | ) | | (26 | %) |
| Oil (Bbls)** | 34,000 |
| | 27,000 |
| | 7,000 |
| | 26 | % |
| Liquids (Bbls)** | 3,000 |
| | 5,000 |
| | (2,000 | ) | | (40 | %) |
| | | | Net Production | | Net Production |
| | Nine months ended | | Increase | | Three months ended | | Increase |
| | June 30, | | (Decrease) | | December 31, | | (Decrease) |
| | 2020 | | 2019 | | Units | | % | | 2020 | | 2019 | | Units | | % |
| Natural Gas (Mcf)* | 480,000 |
| | 481,000 |
| | (1,000 | ) | | — | % | Natural Gas (Mcf)* | 171,000 | | | 168,000 | | | 3,000 | | | 2 | % |
| Oil (Bbls)** | 113,000 |
| | 95,000 |
| | 18,000 |
| | 19 | % | Oil (Bbls)** | 39,000 | | | 35,000 | | | 4,000 | | | 11 | % |
| Liquids (Bbls)** | 14,000 |
| | 14,000 |
| | — |
| | — | % | Liquids (Bbls)** | 6,000 | | | 5,000 | | | 1,000 | | | 20 | % |
* Mcf = 1,000 cubic feet. Natural gas price per unit is net of pipeline charges.
** Bbl = stock tank barrel equivalent to 42 U.S. gallons
The oil and natural gas segment generated a $3,212,000$373,000 of operating loss before general and administrative expenses in the three months ended June 30,December 31, 2020, a decrease in operating results of $2,947,000$695,000 as compared to the $265,000a $322,000 operating loss before general and administrative expenses generatedprofit during the same period of the prior year. The oil and natural gas segment generated a $4,486,000 operating loss before
general and administrative expenses in the nine months ended June 30, 2020, a decrease in operating results of $945,000 as compared to the $3,541,000 operating loss before general and administrative expenses generated during the same period of the prior year. The operating losses for the current year periods include the impact of a ceiling test impairment of $2,689,000 and $4,326,000 for the three and nine months ended June 30, 2020, respectively. There was no ceiling test impairment during the three months ended June 30, 2019 and a $2,413,000$630,000 ceiling test impairment included in the operating loss forin the nine months ended June 30, 2019.current year, whereas there was no ceiling test impairment in the prior year period.
Oil and natural gas revenues decreased $858,000 (51%$254,000 (12%) for the three months ended June 30,December 31, 2020, as compared to the same period in the prior year, primarily due primarily to a 67%27% decrease in oil prices. The decreaseprices, which was partially offset by a 26%11% increase in oil production resulting from a new well drilled in the Spirit River area which began production in mid-November 2019. Oil and natural gas revenues increased $37,000 (1%) and thus were relatively unchanged for the nine months ended June 30, 2020, as compared to the same period in the prior year.
Oil and natural gas operating expenses decreased $333,000 (25%) and $421,000 (11%increased $222,000 (18%) for the three and nine months ended June 30,December 31, 2020, respectively, as compared to the same periods in the prior year period, primarily due to significant repair and maintenance costs at the Twining property includedan increase in the prior year periods, whereas there were no such costsoil production in the current year periods. The decreases were also due to shut-in of wells with relatively high operating costs and reductions in operator time and discounted costs obtained from vendors that were negotiated in light of the extremely low oil prices.
period. Oil and natural gas segment depletion decreased $267,000 (42%) and $510,000 (25%$411,000 (68%) for the three and nine months ended June 30,December 31, 2020, respectively, as compared to the same periods in the prior year period, primarily due to a decrease in the depletion rates for the current year periods,rate as compared to the same periods in prior year, due primarily toa result of ceiling test impairment write-downs in the prior fiscal year.
The well drilled in the Spirit River area commenced production on November 17, 2019 and produced approximately 4,000 and 24,000 net barrels of oil during the three and nine months ended June 30, 2020, respectively; these net oil production amounts were net of a 6% royalty rate, which has increased to 17% beginning in April 2020 as the new well royalty holiday ended. The Company's share of recent net oil production in the last week of July 2020 from this well averaged approximately 46 barrels per day, which represents a 58% decrease from the average net daily oil production of 110 barrels per day during the three months ended March 31, 2020. The decline is due to both natural declines in production as well as the higher royalty rate due to the expiry of the royalty holiday.
