UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

☒ Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended ~~December~~March 31, ~~2021~~2022

☐ Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

Commission File Number 1-5103

BARNWELL INDUSTRIES, INC.

(Exact name of registrant as specified in its charter)


Delaware						72-0496921
(State or other jurisdiction of incorporation or organization)						(I.R.S. Employer Identification No.)

1100 Alakea Street, Suite 500, Honolulu, Hawaii						96813
(Address of principal executive offices)						(Zip code)

(808) 531-8400
(Registrant’s telephone number, including area code)

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


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

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. ☒ Yes ☐ No

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). ☒ Yes ☐ No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and ~~“emerging~~"emerging growth ~~company”~~company" in Rule 12b-2 of the Exchange Act.

Large accelerated filer

☐

Accelerated filer

☐

Non-accelerated filer

☒

Smaller reporting company

☒

Emerging growth company

☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). ☐ Yes ☒ No

As of ~~February 7,~~May 6, 2022 there were ~~9,447,220~~9,956,687 shares of common stock, par value $0.50, outstanding.

BARNWELL INDUSTRIES, INC.

AND SUBSIDIARIES

INDEX


PART I.	FINANCIAL INFORMATION:
Item 1.	Financial Statements (Unaudited)
	Condensed Consolidated Balance Sheets - ~~December~~March 31, ~~2021~~2022 and September 30, 2021	3
	Condensed Consolidated Statements of Operations - three and six months ended ~~December~~March 31, ~~2021~~2022 and ~~2020~~2021	4
	Condensed Consolidated Statements of Comprehensive Income (Loss) - three and six months ended ~~December~~March 31, ~~2021~~2022 and ~~2020~~2021	5
	Condensed Consolidated Statements of Equity (Deficit) - three and six months ended ~~December~~March 31, ~~2021~~2022 and ~~2020~~2021	6
	Condensed Consolidated Statements of Cash Flows - ~~three~~six months ended ~~December~~ March 31, ~~2021~~2022 and ~~2020~~2021	78
	Notes to Condensed Consolidated Financial Statements	89
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	2528
Item 4.	Controls and Procedures	3540
PART II.	OTHER INFORMATION:
Item 1A.	Risk Factors	3641
Item 6.	Exhibits	3742
	Signature	3843
	Index to Exhibits	3944

PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


	March 31, 2022		September 30, 2021
ASSETS
Current assets:
Cash and cash equivalents	$	9,626,000	$	11,279,000

Accounts and other receivables, net of allowance for doubtful accounts of: $192,000 at March 31, 2022; $391,000 at September 30, 2021	4,764,000		3,069,000
Income taxes receivable	638,000		530,000
Asset held for sale	—		687,000
Other current assets	3,228,000		2,470,000
Total current assets	18,256,000		18,035,000

Asset for retirement benefits	2,395,000		2,229,000

Operating lease right-of-use assets	276,000		296,000
Property and equipment:
Oil and natural gas properties, full cost method of accounting:
Proved properties	70,377,000		58,490,000
Unproved properties	—		962,000
Drilling rigs and other property and equipment	7,680,000		7,960,000
Total property and equipment	78,057,000		67,412,000
Accumulated depletion, impairment, depreciation, and amortization	(65,552,000)		(63,537,000)
Total property and equipment, net	12,505,000		3,875,000
Total assets	$	33,432,000	$	24,435,000

LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	1,659,000	$	1,416,000
Accrued capital expenditures	1,360,000		909,000
Accrued compensation	555,000		1,073,000
Accrued operating and other expenses	1,266,000		1,171,000

Current portion of asset retirement obligation	1,532,000		713,000
Other current liabilities	858,000		619,000
Total current liabilities	7,230,000		5,901,000

Long-term debt	48,000		47,000
Operating lease liabilities	174,000		180,000

Liability for retirement benefits	2,131,000		2,101,000
Asset retirement obligation	8,031,000		6,340,000
Deferred income tax liabilities	357,000		359,000
Total liabilities	17,971,000		14,928,000
Commitments and contingencies	0		0
Equity:
Common stock, par value $0.50 per share; authorized, 20,000,000 shares: 10,124,587 issued at March 31, 2022; 9,613,525 issued at September 30, 2021	5,062,000		4,807,000
Additional paid-in capital	7,121,000		4,590,000
Retained earnings	5,481,000		2,356,000
Accumulated other comprehensive loss, net	19,000		32,000
Treasury stock, at cost: 167,900 shares at March 31, 2022 and September 30, 2021	(2,286,000)		(2,286,000)
Total stockholders’ equity	15,397,000		9,499,000
Non-controlling interests	64,000		8,000
Total equity	15,461,000		9,507,000
Total liabilities and equity	$	33,432,000	$	24,435,000

December 31, 2021 September 30, 2021
ASSETS
Current assets:
Cash and cash equivalents $ 12,142,000 $ 11,279,000
Accounts and other receivables, net of allowance for doubtful accounts of:
$355,000 at December 31, 2021; $391,000 at September 30, 2021
3,186,000 3,069,000
Income taxes receivable 519,000 530,000
Asset held for sale — 687,000
Other current assets 2,696,000 2,470,000
Total current assets 18,543,000 18,035,000
Asset for retirement benefits 2,312,000 2,229,000
Operating lease right-of-use assets 252,000 296,000
Property and equipment:
Oil and natural gas properties, full cost method of accounting:
Proved properties 63,040,000 58,490,000
Unproved properties — 962,000
Drilling rigs and other property and equipment 7,711,000 7,960,000
Total property and equipment 70,751,000 67,412,000
Accumulated depletion, depreciation, and amortization (64,183,000) (63,537,000)
Total property and equipment, net 6,568,000 3,875,000
Total assets $ 27,675,000 $ 24,435,000
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable $ 1,207,000 $ 1,416,000
Accrued capital expenditures 2,754,000 909,000
Accrued compensation 821,000 1,073,000
Accrued operating and other expenses 1,141,000 1,171,000
Current portion of asset retirement obligation 1,216,000 713,000
Other current liabilities 728,000 619,000
Total current liabilities 7,867,000 5,901,000
Long-term debt 47,000 47,000
Operating lease liabilities 159,000 180,000
Liability for retirement benefits 2,117,000 2,101,000
Asset retirement obligation 6,267,000 6,340,000
Deferred income tax liabilities 391,000 359,000
Total liabilities 16,848,000 14,928,000
Commitments and contingencies 0 0
Equity:
Common stock, par value $0.50 per share; authorized, 20,000,000 shares:
9,614,683 issued at December 31, 2021 and 9,613,525 issued at September 30, 2021
4,807,000 4,807,000
Additional paid-in capital 4,846,000 4,590,000
Retained earnings 3,429,000 2,356,000
Accumulated other comprehensive income, net 7,000 32,000
Treasury stock, at cost: 167,900 shares at December 31, 2021 and September 30, 2021 (2,286,000) (2,286,000)
Total stockholders' equity 10,803,000 9,499,000
Non-controlling interests 24,000 8,000
Total equity 10,827,000 9,507,000
Total liabilities and equity $ 27,675,000 $ 24,435,000

See Notes to Condensed Consolidated Financial Statements

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)


		Three months ended December 31,					Three months ended March 31,				Six months ended March 31,
		2021		2020			2022		2021		2022		2021
Revenues:	Revenues:					Revenues:
Oil and natural gas	Oil and natural gas	$	3,920,000	$	1,887,000	Oil and natural gas	$	5,133,000	$	2,552,000	$	9,053,000	$	4,439,000
Contract drilling	Contract drilling	876,000		1,942,000		Contract drilling	818,000		1,389,000		1,694,000		3,331,000
Sale of interest in leasehold land	Sale of interest in leasehold land	600,000		485,000		Sale of interest in leasehold land	695,000		—		1,295,000		485,000
Gas processing and other	Gas processing and other	58,000		73,000		Gas processing and other	33,000		57,000		91,000		130,000
		5,454,000		4,387,000			6,679,000		3,998,000		12,133,000		8,385,000
Costs and expenses:	Costs and expenses:					Costs and expenses:
Oil and natural gas operating	Oil and natural gas operating	1,916,000		1,435,000		Oil and natural gas operating	2,126,000		1,759,000		4,042,000		3,194,000
Contract drilling operating	Contract drilling operating	980,000		1,108,000		Contract drilling operating	918,000		1,465,000		1,898,000		2,573,000
General and administrative	General and administrative	1,830,000		1,185,000		General and administrative	2,241,000		1,928,000		4,071,000		3,113,000
Depletion, depreciation, and amortization	Depletion, depreciation, and amortization	483,000		276,000		Depletion, depreciation, and amortization	618,000		227,000		1,101,000		503,000
Impairment of assets	Impairment of assets	—		630,000		Impairment of assets	—		—		—		630,000
Interest expense	Interest expense	—		1,000		Interest expense	—		3,000		—		4,000
		5,209,000		4,635,000