The new well that was drilled and completed in December 2019 at the Twining area began producing oil and natural gas in January 2020. This well contributed approximately 7,200 barrels of net oil production from January through June 2020, representing 11% and 6% of total net oil production for the three and nine months ended June 30, 2020, respectively. The well was temporarily shut-in from mid-April 2020 to mid-May 2020 due to decreased oil prices. Recent net oil production from this well was approximately 108 barrels per day.
As a result of the unprecedented contraction of global oil demand resulting from the COVID-19 pandemic combined with the price war between Saudi Arabia and Russia, the oil price declines that began in March 2020 became more pronounced since then, with oil futures prices temporarily declining to unprecedented levels below zero. While oil prices have recovered somewhat from those recordthe 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 KD II and the amount of fees directly related to such revenues:
| | | | | | | | | | | | | | |
| | | Three months ended
December 31, |
| | | 2020 | | 2019 |
| Sale of interest in leasehold land: | | | | |
| Revenues – sale of interest in leasehold land | | $ | 485,000 | | | $ | — | |
| Fees - included in general and administrative expenses | | (59,000) | | | — | |
| Sale of interest in leasehold land, net of fees paid | | $ | 426,000 | | | $ | — | |
|
| | | | | | | | | | | | | | | |
| | Three months ended
June 30, | | Nine months ended
June 30, |
| | 2020 | | 2019 | | 2020 | | 2019 |
| Sale of interest in leasehold land: | | | |
| | | | |
| Revenues - sale of interest in leasehold land | $ | — |
| | $ | — |
| | $ | — |
| | $ | 165,000 |
|
| Fees - included in general and administrative expenses | — |
| | — |
| | — |
| | (20,000 | ) |
| Sale of interest in leasehold land, net of fees paid | $ | — |
| | $ | — |
| | $ | — |
| | $ | 145,000 |
|
No lots were sold duringDuring the ninethree months ended June 30, 2020. During the nine months ended June 30, 2019,December 31, 2020, Barnwell received $165,000$485,000 in percentage of sales payments from KD I from the sale of onetwo single-family lotlots within Phase II of Increment I. No lots were sold during the three months ended December 31, 2019.
As of June 30,December 31, 2020, 1915 single-family lots, of the 80 lots developed within Increment I, remained to be sold. As discussed in the Overview section above, Replay was admitted as a new development partner of Increment II on March 7, 2019. 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.II, or that the remaining acreage within Increment II will be developed.
Contract Drillingdrilling
Contract drilling revenues and contract drilling costs increased $1,351,000 (80%decreased $704,000 (27%) and $725,000 (58%$706,000 (39%), respectively, for the three months ended June 30,December 31, 2020, as compared to the same period in the prior year. The contract drilling segment generated a $977,000$758,000 operating profit before general and administrative expenses in the three months ended June 30,December 31, 2020, an increase in operating results of $608,000$11,000 as compared to the $369,000a $747,000 operating profit generated during the same period of the prior year.
ContractThe decrease in contract drilling revenues and contract drilling costs increased $4,440,000 (116%) and $1,763,000 (47%), respectively, for the ninethree months ended June 30,December 31, 2020 as compared to the same period in the prior year. The contract drilling segment generated a $2,455,000 operating profit before general and administrative expenses in the nine months ended June 30, 2020, an increase in operating results of $2,600,000 as compared to the $145,000 operating loss generated during the same period of the prior year. The increase in operating results wasyear is primarily due to a significant well drilling contract in the prior year period. The significant well drilling contract was for multiple wells that isand 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 currentprior year periodsperiod with crews working extended hours. TheHowever, operational activity related to this contract has been winding down in the quarter ended December 31, 2020 and thus contract drilling revenues and costs have decreased in the current year period increase in operating results was partially offset by a decrease in operating results dueas compared to the unfavorable impactsame period of the unsuccessful removal of a hole opener at the bottom of a water well as discussed below.
The significantly increased operational activity that has led to the increased contract drilling segment operating results for the three and nine month periods ended June 30, 2020, has declined since June 30, 2020,
as the aforementionedprior year. This significant well drilling contract is nearing completion, such thatwas essentially complete as of December 31, 2020. Accordingly, contract drilling revenues and costs for the remaining quarters of fiscal 2021 are anticipatedexpected to declinebe lower as compared to recently completed quarters.the same periods 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 wereare 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. AsIn September 2020, while making progress towards the drilling of a result, $733,000 of revenue previously recognized was reversedreplacement well in different location, the drill string twisted off and became lodged in the nine months ended June 30, 2020well borehole, which required a
stoppage of drilling and the Company recognized a decrease of approximately $670,000 inneed to dislodge and retrieve the broken drill string. Accordingly, the estimated margintotal 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 this contract in the nine months ended June 30, 2020.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 the 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 June 30,December 31, 2020 as there is no probable or estimable contingent liability.
OnIn July 28, 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 waswere calculated to have been drilled beyond the depth permitted by the permit. The wells were drilled beyond permittedto a depth to penetrate certain layers of impermeable rock necessary to access the aquifer at the instructions and on the advice of the hydrologist.hydrologist hired by the owner of the well. The Company’s share of the proposed penalties and fines calculateswas originally calculated to approximately $1,200,000. TheSubsequently, the Staff of the Commission also providedacknowledged that one well had not been drilled to a proposed alternative settlementdepth 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 penaltiesparties entering into an agreement to turn a current well into a monitoring well. The Commission and finesthe aforementioned four parties have worked on this proposed alternative whereby the named parties would be responsible for the drilling of two monitor wells in locations and with specifications that are subject to approval ofproviding 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 potential sites for monitoring wellsproposals 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 would accept the site locations and specifications of the monitor wells currently being considered.Commission. Additionally, it is uncertain as to how the cost of the two monitoring wells under the alternative settlement would be allocated to the named parties of the subject violations. Accordingly, the Company recorded a contingent liability of approximately $250,000$300,000 at JuneSeptember 30, 2020 and no subsequent accruals have been recorded as of December 31, 2020.
Contract drilling revenues and costs are not seasonal in nature, but can fluctuate significantly based on the awarding and timing of contracts, which are determined by contract drilling customer demand. 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 continues to work, the impact of COVID-19 on the 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 $104,000 (8%$311,000 (21%) for the three months ended June 30,December 31, 2020, as compared to the same period in the prior year. The decrease was primarily due to a reductiondecrease in compensation costs and professional fees related to audit fees in the current year period, partially offset by higher bad debt expense related to oil and natural gas segment joint venture partners that encountered liquidity issues in the current year period, as compared to same period in the prior year. General and administrative expenses increased $414,000 (9%) for the nine months ended June 30, 2020, as compared to the same period in the prior year. The increase was due to increased legal proxy solicitation, proxy advisory, public relations costs and bad debt expenseservices in the current year period, as compared to the same period in the prior year.year period. The increasedecrease was partially offset by lower compensation costsincreased professional fees related to land investment segment proceeds in the current year period, as compared to the same period in the prior year.
Depletion, Depreciation,depreciation, and Amortizationamortization
Depletion, depreciation, and amortization decreased $253,000 (35%) and $438,000 (19%$429,000 (61%) for the three and nine months ended June 30,December 31, 2020, respectively, as compared to the same periodsperiod in the prior year, primarily due to thea decrease in oil and natural gasthe depletion rate 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 of $2,689,000 and $4,326,000 during the three and nine months ended June 30, 2020, respectively.December 31, 2020. There was no ceiling test impairment during the three months ended June 30, 2019 and a ceiling test impairment of $2,413,000 during the nine months ended June 30,December 31, 2019.