							5,903,000		5,382,000		11,112,000		10,017,000
Earnings (loss) before equity in income of affiliates and income taxes	Earnings (loss) before equity in income of affiliates and income taxes	245,000		(248,000)		Earnings (loss) before equity in income of affiliates and income taxes	776,000		(1,384,000)		1,021,000		(1,632,000)
Equity in income of affiliates	Equity in income of affiliates	1,207,000		1,054,000		Equity in income of affiliates	1,760,000		624,000		2,967,000		1,678,000
Earnings before income taxes		1,452,000		806,000
Earnings (loss) before income taxes						Earnings (loss) before income taxes	2,536,000		(760,000)		3,988,000		46,000
Income tax provision	Income tax provision	112,000		63,000		Income tax provision	138,000		34,000		250,000		97,000
Net earnings		1,340,000		743,000
Net earnings (loss)						Net earnings (loss)	2,398,000		(794,000)		3,738,000		(51,000)
Less: Net earnings attributable to non-controlling interests	Less: Net earnings attributable to non-controlling interests	267,000		159,000		Less: Net earnings attributable to non-controlling interests	346,000		62,000		613,000		221,000
Net earnings attributable to Barnwell Industries, Inc.		$	1,073,000	$	584,000
Basic and diluted net earnings per common share attributable to Barnwell Industries, Inc. stockholders		$	0.11	$	0.07
Net earnings (loss) attributable to Barnwell Industries, Inc.						Net earnings (loss) attributable to Barnwell Industries, Inc.	$	2,052,000	$	(856,000)	$	3,125,000	$	(272,000)
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	$	0.21	$	(0.10)	$	0.33	$	(0.03)
Weighted-average number of common shares outstanding:	Weighted-average number of common shares outstanding:					Weighted-average number of common shares outstanding:
Basic and diluted	Basic and diluted	9,446,291		8,277,160		Basic and diluted	9,570,989		8,277,160		9,507,955		8,277,160

See Notes to Condensed Consolidated Financial Statements

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(Unaudited)

Three months ended
December 31,
2021 2020
Net earnings $ 1,340,000 $ 743,000
Other comprehensive (loss) income:
Foreign currency translation adjustments, net of taxes of $0 (25,000) (234,000)
Retirement plans:
Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0 — 33,000
Total other comprehensive loss (25,000) (201,000)
Total comprehensive income 1,315,000 542,000
Less: Comprehensive income attributable to non-controlling interests (267,000) (159,000)
Comprehensive income attributable to Barnwell Industries, Inc. $ 1,048,000 $ 383,000


	Three months ended March 31,				Six months ended March 31,
	2022		2021		2022		2021
Net earnings (loss)	$	2,398,000	$	(794,000)	$	3,738,000	$	(51,000)
Other comprehensive income (loss):
Foreign currency translation adjustments, net of taxes of $0	12,000		(85,000)		(13,000)		(319,000)
Retirement plans:
Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	—		33,000		—		66,000



Total other comprehensive income (loss)	12,000		(52,000)		(13,000)		(253,000)
Total comprehensive income (loss)	2,410,000		(846,000)		3,725,000		(304,000)
Less: Comprehensive income attributable to non-controlling interests	(346,000)		(62,000)		(613,000)		(221,000)
Comprehensive income (loss) attributable to Barnwell Industries, Inc.	$	2,064,000	$	(908,000)	$	3,112,000	$	(525,000)

See Notes to Condensed Consolidated Financial Statements

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (DEFICIT)

Three months ended ~~December~~March 31, ~~2021~~2022 and ~~2020~~2021

(Unaudited)


		Shares Outstanding	Common Stock		Additional Paid-In Capital		Retained Earnings (Accumulated Deficit)		Accumulated Other Comprehensive Income (Loss)		Treasury Stock		Non-controlling Interests		Total Equity (Deficit)			Shares Outstanding	Common Stock		Additional Paid-In Capital		Retained Earnings (Accumulated Deficit)		Accumulated Other Comprehensive Income (Loss)		Treasury Stock		Non-controlling Interests		Total Equity (Deficit)
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
Balance at December 31, 2020																	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)
Net (loss) earnings																	Net (loss) earnings	—	—		—		(856,000)		—		—		62,000		(794,000)
Foreign currency translation adjustments, net of taxes of $0	Foreign currency translation adjustments, net of taxes of $0	—	—		—		—		(234,000)		—		—		(234,000)		Foreign currency translation adjustments, net of taxes of $0	—	—		—		—		(85,000)		—		—		(85,000)
Distributions to non-controlling interests	Distributions to non-controlling interests	—	—		—		—		—		—		(248,000)		(248,000)		Distributions to non-controlling interests	—	—		—		—		—		—		(61,000)		(61,000)
Share-based compensation																	Share-based compensation	—	—		151,000		—		—		—		—		151,000
Retirement plans:	Retirement plans:																Retirement plans:
Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	—	—		—		—		33,000		—		—		33,000		Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	—	—		—		—		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)
Balance at March 31, 2021																	Balance at March 31, 2021	8,277,160	$	4,223,000	$	1,501,000	$	(4,169,000)	$	(1,688,000)	$	(2,286,000)	$	4,000	$	(2,415,000)

Balance at September 30, 2021		9,445,625	$	4,807,000	$	4,590,000	$	2,356,000	$	32,000	$	(2,286,000)	$	8,000	$	9,507,000
Balance at December 31, 2021																	Balance at December 31, 2021	9,446,783	$	4,807,000	$	4,846,000	$	3,429,000	$	7,000	$	(2,286,000)	$	24,000	$	10,827,000
Net earnings	Net earnings	—	—		—		1,073,000		—		—		267,000		1,340,000		Net earnings	—	—		—		2,052,000		—		—		346,000		2,398,000
Foreign currency translation adjustments, net of taxes of $0	Foreign currency translation adjustments, net of taxes of $0	—	—		—		—		(25,000)		—		—		(25,000)		Foreign currency translation adjustments, net of taxes of $0	—	—		—		—		12,000		—		—		12,000
Distributions to non-controlling interests	Distributions to non-controlling interests	—	—		—		—		—		—		(251,000)		(251,000)		Distributions to non-controlling interests	—	—		—		—		—		—		(306,000)		(306,000)
Share-based compensation	Share-based compensation	—	—		254,000		—		—		—		—		254,000		Share-based compensation	—	—		173,000		—		—		—		—		173,000
Issuance of common stock for services	Issuance of common stock for services	1,158	—		2,000		—		—		—		—		2,000		Issuance of common stock for services	437	—		1,000		—		—		—		—		1,000
Issuance of common stock, net of costs																	Issuance of common stock, net of costs	509,467	255,000		2,101,000		—		—		—		—		2,356,000

Balance at December 31, 2021		9,446,783	$	4,807,000	$	4,846,000	$	3,429,000	$	7,000	$	(2,286,000)	$	24,000	$	10,827,000

Balance at March 31, 2022																	Balance at March 31, 2022	9,956,687	$	5,062,000	$	7,121,000	$	5,481,000	$	19,000	$	(2,286,000)	$	64,000	$	15,461,000

See Notes to Condensed Consolidated Financial Statements

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (DEFICIT)

Six months ended March 31, 2022 and 2021

(Unaudited)


	Shares Outstanding	Common Stock		Additional Paid-In Capital		Retained Earnings (Accumulated Deficit)		Accumulated Other Comprehensive Income (Loss)		Treasury Stock		Non-controlling Interests		Total Equity (Deficit)
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 (loss) earnings	—	—		—		(272,000)		—		—		221,000		(51,000)
Foreign currency translation adjustments, net of taxes of $0	—	—		—		—		(319,000)		—		—		(319,000)
Distributions to non-controlling interests	—	—		—		—		—		—		(309,000)		(309,000)
Share-based compensation	—	—		151,000		—		—		—		—		151,000
Retirement plans:
Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	—	—		—		—		66,000		—		—		66,000
Balance at March 31, 2021	8,277,160	$	4,223,000	$	1,501,000	$	(4,169,000)	$	(1,688,000)	$	(2,286,000)	$	4,000	$	(2,415,000)