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. Prior to the quarter ended March 31, 2020, theThe ceiling test calculation at December 31, 2019 included management’s estimation that the Company had the ability to fund all of the approximately $12,000,000 of 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 approximately $12,000,000 of capital expenditures necessary to develop the proved
undeveloped reserves. Therefore, the proved undeveloped reserves continue to behave 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 oilthe 12-month historical rolling average first-day-of-the-month prices remain at current levels or decline further, it is more likely than not thatfrom the 12-month historical rolling average first-day-of-the-month prices used in the December 31, 2020 ceiling calculation, the Company willcould incur further impairment write-downs in future periods in the absence of any offsetting factors that are not currently known or projected.
Gain on Sale of 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 a result of the sale transaction, the Company recognized a gain of $1,336,000, inclusive of a $236,000 gain from the reversal of the storage yard's lease liability in excess of the right-of-use asset, in the quarter ended March 31, 2020.
Equity in Lossincome (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 lossesincome of $111,000 and $179,000$1,054,000 during the three and nine months ended June 30,December 31, 2020, respectively, as compared to allocated losses of $259,000 and $545,000$43,000 during the three and nine months ended June 30, 2019, respectively.December 31, 2019. The changeincrease in the allocated partnership lossesincome is primarily due to the investee partnerships' improved operating resultsKukio Resort Land Development Partnerships' sale of two lots during the current year period, whereas there was no lot sales in the prior year period, as well as a significant increase in real estate resale activity in the current year period for which the Kukio Resort Land Development Partnerships' real estate sales office earns commissions revenue. Additionally, the increase is also attributed to $459,000 in preferred return payments received from KKM, 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 three and nine months ended June 30,December 31, 2020. The preferred return payments received during 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 compared toof December 31, 2020.
During the same periodsthree months ended December 31, 2020, Barnwell received net cash distributions in the prior year.amount of $1,712,000 from the Kukio Resort Land Development Partnerships after distributing $155,000 to non-controlling interests. Of the $1,712,000 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 three months ended December 31, 2019.
Income Taxestaxes
Barnwell’s effective consolidated income tax benefit rate for the three months ended December 31, 2020, after adjusting lossearnings (loss) before income taxes for non-controlling interests, was 1% for the three months ended June 30, 2020 and nil for the nine months ended June 30, 2020,10%, as compared to an effective income tax benefit rate of 6% and 3%nil for the three and nine months ended June 30, 2019, respectively. December 31, 2019.
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 Loss Attributableearnings (loss) attributable to Non-controlling Interestsnon-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 lossearnings attributable to non-controlling interests totaled $11,000 and $20,000 for the three and nine months ended June 30,December 31, 2020 respectively,totaled $159,000, as compared to net loss attributable to non-controlling interests of $33,000 and $32,000$5,000 for the same periodsperiod in the prior year. The changeincrease of $22,000 (67%) and $12,000
(38%) for the three and nine months, respectively,$164,000 is primarily due to a decreasepercentage 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 Partnership lossesPartnerships' income in the current year periodsperiod as compared to the same periodsperiod in the prior year.
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 June 30,December 31, 2020, Barnwell had $1,691,000$5,370,000 in working capital.
Cash Flows
Cash flows provided by operationsoperating activities totaled $472,000$80,000 for the ninethree months ended June 30,December 31, 2020, as compared to cash flows used in operationsoperating activities of $1,631,000 during$1,366,000 for the same period in the prior year. This $1,446,000 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. The $2,103,000 changeyear, and fluctuations in operating cashworking capital.
Cash flows forprovided by investing activities totaled $875,000 during the ninethree months ended June 30,December 31, 2020, as compared to the prior year was primarily due to higher operating results for the contract drilling segment as well as higher operating results, before non-cash impairment and depletion expenses, for the oil and natural gas segment as compared to the prior year period. The change was also due to changes in working capital, primarily attributed to fluctuations in contract liabilities in the current period as compared to the prior year period.