Balance at September 30, 2021	9,445,625	$	4,807,000	$	4,590,000	$	2,356,000	$	32,000	$	(2,286,000)	$	8,000	$	9,507,000
Net earnings	—	—		—		3,125,000		—		—		613,000		3,738,000
Foreign currency translation adjustments, net of taxes of $0	—	—		—		—		(13,000)		—		—		(13,000)
Distributions to non-controlling interests	—	—		—		—		—		—		(557,000)		(557,000)
Share-based compensation	—	—		427,000		—		—		—		—		427,000
Issuance of common stock for services	1,595	—		3,000		—		—		—		—		3,000
Issuance of common stock, net of costs	509,467	255,000		2,101,000		—		—		—		—		2,356,000



Balance at March 31, 2022	9,956,687	$	5,062,000	$	7,121,000	$	5,481,000	$	19,000	$	(2,286,000)	$	64,000	$	15,461,000

See Notes to Condensed Consolidated Financial Statements

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


		Three months ended December 31,					Six months ended March 31,
		2021		2020			2022		2021
Cash flows from operating activities:	Cash flows from operating activities:					Cash flows from operating activities:
Net earnings		$	1,340,000	$	743,000
Adjustments to reconcile net earnings to net cash
provided by operating activities:
Net earnings (loss)						Net earnings (loss)	$	3,738,000	$	(51,000)
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 income of affiliates	Equity in income of affiliates	(1,207,000)		(1,054,000)		Equity in income of affiliates	(2,967,000)		(1,678,000)
Depletion, depreciation, and amortization	Depletion, depreciation, and amortization	483,000		276,000		Depletion, depreciation, and amortization	1,101,000		503,000

Impairment of assets	Impairment of assets	—		630,000		Impairment of assets	—		630,000
Sale of interest in leasehold land, net of fees paid	Sale of interest in leasehold land, net of fees paid	(527,000)		(426,000)		Sale of interest in leasehold land, net of fees paid	(1,137,000)		(426,000)
Distributions of income from equity investees	Distributions of income from equity investees	1,207,000		1,054,000		Distributions of income from equity investees	2,737,000		1,607,000

Retirement benefits income	Retirement benefits income	(68,000)		(8,000)		Retirement benefits income	(136,000)		(17,000)
Accretion of asset retirement obligation		159,000		137,000

Non-cash rent income	Non-cash rent income	(1,000)		(1,000)		Non-cash rent income	—		(2,000)
Deferred income tax expense		32,000		39,000
Accretion of asset retirement obligation						Accretion of asset retirement obligation	351,000		277,000
Deferred income tax (benefit) expense						Deferred income tax (benefit) expense	(2,000)		14,000
Asset retirement obligation payments	Asset retirement obligation payments	(83,000)		(38,000)		Asset retirement obligation payments	(363,000)		(179,000)
Share-based compensation expense	Share-based compensation expense	254,000		—		Share-based compensation expense	427,000		151,000
Common stock issued for services	Common stock issued for services	2,000		—		Common stock issued for services	3,000		—
Retirement plan contributions and payments	Retirement plan contributions and payments	—		(2,000)		Retirement plan contributions and payments	(1,000)		(4,000)
Bad debt expense	Bad debt expense	—		7,000		Bad debt expense	44,000		7,000

Decrease from changes in current assets and liabilities	Decrease from changes in current assets and liabilities	(682,000)		(1,277,000)		Decrease from changes in current assets and liabilities	(2,096,000)		(1,170,000)
Net cash provided by operating activities		909,000		80,000
Net cash provided by (used in) operating activities						Net cash provided by (used in) operating activities	1,699,000		(338,000)
Cash flows from investing activities:	Cash flows from investing activities:					Cash flows from investing activities:

Distribution from equity investees in excess of earnings	Distribution from equity investees in excess of earnings	—		813,000		Distribution from equity investees in excess of earnings	230,000		813,000
Proceeds from sale of interest in leasehold land, net of fees paid	Proceeds from sale of interest in leasehold land, net of fees paid	527,000		426,000		Proceeds from sale of interest in leasehold land, net of fees paid	1,137,000		426,000
Proceeds from the sale of contract drilling assets	Proceeds from the sale of contract drilling assets	687,000		—		Proceeds from the sale of contract drilling assets	687,000		—

Payments to acquire oil and natural gas properties	Payments to acquire oil and natural gas properties	(317,000)		—		Payments to acquire oil and natural gas properties	(1,563,000)		—
Capital expenditures - oil and natural gas	Capital expenditures - oil and natural gas	(702,000)		(364,000)		Capital expenditures - oil and natural gas	(5,223,000)		(552,000)
Capital expenditures - all other	Capital expenditures - all other	(1,000)		—		Capital expenditures - all other	(9,000)		(24,000)
Net cash provided by investing activities		194,000		875,000
Payment for other non-current asset						Payment for other non-current asset	—		(250,000)
Issuance of note receivable						Issuance of note receivable	(400,000)		—
Net cash (used in) provided by investing activities						Net cash (used in) provided by investing activities	(5,141,000)		413,000
Cash flows from financing activities:	Cash flows from financing activities:					Cash flows from financing activities:
Borrowings on long-term debt						Borrowings on long-term debt	—		47,000
Distributions to non-controlling interests						Distributions to non-controlling interests	(557,000)		(309,000)
Proceeds from issuance of stock, net of costs						Proceeds from issuance of stock, net of costs	2,356,000		—

Borrowings on long-term debt		—		31,000

Distributions to non-controlling interests		(251,000)		(248,000)
Net cash used in financing activities		(251,000)		(217,000)
Payment of deferred offering costs						Payment of deferred offering costs	—		(23,000)
Net cash provided by (used in) financing activities						Net cash provided by (used in) financing activities	1,799,000		(285,000)
Effect of exchange rate changes on cash and cash equivalents	Effect of exchange rate changes on cash and cash equivalents	11,000		12,000		Effect of exchange rate changes on cash and cash equivalents	(10,000)		13,000
Net increase in cash and cash equivalents		863,000		750,000
Net decrease in cash and cash equivalents						Net decrease in cash and cash equivalents	(1,653,000)		(197,000)
Cash and cash equivalents at beginning of period	Cash and cash equivalents at beginning of period	11,279,000		4,584,000		Cash and cash equivalents at beginning of period	11,279,000		4,584,000
Cash and cash equivalents at end of period	Cash and cash equivalents at end of period	$	12,142,000	$	5,334,000	Cash and cash equivalents at end of period	$	9,626,000	$	4,387,000

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), a 75%-owned land investment partnership (KD Kona 2013 LLLP), and a variable interest entity (Teton Barnwell Fund I, LLC) for which the Company is deemed to be the primary beneficiary. All significant intercompany accounts and transactions have been eliminated.

Undivided interests in oil and natural gas exploration and production joint ventures are consolidated on a proportionate basis. Barnwell’s investments in both unconsolidated entities in which a significant, but less than controlling, interest is held and in variable interest entities in which the Company is not deemed to be the primary beneficiary are accounted for by the equity method.

Unless otherwise indicated, all references to “dollars” in this Form 10-Q are to U.S. dollars.

Unaudited Interim Financial Information

The accompanying unaudited condensed consolidated financial statements and notes have been prepared by Barnwell in accordance with the rules and regulations of the United States (“U.S.”) Securities and Exchange ~~Commission.~~Commission (“SEC”). Accordingly, certain information and footnote disclosures normally included in the annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to those rules and regulations, although the Company believes that the disclosures made are adequate to make the information not misleading. These condensed consolidated financial statements and notes should be read in conjunction with the consolidated financial statements and notes thereto included in Barnwell’s September 30, 2021 Annual Report on Form 10-K, as amended by our Form 10-K/A Amendment No. 1. The Condensed Consolidated Balance Sheet as of September 30, 2021 has been derived from audited consolidated financial statements.

In the opinion of management, all adjustments (which include only normal recurring adjustments) necessary to present fairly the financial position at ~~December~~March 31, ~~2021,~~2022, results of operations, comprehensive income (loss), and equity (deficit) for the three and six months ended March 31, 2022 and 2021, and cash flows for the ~~three~~six months ended ~~December~~March 31, ~~2021~~2022 and ~~2020,~~2021, have been made. The results of operations for the period ended ~~December~~March 31, ~~2021~~2022 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

There have been no changes to Barnwell's significant accounting policies as described in the Notes to Consolidated Financial Statements included in Item 8 of the Company's most recently filed Annual Report on Form 10-K, as amended by our Form 10-K/A Amendment No. 1.

Recently Adopted Accounting Pronouncements

In December 2019, the Financial Accounting Standards Board issued Accounting Standards Update (“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. The Company adopted the provisions of this ASU effective October 1, 2021. The adoption of this update did not have an impact on Barnwell's consolidated financial statements.

2. EARNINGS (LOSS) PER COMMON SHARE

Basic earnings (loss) per share is computed using the weighted-average number of common shares outstanding for the period. Diluted earnings (loss) per share is calculated using the treasury stock method to reflect the assumed issuance of common shares for all potentially dilutive securities, which consist of outstanding stock options. Potentially dilutive shares are excluded from the computation of diluted earnings (loss) per share if their effect is anti-dilutive.

Options to purchase 615,000 and 665,000 shares of common stock were excluded from the computation of diluted shares for the three and six months ended ~~December~~March 31, 2022 and 2021, respectively, as their inclusion would have been anti-dilutive. ~~There were no options outstanding at December 31, 2020.~~

Reconciliations between net earnings (loss) attributable to Barnwell stockholders and common shares outstanding of the basic and diluted net earnings (loss) per share computations are detailed in the following tables:

Three months ended December 31, 2021
Net Earnings
(Numerator) Shares
(Denominator) Per-Share
Amount
Basic net earnings per share $ 1,073,000 9,446,291 $ 0.11
Effect of dilutive securities -
common stock options — —
Diluted net earnings per share $ 1,073,000 9,446,291 $ 0.11


	Three months ended March 31, 2022
	Net Earnings (Numerator)		Shares (Denominator)	Per-Share Amount
Basic net earnings per share	$	2,052,000	9,570,989	$	0.21
Effect of dilutive securities -
common stock options	—		—
Diluted net earnings per share	$	2,052,000	9,570,989	$	0.21

910


		Three months ended December 31, 2020						Six months ended March 31, 2022
		Net Earnings (Numerator)		Shares (Denominator)	Per-Share Amount			Net Earnings (Numerator)		Shares (Denominator)	Per-Share Amount
Basic net earnings per share	Basic net earnings per share	$	584,000	8,277,160	$	0.07	Basic net earnings per share	$	3,125,000	9,507,955	$	0.33
Effect of dilutive securities -	Effect of dilutive securities -						Effect of dilutive securities -
common stock options	common stock options	—		—			common stock options	—		—
Diluted net earnings per share	Diluted net earnings per share	$	584,000	8,277,160	$	0.07	Diluted net earnings per share	$	3,125,000	9,507,955	$	0.33


	Three months ended March 31, 2021
	Net Loss (Numerator)		Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(856,000)	8,277,160	$	(0.10)
Effect of dilutive securities -
common stock options	—		—
Diluted net loss per share	$	(856,000)	8,277,160	$	(0.10)


	Six months ended March 31, 2021
	Net Loss (Numerator)		Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(272,000)	8,277,160	$	(0.03)
Effect of dilutive securities -
common stock options	—		—
Diluted net loss per share	$	(272,000)	8,277,160	$	(0.03)

3.NOTE RECEIVABLE

In February 2022, the Company loaned $400,000 to an unrelated third party and recorded a $400,000 note receivable. The note receivable is included in “Other current assets” in the Company’s Condensed Consolidated Balance Sheet as of March 31, 2022. In April 2022, the loan was repaid in full and no interest was accrued during the outstanding period.

4. INVESTMENTS

Investment in Kukio Resort Land Development Partnerships

On November 27, 2013, Barnwell, through a wholly-owned subsidiary, entered into 2 limited liability limited partnerships, KD Kona 2013 LLLP (“KD Kona”) and KKM Makai, LLLP (“KKM”), and indirectly acquired a 19.6% non-controlling ownership interest in each of KD Kukio Resorts, LLLP, KD Maniniowali, LLLP and KD Kaupulehu, LLLP (“KDK”) for $5,140,000. These entities, collectively referred to hereinafter as the “Kukio Resort Land Development Partnerships,” own certain real estate and development rights interests in the Kukio, Maniniowali and Kaupulehu portions of Kukio Resort, a private residential community on the Kona coast of the island of Hawaii, as well as Kukio Resort’s real estate sales office operations. KDK holds interests in KD Acquisition, LLLP (“KD I”) and KD Acquisition II, LP, formerly KD Acquisition II, LLLP (“KD II”). KD I is the developer of Kaupulehu Lot 4A Increment I (“Increment I”), and KD II is the developer of Kaupulehu Lot 4A Increment II (“Increment II”). ~~Barnwell's~~Barnwell’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 63 lots remain to be sold at Increment I as of ~~December~~March 31, ~~2021,~~2022, as well as from commissions on real estate sales by the real estate sales office and revenues resulting from the sale of private club memberships. NaN ocean front parcels approximately 2 to 3 acres in size ~~each~~ 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. No definitive development plans have been made by the developer of Increment II as of the date of this report.

In March 2019, KD II admitted a new development partner, Replay Kaupulehu Development, LLC (“Replay”), a party unrelated to Barnwell, in an effort to move forward with development of the remainder of Increment II at Kaupulehu. KDK and Replay hold ownership interests of 55% and 45%, respectively, of KD II and Barnwell has a 10.8% indirect non-controlling ownership interest in KD II through KDK, which is accounted for using the equity method of accounting. Barnwell continues to have an indirect 19.6% non-controlling ownership interest in KD Kukio Resorts, LLLP, KD Maniniowali, LLLP, and KD I.

Barnwell has the right to receive distributions from the Kukio Resort Land Development Partnerships via its non-controlling ~~interests~~interest 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 was reflected as an additional equity pickup in the "Equity in income of affiliates" line item in the accompanying Condensed Consolidated Statement of Operations for the ~~three~~six months ended ~~December~~March 31, ~~2020.~~2021. The preferred return payments received in the quarter ended December 31, 2020 brought the cumulative preferred return total to $656,000, which was the total amount to which Barnwell was entitled.

During the ~~three~~six months ended ~~December~~March 31, ~~2021,~~2022, Barnwell received cash distributions of ~~$1,207,000~~$2,967,000 from the Kukio Resort Land Development ~~Partnerships~~Partnership resulting in a net amount of ~~$1,075,000,~~$2,643,000, after distributing ~~$132,000~~$324,000 to non-controlling interests. During the ~~three~~six months ended ~~December~~March 31, ~~2020,~~2021, Barnwell received net cash distributions in the amount of ~~$1,712,000 from the Kukio Resort Land Development Partnerships~~$2,205,000 after distributing ~~$155,000~~$215,000 to non-controlling interests. Of the ~~$1,712,000~~$2,205,000 net cash distributions received, $459,000 represented a payment of the preferred return from KKM, as discussed above.

~~Barnwell's~~

Barnwell’s share of the operating results of its equity inaffiliates was income of ~~affiliates was $1,207,000~~$1,760,000 and $2,967,000 for the three and six months ended ~~December~~March 31, ~~2021, as~~2022, respectively, compared to ~~$1,054,000,~~income of $624,000 and $1,678,000, which includes the $459,000 payment of the preferred return from KKM discussed above, for the three and six months ended ~~December~~March 31, ~~2020.~~2021, respectively.