Cashcash flows used in investing activities totaled $1,116,000 during the nine months ended June 30, 2020, as compared to $802,000 of net cash provided by investing activities$863,000 during the same period of the prior year. This $1,918,000 decrease$1,738,000 increase in investing cash flows was primarily due to $741,000a decrease of $1,080,000 in maturitiesoil and natural gas capital expenditures, a $426,000 increase in percentage of certificatessales proceeds received, net of depositfees, and an increase of $813,000 received in distributions from equity investees in excess of earnings in the prior fiscalcurrent year period as compared to none in the currentprior year period, partially offset by a $911,000$594,000 decrease in proceeds from the sale of oil and natural gas properties in the current period as compared to the prior year period, and an increase of $2,451,000 in oil and natural gas capital expenditures, mainly attributed to new wells drilled in the Twining and Spirit River areas in the current period, as compared to the prior year period. These items were partially offset by an increase of $1,100,000 in proceeds in the current year period attributed to 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, and a decrease of $906,000 in other capital expenditures in the current year period, primarily due to the purchase of a water well drilling rig and other ancillary equipment in the prior year period.
Net cash provided by financing activities totaled $147,000 for the nine months ended June 30, 2020, as compared to net cashCash flows used in financing activities of $110,000totaled $217,000 during the three months ended December 31, 2020. There was no cash flows from financing activities for the ninethree months ended June 30,December 31, 2019. The $257,000$217,000 change in financing cash flows was primarily attributed to an increase of $147,000 in long-term borrowings attributed to the PPP loan received during the current year period and $110,000$248,000 in distributions to non-controlling interests in the priorcurrent year, which was partially offset by an increase of $31,000 in long-term debt borrowings attributed to the Canada Emergency Business Account Loan received during the current year period.
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 PPPPaycheck Protection Program (“PPP”) pursuant to the CARESCoronavirus Aid, Relief, and Economic Security (“CARES”) Act that was signed into law in March 2020. The note matures two years after the date of the loan disbursement and bears interest at a
fixed annual rate of 1.00%1%, with the first six months of principal and interest deferred.payments deferred until ten months after the last day of the covered period. Under the terms of the CARES Act, as amended by the Paycheck Protection Program Flexibility Act of 2020, and the PPP, the Company can apply for and be granted forgiveness for all or a portion 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 by the Company over the 24-week period following the loan disbursement date. AtAs of the date of this time,filing, the Company is in the process of applying for forgiveness and believes that its use of the loan proceeds will meet the conditions for forgiveness under the PPP.PPP and expects the loan to be recorded as income when legal forgiveness is obtained.
Canada Emergency Wage SubsidyBusiness Account Loan
During the quarter ended June 30,December 31, 2020, the Company’s two subsidiaries with Canadian operations,subsidiary, Barnwell of Canada, Limited, and Octavian Oil, Ltd., qualified forreceived a loan of approximately $31,000 (CAD$40,000) under the Canada Emergency Wage Subsidy (“CEWS”).Business Account loan program for small businesses. The CEWSloan is interest-free with no principal payments required until December 31, 2022, after which the remaining loan balance is converted to a program that will provide a subsidy ofthree year term loan at 5% annual interest paid monthly. If the Company repays 75% of eligible employee wagesthe principal amount prior to December 31, 2022, there will be loan forgiveness of 25% up to a maximum of approximately $600 per week for each employee. As of the date of this report, the Company received a total of approximately $67,000 in CEWS subsidies. The CEWS is currently scheduled to run through August 29, 2020.CAD$10,000.
Going Concern
Our ability to sustain our business in the future will depend on sufficient oil and natural gas operating cash flows, which are highly sensitive to potentially volatile oil and natural gas prices, sufficient contract drilling operating cash flows, which are subject to potentially 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 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 a trend of losses and negative operating cash flows in recentthree of the last four years. Due to uncertainties regarding oil prices and the additionalcontinuing 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 ability to fund our non-discretionary cash outflows and thus substantial doubt about our ability to continue as a going concern for one year from the date of the filing of this report.
ThePrior to and during fiscal 2021, the Company is investigatinginvestigated potential sources of funding, including non-core oil and natural gas property sales, however, no probable sources of such funding have yet been secured. Alternatively, management hasAdditionally, in fiscal 2020, the ability to sellCompany listed its corporate office on the 29th floor of a commercial office building in downtown Honolulu, Hawaii for sale to generate liquidity without impacting operations significantly, in order to mitigate the substantial doubt about our ability to continue as a going concern. However, the Company’s ability to sell its corporate office at an appropriate time or for a sufficient price is outside of the Company's control and is therefore not probable. Because of this uncertainty as well as the continuing uncertainties regarding the potential duration and depth of the impacts of the COVID-19 pandemic on our
business as described above, substantial doubt about our ability to continue as a going concern for one year from the date of the filing of this report exists.