Summarized financial information for the Kukio Resort Land Development Partnerships is as follows:


		Three months ended December 31,					Three months ended March 31,
		2021		2020			2022		2021
Revenue	Revenue	$	9,253,000	$	8,120,000	Revenue	$	9,665,000	$	7,330,000
Gross profit	Gross profit	$	6,714,000	$	3,998,000	Gross profit	$	6,433,000	$	3,646,000
Net earnings	Net earnings	$	5,963,000	$	2,612,000	Net earnings	$	5,673,000	$	2,702,000


	Six months ended March 31,
	2022		2021
Revenue	$	18,918,000	$	15,450,000
Gross profit	$	13,147,000	$	7,644,000
Net earnings	$	11,636,000	$	5,314,000

In the quarter ended June 30, 2021, the Company received cumulative distributions from the Kukio Resort Land Development Partnerships in excess of our investment balance and in accordance with applicable accounting guidance, the Company suspended its equity method earnings recognition and the Kukio Resort Land Development Partnership investment balance was reduced to zero with the distributions received in excess of our investment balance recorded as equity in income of affiliates because the distributions are not refundable by agreement or by law and the Company is not liable for the obligations of or otherwise committed to provide financial support to the Kukio Resort Land Development Partnerships. The Company will record future equity method earnings only after our share of the Kukio Resort Land Development Partnership’s cumulative earnings in excess of distributions during the suspended period exceeds our share of the Kukio Resort Land Development Partnership’s income recognized for the excess distributions, and during this suspended period any distributions received will be recorded as equity in income of affiliates. Accordingly, the amount of equity in income of affiliates recognized in the ~~three~~six months ended ~~December~~March 31, ~~2021~~2022 was equivalent to the ~~$1,207,000~~$2,967,000 of distributions received in that period.

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 ~~17)~~18).

With respect to Increment I, Kaupulehu Developments is entitled to receive payments from KD I based on ~~the following percentages~~10% 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 lot sales was $243,038,000 through December 31, 2021.I. NaN single-family lots were sold during the ~~three~~six months ended ~~December~~March 31, ~~2021~~2022 and 63 single-family lots, of the 80 lots developed within Increment I, remained to be sold as of ~~December~~March 31, ~~2021.~~2022.

Under the terms of the Increment II agreement with KD II, Kaupulehu Developments is entitled to 15% of the distributions of KD II, the cost of which is to be solely borne by KDK out of its 55% ownership interest in KD II, plus a priority payout of 10% of KDK’s cumulative net profits derived from Increment II sales subsequent to Phase 2A, up to a maximum of $3,000,000 as to the priority payout. Such interests are limited to distributions or net profits interests and Barnwell ~~will~~does not have any partnership interests in KD II or KDK through its interest in Kaupulehu Developments. The arrangement also gives Barnwell rights to 3 single-family residential lots in Phase 2A of Increment II, and 4

single-family residential lots in phases subsequent to Phase 2A when such lots are developed by KD II, all at no cost to Barnwell. Barnwell is committed to commence construction of improvements within 90 days of the transfer of the 4 lots in the phases subsequent to Phase 2A as a condition of the transfer of such lots. Also, in addition to Barnwell’s existing obligations to pay professional fees to certain parties based on percentages of its gross receipts, Kaupulehu Developments is also is obligated to pay an amount equal to 0.72% and ~~0.20%~~0.2% of the cumulative net profits of KD II to KD Development, LLC and a pool of various individuals, respectively, all of whom are partners of KKM and are unrelated to Barnwell, in compensation for the agreement of these parties to admit the new development partner for Increment II. Such compensation will be reflected as the obligation becomes probable and the amount of the obligation can be reasonably estimated.

The following table summarizes the Increment I revenues from KD I and the amount of fees directly related to such revenues:


		Three months ended December 31,					Three months ended March 31,				Six months ended March 31,
		2021		2020			2022		2021		2022		2021
Sale of interest in leasehold land:	Sale of interest in leasehold land:					Sale of interest in leasehold land:
Revenues - sale of interest in leasehold land	Revenues - sale of interest in leasehold land	$	600,000	$	485,000	Revenues - sale of interest in leasehold land	$	695,000	$	—	$	1,295,000	$	485,000
Fees - included in general and administrative expenses	Fees - included in general and administrative expenses	(73,000)		(59,000)		Fees - included in general and administrative expenses	(85,000)		—		(158,000)		(59,000)
Sale of interest in leasehold land, net of fees paid	Sale of interest in leasehold land, net of fees paid	$	527,000	$	426,000	Sale of interest in leasehold land, net of fees paid	$	610,000	$	—	$	1,137,000	$	426,000

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. No definitive development plans have been made by the developer of Increment II as of the date of this report.

Investment in Leasehold Land Interest - Lot 4C

Kaupulehu Developments holds an interest in an area of approximately 1,000 acres of vacant leasehold land zoned conservation located adjacent to Lot 4A, which currently has no development potential without both a development agreement with the lessor and zoning reclassification. The lease terminates in December 2025.

1214

4.5. CONSOLIDATED VARIABLE INTEREST ENTITY

In February 2021, Barnwell Industries, Inc. established a new wholly-owned subsidiary named BOK Drilling, LLC (“BOK”) for the purpose of indirectly investing in oil and natural gas exploration and development in Oklahoma. BOK and Gros Ventre Partners, LLC (“Gros Ventre”), an entity affiliated with the Company, entered into the Limited Liability Agreement (the ~~“Agreement”~~“Teton Operating Agreement”) of Teton Barnwell Fund I, LLC (“Teton Barnwell”), an entity formed for the purpose of directly entering into such oil and natural gas investments. Under the terms of the Teton Operating Agreement, the profits of Teton Barnwell are split between BOK and Gros Ventre at 98% and 2%, respectively, and as the manager of Teton Barnwell, Gros ~~Ventre~~Venture is paid an annual asset management fee equal to 1% of the cumulative capital contributions made to Teton Barnwell as compensation for its management services. BOK is responsible for 100% of the capital contributions made to Teton Barnwell and as of ~~December~~March 31, ~~2021,~~2022, the Company has made a total of $1,250,000 in cumulative capital contributions to Teton Barnwell to fund its initial oil and natural gas ~~investments~~investment in Oklahoma.

The Company has determined that Teton Barnwell is a variable interest entity (“VIE”) as the entity is structured with non-substantive voting rights and that the Company is the primary beneficiary. This is due to the fact that even though Teton Barnwell has a unanimous consent voting structure, BOK is responsible for 100% of the capital contributions required to fund Teton Barnwell’s future oil exploration and development investments pursuant to the Teton Operating Agreement and thus, BOK has the power to steer the decisions that most significantly impact Teton Barnwell’s economic performance and has the obligation to absorb any potential losses that could be significant to Teton Barnwell. As BOK is the primary beneficiary of the VIE, Teton Barnwell’s operating results, assets and liabilities are consolidated by the Company.

Mr. Colin R. O'Farrell, a member of the Board of Directors of the Company effective July 12, 2021, is the sole member of Four Pines Operating LLC which owns a 25% interest in Gros Ventre. Mr. O'Farrell's influence as a member of the Board of Directors of the Company further supports the consolidation of Teton Barnwell's operating results, assets and liabilities as discussed above.

The following table summarizes the carrying value of the assets and liabilities of Teton Barnwell that are consolidated by the Company. Intercompany balances are eliminated in consolidation and thus, are not reflected in the table below.


		December 31, 2021		September 30, 2021			March 31, 2022		September 30, 2021
ASSETS	ASSETS					ASSETS
Cash and cash equivalents	Cash and cash equivalents	$	444,000	$	136,000	Cash and cash equivalents	$	624,000	$	136,000
Accounts and other receivables	Accounts and other receivables	945,000		118,000		Accounts and other receivables	1,548,000		118,000
Oil and natural gas properties, full cost method of accounting:	Oil and natural gas properties, full cost method of accounting:					Oil and natural gas properties, full cost method of accounting:
Proved properties, net	Proved properties, net	1,019,000		203,000		Proved properties, net	909,000		203,000
Unproved properties	Unproved properties	—		962,000		Unproved properties	—		962,000
Total assets	Total assets	$	2,408,000	$	1,419,000	Total assets	$	3,081,000	$	1,419,000

LIABILITIES	LIABILITIES					LIABILITIES
Accounts payable	Accounts payable	$	10,000	$	3,000	Accounts payable	$	1,000	$	3,000
Accrued capital expenditures	Accrued capital expenditures	284,000		581,000		Accrued capital expenditures	277,000		581,000
Accrued operating and other expenses	Accrued operating and other expenses	71,000		20,000		Accrued operating and other expenses	35,000		20,000
Total liabilities	Total liabilities	$	365,000	$	604,000	Total liabilities	$	313,000	$	604,000

1315

5.6. ASSET HELD FOR SALE

In September 2021, the Company designated a contract drilling segment drilling rig and related ancillary equipment, with an aggregate net carrying value of $725,000, as assets held for sale and recorded an impairment of $38,000 to reduce the value of these assets to its fair value, less estimated selling costs. The fair value of these assets in the aggregate amount of $687,000 was recorded as “Assets held for sale” on the Company's Condensed Consolidated Balance Sheet at September 30, 2021. In October 2021, the Company sold the drilling rig and related ancillary equipment for proceeds of $687,000, net of related costs, which was equivalent to its net carrying value.