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 $26,000 and $3,144,000 for the three and nine months ended June 30, 2020, respectively, whereas these amounts were not significant for the three and nine months ended June 30, 2019. In the quarter ended December 31, 2019, Barnwell drilled one gross (1.00 net) development well in the Twining area and incurred approximately $2,400,000 in capital expenditures for this well during the nine months ended June 30, 2020. Also in the
quarter ended December 31, 2019, Barnwell participated in the drilling of one gross (0.28 net) development well in the Spirit River area and incurred approximately $670,000 in capital expenditures for this well during the nine months ended June 30, 2020.
Due to the uncertainties created by the COVID-19 pandemic, investments in oil and natural gas properties have been suspended indefinitely.
Oil and Natural Gas Property Acquisitions and Dispositions
Dispositions
In October 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 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 gain or loss recognized, as the sale did not result in a significant alteration of the relationship between capitalized costs and proved reserves.
There were no oil and natural gas property dispositions during the nine months ended June 30, 2019. The $1,519,000 of proceeds from sale of oil and natural gas properties included in the Condensed Consolidated Statement of Cash Flows for the nine months ended June 30, 2019 primarily represents the refund of income taxes previously withheld from what otherwise would have been proceeds on the previous years' oil and natural gas property sales.
In January 2020, Barnwell engaged a broker to market its non-core oil and natural gas properties in areas other than at Twining. No significant bids were received on their due date and the marketed properties remain open for bid.
Acquisitions
There were no significant amounts paid for oil and natural gas property acquisitions during the nine months ended June 30, 2020.
In the quarter ended December 31, 2018, Barnwell acquired additional working interests in oil and natural gas properties located in the Wood River and Twining areas of Alberta, Canada for cash consideration of $355,000. The purchase prices per the agreements were adjusted for customary purchase price adjustments to reflect the economic activity from the effective date to the closing date. The customary adjustments to the purchase prices were finalized during the quarter ended June 30, 2019 and resulted in an immaterial adjustment. There were no other oil and natural gas property acquisitions during the nine months ended June 30, 2019.
NYSE American Continued Listing Standard
On January 13, 2020, the Company received a letter from the NYSE American LLCstaff (the “Exchange”“Exchange Staff”) Staff indicating that the Company iswas not in compliance with certain continued listing standards relating to stockholders equity as set forth in Part 10, Section 1003Sections 1003(a)(i) and (a)(ii) of the NYSE American Company Guide (the “Guide”). Based on the Company’s annual report on Form 10-K for the fiscal year ended September 30, 2019, which was filed with the SEC on December 20, 2019, the Company was below compliance with Part 10, Sections
1003(a)(i) and (a)(ii) of the Guide since it reported stockholders’ equity of $1.2 million and net losses in fiscal years ended September 30, 2019, September 30, 2018 and September 30, 2016. The Company’s failure to meet the NYSE American’s stockholders’ equity requirements and the exceptions resulted in a risk that our common stock may be delisted.
In accordance with the Exchange’sNYSE American’s policies and procedures, the Company submitted itsa plan of compliance (the “Plan”) addressing how the Company intendsintended to regain compliance with Part 10, Section 1003 of the Guide. On April 2, 2020, the ExchangeNYSE 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 (the “Plan Period”). The Company has been and will continue to be subject to periodic review by Exchange Staff during the Plan Period. The Plan was submitted to the ExchangeNYSE American before the start of the COVID-19 pandemic-related low commodity price environment, the oil price war between Saudi Arabia 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 Exchange’sNYSE American’s listing standards. If 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 ExchangeNYSE American may initiate delisting procedures as appropriate.