6.7. OIL AND NATURAL GAS PROPERTIES

Acquisitions

In the ~~three months~~quarter ended December 31, 2021, Barnwell acquired working interests in oil and natural gas properties located in the Twining area of Alberta, Canada, for cash consideration of $317,000.

In January 2022, Barnwell acquired additional working interests in oil and natural gas properties located in the Twining area of Alberta, Canada for consideration of $1,246,000. The purchase price per the agreement was adjusted for customary purchase price adjustments to reflect the economic activity from the effective date to the closing date. The final determination of the customary adjustments to the purchase price has not yet been made, however, it is not expected to result in a material adjustment. Barnwell also assumed $1,500,000 in asset retirement obligations associated with the acquisition.

There were no oil and natural gas working interest acquisitions during the ~~three~~six months ended ~~December~~March 31, ~~2020.~~2021.

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 no ceiling test impairment during the three months ended ~~December~~March 31, 2022 and 2021. There was no ceiling test impairment during the six months ended March 31, 2022 and a $630,000 ceiling test impairment during the ~~three~~six months ended ~~December~~March 31, ~~2020.~~2021.

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.

7.8. RETIREMENT PLANS

Barnwell sponsors a noncontributory defined benefit pension plan (“Pension Plan”) covering substantially all of its U.S. employees. Additionally, Barnwell sponsors a Supplemental Executive Retirement Plan (“SERP”), a noncontributory supplemental retirement benefit plan which covers certain current and former employees of Barnwell for amounts exceeding the limits allowed under the Pension Plan, and previously sponsored a ~~sponsored~~ post-retirement medical insurance benefits plan (“Post-retirement Medical”) covering eligible U.S. employees.

In June 2021, the Company terminated its Post-retirement Medical plan effective June 4, 2021. Pursuant to the Post-retirement Medical plan document, the Company, as the sponsor of the Post-retirement Medical plan, had the right to terminate the plan by resolution of the Board of Directors of the Company and sixty days’ notice to each participant in the plan. Further, under the terms of the plan document, the participants in the Post-retirement Medical plan were not entitled to any unpaid vested benefits thereunder upon termination of the plan. The Post-retirement Medical plan was an unfunded plan and the Company funded benefits when payments were made.

The following ~~table details~~tables detail the components of net periodic benefit (income) cost for Barnwell’s retirement plans:


		Pension Plan				SERP				Postretirement Medical					Pension Plan				SERP				Post-retirement Medical
		Three months ended December 31,													Three months ended March 31,
		2021		2020		2021		2020		2021		2020			2022		2021		2022		2021		2022		2021

Interest cost	Interest cost	$	73,000	$	65,000	$	15,000	$	13,000	$	—	$	18,000	Interest cost	$	72,000	$	64,000	$	15,000	$	13,000	$	—	$	18,000
Expected return on plan assets	Expected return on plan assets	(156,000)		(137,000)		—		—		—		—		Expected return on plan assets	(155,000)		(137,000)		—		—		—		—

Amortization of net actuarial loss	Amortization of net actuarial loss	—		10,000		—		—		—		23,000		Amortization of net actuarial loss	—		10,000		—		—		—		23,000

Net periodic benefit (income) cost	Net periodic benefit (income) cost	$	(83,000)	$	(62,000)	$	15,000	$	13,000	$	—	$	41,000	Net periodic benefit (income) cost	$	(83,000)	$	(63,000)	$	15,000	$	13,000	$	—	$	41,000


	Pension Plan				SERP				Post-retirement Medical
	Six months ended March 31,
	2022		2021		2022		2021		2022		2021

Interest cost	$	145,000	$	129,000	$	30,000	$	26,000	$	—	$	36,000
Expected return on plan assets	(311,000)		(274,000)		—		—		—		—

Amortization of net actuarial loss	—		20,000		—		—		—		46,000


Net periodic benefit (income) cost	$	(166,000)	$	(125,000)	$	30,000	$	26,000	$	—	$	82,000

The net periodic benefit (income) cost is included in “General and administrative” expenses in the Company's Condensed Consolidated Statements of Operations.

Currently, no contributions are expected to be made to the Pension Plan during fiscal 2022. The SERP plan is unfunded and Barnwell funds benefits when payments are made. Expected payments under the SERP for fiscal 2022 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.

8.9. INCOME TAXES

The components of earnings (loss) before income taxes, after adjusting the earnings for non-controlling interests, are as follows:


		Three months ended December 31,					Three months ended March 31,				Six months ended March 31,
		2021		2020			2022		2021		2022		2021
United States	United States	$	892,000	$	1,422,000	United States	$	1,016,000	$	(931,000)	$	1,908,000	$	491,000
Canada	Canada	293,000		(775,000)		Canada	1,174,000		109,000		1,467,000		(666,000)
		$	1,185,000	$	647,000		$	2,190,000	$	(822,000)	$	3,375,000	$	(175,000)

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


		Three months ended December 31,					Three months ended March 31,				Six months ended March 31,
		2021		2020			2022		2021		2022		2021
Current	Current	$	80,000	$	24,000	Current	$	172,000	$	59,000	$	252,000	$	83,000
Deferred	Deferred	32,000		39,000		Deferred	(34,000)		(25,000)		(2,000)		14,000
		$	112,000	$	63,000		$	138,000	$	34,000	$	250,000	$	97,000

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. Income from our investment in the Oklahoma oil venture is 100% allocable to Oklahoma

and Barnwell receives no benefit from consolidated or unitary losses and, therefore, is subject to Oklahoma state taxes. In addition, net operating loss carryforwards, the benefit of which had not previously been recognized due to the Company's continuing full valuation allowance, are estimated to be partially utilized in the current year periods as the recognized benefit is now more likely than not.

1618

9.10. REVENUE FROM CONTRACTS WITH CUSTOMERS

Disaggregation of Revenue

The following tables ~~provides~~provide information about disaggregated revenue by revenue streams, reportable segments, geographical region, and timing of revenue recognition for the three and six months ended ~~December~~March 31, ~~2021~~2022 and ~~2020.~~2021.


			Three months ended December 31, 2021												Three months ended March 31, 2022
			Oil and natural gas		Contract drilling		Land investment		Other		Total				Oil and natural gas		Contract drilling		Land investment		Other		Total
Revenue streams:	Revenue streams:												Revenue streams:
		Oil	$	2,668,000	$	—	$	—	$	—	$	2,668,000		Oil	$	3,657,000	$	—	$	—	$	—	$	3,657,000
		Natural gas	849,000		—		—		—		849,000			Natural gas	859,000		—		—		—		859,000
		Natural gas liquids	403,000		—		—		—		403,000			Natural gas liquids	617,000		—		—		—		617,000
		Drilling and pump	—		876,000		—		—		876,000			Drilling and pump	—		818,000		—		—		818,000
		Contingent residual payments	—		—		600,000		—		600,000			Contingent residual payments	—		—		695,000		—		695,000
		Other	—		—		—		57,000		57,000			Other	—		—		—		32,000		32,000
		Total revenues before interest income	$	3,920,000	$	876,000	$	600,000	$	57,000	$	5,453,000		Total revenues before interest income	$	5,133,000	$	818,000	$	695,000	$	32,000	$	6,678,000
Geographical regions:	Geographical regions:												Geographical regions:
		United States	$	964,000	$	876,000	$	600,000	$	4,000	$	2,444,000		United States	$	992,000	$	818,000	$	695,000	$	—	$	2,505,000
		Canada	2,956,000		—		—		53,000		3,009,000			Canada	4,141,000		—		—		32,000		4,173,000
		Total revenues before interest income	$	3,920,000	$	876,000	$	600,000	$	57,000	$	5,453,000		Total revenues before interest income	$	5,133,000	$	818,000	$	695,000	$	32,000	$	6,678,000
Timing of revenue recognition:	Timing of revenue recognition:												Timing of revenue recognition:
		Goods transferred at a point in time	$	3,920,000	$	—	$	600,000	$	57,000	$	4,577,000		Goods transferred at a point in time	$	5,133,000	$	—	$	695,000	$	32,000	$	5,860,000
		Services transferred over time	—		876,000		—		—		876,000			Services transferred over time	—		818,000		—		—		818,000
		Total revenues before interest income	$	3,920,000	$	876,000	$	600,000	$	57,000	$	5,453,000		Total revenues before interest income	$	5,133,000	$	818,000	$	695,000	$	32,000	$	6,678,000

Three months ended December 31, 2020
Oil and natural gas Contract drilling Land investment Other Total
Revenue streams:
Oil $ 1,380,000 $ — $ — $ — $ 1,380,000
Natural gas 375,000 — — — 375,000
Natural gas liquids 132,000 — — — 132,000
Drilling and pump — 1,942,000 — — 1,942,000
Contingent residual payments — — 485,000 — 485,000
Other — — — 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 $ — $ 1,942,000 $ 485,000 $ — $ 2,427,000
Canada 1,887,000 — — 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 $ — $ 485,000 $ 73,000 $ 2,445,000
Services transferred over time — 1,942,000 — — 1,942,000
Total revenues before interest income $ 1,887,000 $ 1,942,000 $ 485,000 $ 73,000 $ 4,387,000


		Three months ended March 31, 2021
		Oil and natural gas		Contract drilling		Land investment		Other		Total
Revenue streams:
	Oil	$	1,933,000	$	—	$	—	$	—	$	1,933,000
	Natural gas	461,000		—		—		—		461,000
	Natural gas liquids	158,000		—		—		—		158,000
	Drilling and pump	—		1,389,000		—		—		1,389,000

	Other	—		—		—		57,000		57,000
	Total revenues before interest income	$	2,552,000	$	1,389,000	$	—	$	57,000	$	3,998,000
Geographical regions:
	United States	$	—	$	1,389,000	$	—	$	4,000	$	1,393,000
	Canada	2,552,000		—		—		53,000		2,605,000
	Total revenues before interest income	$	2,552,000	$	1,389,000	$	—	$	57,000	$	3,998,000
Timing of revenue recognition:
	Goods transferred at a point in time	$	2,552,000	$	—	$	—	$	57,000	$	2,609,000
	Services transferred over time	—		1,389,000		—		—		1,389,000
	Total revenues before interest income	$	2,552,000	$	1,389,000	$	—	$	57,000	$	3,998,000

1719


		Six months ended March 31, 2022
		Oil and natural gas		Contract drilling		Land investment		Other		Total
Revenue streams:
	Oil	$	6,325,000	$	—	$	—	$	—	$	6,325,000
	Natural gas	1,708,000		—		—		—		1,708,000
	Natural gas liquids	1,020,000		—		—		—		1,020,000
	Drilling and pump	—		1,694,000		—		—		1,694,000
	Contingent residual payments	—		—		1,295,000		—		1,295,000
	Other	—		—		—		89,000		89,000
	Total revenues before interest income	$	9,053,000	$	1,694,000	$	1,295,000	$	89,000	$	12,131,000
Geographical regions:
	United States	$	1,956,000	$	1,694,000	$	1,295,000	$	4,000	$	4,949,000
	Canada	7,097,000		—		—		85,000		7,182,000
	Total revenues before interest income	$	9,053,000	$	1,694,000	$	1,295,000	$	89,000	$	12,131,000
Timing of revenue recognition:
	Goods transferred at a point in time	$	9,053,000	$	—	$	1,295,000	$	89,000	$	10,437,000
	Services transferred over time	—		1,694,000		—		—		1,694,000
	Total revenues before interest income	$	9,053,000	$	1,694,000	$	1,295,000	$	89,000	$	12,131,000


		Six months ended March 31, 2021
		Oil and natural gas		Contract drilling		Land investment		Other		Total
Revenue streams:
	Oil	$	3,313,000	$	—	$	—	$	—	$	3,313,000
	Natural gas	836,000		—		—		—		836,000
	Natural gas liquids	290,000		—		—		—		290,000
	Drilling and pump	—		3,331,000		—		—		3,331,000
	Contingent residual payments	—		—		485,000		—		485,000
	Other	—		—		—		130,000		130,000
	Total revenues before interest income	$	4,439,000	$	3,331,000	$	485,000	$	130,000	$	8,385,000
Geographical regions:
	United States	$	—	$	3,331,000	$	485,000	$	4,000	$	3,820,000
	Canada	4,439,000		—		—		126,000		4,565,000
	Total revenues before interest income	$	4,439,000	$	3,331,000	$	485,000	$	130,000	$	8,385,000
Timing of revenue recognition:
	Goods transferred at a point in time	$	4,439,000	$	—	$	485,000	$	130,000	$	5,054,000
	Services transferred over time	—		3,331,000		—		—		3,331,000
	Total revenues before interest income	$	4,439,000	$	3,331,000	$	485,000	$	130,000	$	8,385,000

Contract Balances

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


		December 31, 2021		September 30, 2021			March 31, 2022		September 30, 2021
Accounts receivables from contracts with customers	Accounts receivables from contracts with customers	$	2,990,000	$	2,797,000	Accounts receivables from contracts with customers	$	4,446,000	$	2,797,000
Contract assets	Contract assets	497,000		581,000		Contract assets	522,000		581,000
Contract liabilities	Contract liabilities	523,000		455,000		Contract liabilities	662,000		455,000

Accounts receivables from contracts with customers are included in ~~"Accounts~~“Accounts and other receivables, net of allowance for doubtful accounts,"” and contract assets, which includes costs and estimated earnings in excess of billings and retainage, are included in “Other current assets.” Contract liabilities, which includes billings in excess of costs and estimated earnings are included in “Other current liabilities” in the accompanying Condensed Consolidated Balance Sheets.

Retainage, included in contract assets, represents amounts due from customers, but where payments are withheld contractually until certain construction milestones are met. Amounts retained typically range from 5% to 10% of the total invoice, up to contractually-specified maximums. The Company classifies as a current asset those retainages that are expected to be collected in the next twelve months.

Contract assets represent the Company’s rights to consideration in exchange for services transferred to a customer that have not been billed as of the reporting date. The Company’s rights are generally unconditional at the time its performance obligations are satisfied.

When the Company receives consideration or such consideration is unconditionally due from a customer prior to transferring goods or services to the customer under the terms of a sales contract, the Company records deferred revenue, which represents a contract liability. Such deferred revenue typically results from billings in excess of costs and estimated earnings on uncompleted contracts. As of ~~December~~March 31, ~~2021~~2022 and September 30, 2021, the Company had ~~$523,000~~$662,000 and $455,000, respectively, included in “Other current liabilities” on the balance ~~sheet~~sheets for those performance obligations expected to be completed in the next twelve months.

During the ~~three~~six months ended ~~December~~March 31, ~~2021~~2022 and ~~2020,~~2021, the amount of revenue recognized that was previously included in contract liabilities as of the beginning of the respective period was ~~$186,000~~$308,000 and ~~$573,000,~~$789,000, respectively.

Contracts are sometimes modified for a change in scope or other requirements. The Company considers contract modifications to exist when the modification either creates new or changes the existing enforceable rights and obligations. Most of the Company’s contract modifications are for goods and services that are not distinct from the existing performance obligations. The effect of a contract modification on the transaction price, and the measure of progress for the performance obligation to which it relates, is recognized as an adjustment to revenue (either as an increase or decrease) on a cumulative catchup basis.

Performance Obligations

The Company’s remaining performance obligations for drilling and pump installation contracts (hereafter referred to as “backlog”) represent the unrecognized revenue value of the Company’s contract commitments. The Company’s backlog may vary significantly each reporting period based on the timing of major new contract commitments. In addition, our customers have the right, under some infrequent circumstances, to terminate contracts or defer the timing of the Company’s services and their payments to us. Nearly all of the Company's contract drilling segment contracts have original expected durations of one year or less. At ~~December~~March 31, ~~2021,~~2022, the Company had four contract drilling jobs with original expected durations of greater than one year. For these contracts, ~~approximately~~ 13% of the remaining performance obligation of ~~$2,818,000~~$2,844,000 is expected to be recognized ~~as revenue~~ in the next twelve months and the remaining, thereafter.