On July 2, 2020, the Company submitted its update to the Plan as was required by the Exchange. In that update, the Company reported that due largely to the impact of COVID-19 on the outlook for oil prices and other economic impacts of COVID-19 that could be relevant to the Company’s operations, the Company expects that it likely will not obtain a stockholders’ equity of $4,000,000 by July 13, 2021, the end of the Plan “cure period.” Additionally, theThe Company’s reported stockholders’ equity fell from $2,049,000 at March 31, 2020 to a stockholders’ deficit of $1,512,000$2,045,000 at JuneSeptember 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 in compliance with the NYSE American continued listing standards relating to stockholders’ equity to which the Plan relates; specifically Section 1003(a)(i) (requiring stockholders’ equity of $2.0 million or more if it has reported losses from continuing operations and/or net losses in two of its three most recent fiscal years) and Section 1003(a)(ii) (requiring. 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 $4.0 million or more if it has reported losses from continuing operations and/or net lossesthe Plan Period and accordingly result in three of its four most recent fiscal years).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 Exchange other than acknowledgment of receipt ofNYSE American regarding the update.January 2021 Plan updates. If the ExchangeNYSE 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 additions and revisions to estimated asset retirement obligations, totaled $139,000 for the three months ended December 31, 2020, as compared to $3,105,000 for the same period in the prior year.
Due to the uncertainties created by the COVID-19 pandemic, investments in oil and natural gas properties have been suspended pending suitable market opportunities and sufficient sources of funding.
Oil and Natural Gas Properties Acquisitions and Dispositions
Dispositions
There were no oil and natural gas property dispositions during the three months ended December 31, 2020.
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.
Acquisitions
There were no significant amounts paid for oil and natural gas property acquisitions during the three months ended December 31, 2020, and 2019.
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 June 30,December 31, 2020, 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 June 30,December 31, 2020 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 June 30,December 31, 2020 that materially affected, or is reasonably likely to materially affect, Barnwell’s internal control over financial reporting.
PART II - OTHER INFORMATION
ITEM 1A. RISK FACTORS
We are updating the risk factor disclosure in “Item 1A. Risk Factors” in our Annual Report on Form 10-K, as amended by our Form 10-K/A Amendment No. 1 and Form 10-K/A Amendment No. 2, for the fiscal year ended September 30, 2019 by adding the discussion below.
Entity-Wide Risks
Our business operations and financial condition have been and may continue to be materially and adversely affected by the outbreak of a novel strain of coronavirus disease, referred to as COVID-19.
An outbreak of a novel strain of coronavirus, which causes the disease referred to as COVID-19, emerged in Wuhan, China in late 2019. The novel coronavirus is considered highly contagious and has spread to most countries around the world and throughout the United States, creating a serious impact on customers, workforces and suppliers, disrupting economies and financial markets and leading to a world-wide economic downturn. On March 11, 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 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. The Company is currently following the recommendations of local and federal health authorities to minimize exposure risk for its various stakeholders, including employees.
The global economy, our markets and our business have been materially and adversely affected by COVID-19. In the first calendar quarter of 2020, the COVID-19 outbreak caused significant reductions in demand for oil and oil prices, which has caused the Company to suspend the development of proven undeveloped reserves and has impacted the Company’s financial condition and outlook. While the Company’s contract drilling segment continues to work, the impact of COVID-19 on the 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. Both the health and economic aspects of the COVID-19 pandemic are 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, 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 or 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.
Our failure to maintain continued compliance with the listing requirements of the NYSE American exchange could result in the delisting of our common stock.
Our common stock is listed on the NYSE American. The rules of NYSE American provide that shares be delisted from trading, if, among other things, the Company has failed to comply with its listing agreements relating to stockholders’ equity. For example, the NYSE American may consider suspending trading in, or removing the listing of, securities of an issuer that has stockholders’ equity of less than (i) $6.0 million if such issuer has sustained losses from continuing operations and/or net losses in its five most recent fiscal years, (ii) $4.0 million if such issuer has sustained losses from continuing operations and/or net losses in three of its four most recent fiscal years, and (iii) $2.0 million if such issuer has sustained losses from continuing operations and/or net losses in two of its three most recent fiscal years. As of September 30, 2019, the Company had stockholders’ equity of approximately $1.2 million, and we may not be able to maintain stockholders’ equity in the future. Even if an issuer has a stockholders’ deficit, the NYSE American will not normally consider delisting securities of an issuer that fails to meet these requirements if the issuer has (1) average global market capitalization of at least $50,000,000; or total assets and revenue of $50,000,000 in its last fiscal year, or in two of its last three fiscal years; and (2) the issuer has at least 1,100,000 shares publicly held, a market value of publicly held shares of at least $15,000,000 and 400 round lot shareholders. As of September 30, 2019, the Company’s total value of market capitalization was approximately $4,304,000. As such, we do not currently meet these exceptions and there is a risk that our common stock may be delisted as a result of our failure to meet the minimum stockholders' equity requirement for continued listing. The NYSE American provides for an 18-month “cure period” for the Company to regain the minimum stockholders’ equity requirement, however if the Company is unable to do so, the NYSE American may delist the Company’s common stock.
On January 13, 2020, the Company received a letter from the Exchange Staff indicating that the Company is not in compliance with certain continued listing standards relating to stockholders equity as set forth in Part 10, Section 1003 of the Guide. Based on the Company’s annual report on Form 10-K for the fiscal year ended September 30, 2019, which was filed with the SEC on December 20, 2019, the Company was below compliance with Part 10, Sections 1003(a)(i) and (a)(ii) of the Guide since it reported stockholders’ equity of $1.2 million and net losses in fiscal years ended September 30, 2019, September 30, 2018 and September 30, 2016.
In accordance with the Exchange’s policies and procedures, the Company submitted its Plan addressing how the Company intends to regain compliance with Part 10, Section 1003 of the Guide. On April 2, 2020, the Exchange notified the Company that it accepted the Company’s Plan and granted the Company an extension for its continued listing during the Plan Period. The Company will be subject to periodic review by Exchange Staff during the Plan Period. The Plan was submitted to the Exchange before the start of the COVID-19 pandemic-related low commodity price environment, the oil price war between Saudi Arabia 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 Exchange’s listing standards. If the Company does not regain compliance by the end of the Plan Period, or if the Company does not make progress consistent with its Plan, the Exchange may initiate delisting procedures as appropriate.
On July 2, 2020, the Company submitted its update to the Plan as was required by the Exchange. In that update, the Company reported that due largely to the impact of COVID-19 on the outlook for oil prices and other economic impacts of COVID-19 that could be relevant to the Company’s operations, the Company expects that it likely will not obtain a stockholders’ equity of $4,000,000 by July 13, 2021, the end of the Plan “cure period.” Additionally, the Company’s reported stockholders’ equity fell from $2,049,000 at March
31, 2020 to a stockholders’ deficit of $1,512,000 at June 30, 2020. Thus, the Company may fail to be in compliance with the NYSE American continued listing standards relating to stockholders’ equity to which the Plan relates; specifically Section 1003(a)(i) (requiring stockholders’ equity of $2.0 million or more if it has reported losses from continuing operations and/or net losses in two of its three most recent fiscal years) and Section 1003(a)(ii) (requiring stockholders’ equity of $4.0 million or more if it has reported losses from continuing operations and/or net losses in three of its four most recent fiscal years). The Company has not received any correspondence from the Exchange other than acknowledgment of receipt of the update. If the Exchange 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.
ITEM 6. EXHIBITS
| | | | | | | | |
Exhibit
Number | | Description |
| | |
Exhibit
Number
31.1 | | Description |
3.2 | | Amended and Restated By-Laws (1)
|
| | |
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 |
| | |
(1) Incorporated by reference to Exhibit 3.1 to Registrant’s Form 8-K filed on January 14, 2020.
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, 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 | | BARNWELL INDUSTRIES, INC. |
| | (Registrant) |
| | |
| | |
Date: | August 13, 2020 | /s/ Russell M. Gifford |
| | Russell M. Gifford |
| | Chief Financial Officer, |
| | Executive Vice President, |
| | Treasurer and Secretary |
INDEX TO EXHIBITS
|
| | |
Exhibit
Number
| | Description |
| | |
3.2 | | |
| | |
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 |
| | |
(1) Incorporated by reference to Exhibit 3.1 to Registrant’s Form 8-K filed on January 14, 2020.