Contract Fulfillment Costs

Preconstruction costs, which include costs such as set-up and mobilization, are capitalized and allocated across all performance obligations and deferred and amortized over the contract term on a progress towards completion basis. As of ~~December~~March 31, ~~2021~~2022 and September 30, 2021, the Company had ~~$281,000~~$257,000 and $326,000, respectively, in unamortized preconstruction costs related to contracts that were not completed. During the three and six months ended ~~December~~March 31, ~~2021~~2022 and ~~2020,~~2021, the amortization of preconstruction costs related to contracts were not material and were included in the accompanying Condensed Consolidated Statements of Operations. Additionally, no impairment charges in connection with the Company’s preconstruction costs were recorded during the three and six months ended ~~December~~March 31, ~~2021~~2022 and ~~2020.~~

2021.

1922

~~10.~~11. SEGMENT INFORMATION

Barnwell operates the following segments: 1) acquiring, developing, producing and selling oil and natural gas in Canada and Oklahoma (oil and natural gas); 2) investing in land interests in Hawaii (land investment); and 3) drilling wells and installing and repairing water pumping systems in Hawaii (contract drilling).

The following table presents certain financial information related to Barnwell’s reporting segments. All revenues reported are from external customers with no intersegment sales or transfers.

Three months ended
December 31,
2021 2020
Revenues:
Oil and natural gas $ 3,920,000 $ 1,887,000
Contract drilling 876,000 1,942,000
Land investment 600,000 485,000
Other 57,000 73,000
Total before interest income 5,453,000 4,387,000
Interest income 1,000 —
Total revenues $ 5,454,000 $ 4,387,000
Depletion, depreciation, and amortization:
Oil and natural gas $ 436,000 $ 195,000
Contract drilling 47,000 76,000
Other — 5,000
Total depletion, depreciation, and amortization $ 483,000 $ 276,000
Impairment:
Oil and natural gas $ — $ 630,000
Total impairment $ — $ 630,000
Operating profit (loss) (before general and administrative expenses):
Oil and natural gas $ 1,568,000 $ (373,000)
Contract drilling (151,000) 758,000
Land investment 600,000 485,000
Other 57,000 68,000
Total operating profit 2,074,000 938,000
Equity in income of affiliates:
Land investment 1,207,000 1,054,000
General and administrative expenses (1,830,000) (1,185,000)
Interest expense — (1,000)
Interest income 1,000 —
Earnings before income taxes $ 1,452,000 $ 806,000


	Three months ended March 31,				Six months ended March 31,
	2022		2021		2022		2021
Revenues:
Oil and natural gas	$	5,133,000	$	2,552,000	$	9,053,000	$	4,439,000
Contract drilling	818,000		1,389,000		1,694,000		3,331,000
Land investment	695,000		—		1,295,000		485,000
Other	32,000		57,000		89,000		130,000
Total before interest income	6,678,000		3,998,000		12,131,000		8,385,000
Interest income	1,000		—		2,000		—
Total revenues	$	6,679,000	$	3,998,000	$	12,133,000	$	8,385,000
Depletion, depreciation, and amortization:
Oil and natural gas	$	577,000	$	146,000	$	1,013,000	$	341,000
Contract drilling	41,000		77,000		88,000		153,000
Other	—		4,000		—		9,000
Total depletion, depreciation, and amortization	$	618,000	$	227,000	$	1,101,000	$	503,000
Impairment:
Oil and natural gas	$	—	$	—	$	—	$	630,000


Total impairment	$	—	$	—	$	—	$	630,000
Operating profit (loss) (before general and administrative expenses):
Oil and natural gas	$	2,430,000	$	647,000	$	3,998,000	$	274,000
Contract drilling	(141,000)		(153,000)		(292,000)		605,000
Land investment	695,000		—		1,295,000		485,000
Other	32,000		53,000		89,000		121,000

Total operating profit	3,016,000		547,000		5,090,000		1,485,000
Equity in income of affiliates:
Land investment	1,760,000		624,000		2,967,000		1,678,000
General and administrative expenses	(2,241,000)		(1,928,000)		(4,071,000)		(3,113,000)
Interest expense	—		(3,000)		—		(4,000)
Interest income	1,000		—		2,000		—


Earnings (loss) before income taxes	$	2,536,000	$	(760,000)	$	3,988,000	$	46,000

2023

~~11.~~12. ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

The changes in each component of accumulated other comprehensive income (loss) were as follows:


		Three months ended December 31,					Three months ended March 31,				Six months ended March 31,
		2021		2020			2022		2021		2022		2021
Foreign currency translation:	Foreign currency translation:					Foreign currency translation:
Beginning accumulated foreign currency translation	Beginning accumulated foreign currency translation	$	262,000	$	545,000	Beginning accumulated foreign currency translation	$	237,000	$	311,000	$	262,000	$	545,000
Change in cumulative translation adjustment before reclassifications	Change in cumulative translation adjustment before reclassifications	(25,000)		(234,000)		Change in cumulative translation adjustment before reclassifications	12,000		(85,000)		(13,000)		(319,000)

Income taxes	Income taxes	—		—		Income taxes	—		—		—		—
Net current period other comprehensive loss		(25,000)		(234,000)
Net current period other comprehensive income (loss)						Net current period other comprehensive income (loss)	12,000		(85,000)		(13,000)		(319,000)
Ending accumulated foreign currency translation	Ending accumulated foreign currency translation	237,000		311,000		Ending accumulated foreign currency translation	249,000		226,000		249,000		226,000
Retirement plans:	Retirement plans:					Retirement plans:
Beginning accumulated retirement plans benefit cost	Beginning accumulated retirement plans benefit cost	(230,000)		(1,980,000)		Beginning accumulated retirement plans benefit cost	(230,000)		(1,947,000)		(230,000)		(1,980,000)
Amortization of net actuarial loss	Amortization of net actuarial loss	—		33,000		Amortization of net actuarial loss	—		33,000		—		66,000

Income taxes	Income taxes	—		—		Income taxes	—		—		—		—
Net current period other comprehensive income	Net current period other comprehensive income	—		33,000		Net current period other comprehensive income	—		33,000		—		66,000
Ending accumulated retirement plans benefit cost	Ending accumulated retirement plans benefit cost	(230,000)		(1,947,000)		Ending accumulated retirement plans benefit cost	(230,000)		(1,914,000)		(230,000)		(1,914,000)
Accumulated other comprehensive income (loss), net of taxes	Accumulated other comprehensive income (loss), net of taxes	$	7,000	$	(1,636,000)	Accumulated other comprehensive income (loss), net of taxes	$	19,000	$	(1,688,000)	$	19,000	$	(1,688,000)

The amortization of net actuarial loss for the retirement plans are included in the computation of net periodic benefit (income) cost which is a component of “General and administrative” expenses on the accompanying Condensed Consolidated Statements of Operations (see Note 78 for additional details).

~~12.~~13. FAIR VALUE MEASUREMENTS

The carrying values of cash and cash equivalents, accounts and other receivables, accounts payable and accrued current liabilities approximate their fair values due to the short-term nature of the instruments.

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

The estimated fair values of oil and natural gas properties and the asset retirement obligation incurred in the drilling of oil and natural gas wells or assumed in the acquisitions of additional oil and natural gas working interests are based on an estimated discounted cash flow model and market assumptions. The significant Level 3 assumptions used in the calculation of estimated discounted cash flows included future commodity prices, projections of estimated quantities of oil and natural gas reserves, expectations for timing and amount of future development, operating and asset retirement costs, projections of future rates of production, expected recovery rates and risk adjusted discount rates.

Barnwell estimates the fair value of asset retirement obligations based on the projected discounted future cash outflows required to settle abandonment and restoration liabilities. Such an estimate requires assumptions and judgments regarding the existence of liabilities, the amount and timing of cash outflows required to settle the liability, what constitutes adequate restoration, inflation factors, credit adjusted

discount rates, and consideration of changes in legal, regulatory, environmental and political environments. Abandonment and restoration cost estimates are determined in conjunction with Barnwell’s reserve engineers based on historical information regarding costs incurred to abandon and restore similar

well sites, information regarding current market conditions and costs, and knowledge of subject well sites and properties. Asset retirement obligation fair value measurements in the current period were Level 3 fair value measurements.

~~13.~~14. DEBT

Canada Emergency Business Account Loan

In the quarter ended December 31, 2020, the Company’s Canadian subsidiary, Barnwell of Canada, received a loan of CAD$40,000 (in Canadian dollars) under the Canada Emergency Business Account (“CEBA”) loan program for small businesses. In the quarter ended March 31, 2021, the Company applied for an increase to our CEBA loan and received an additional CAD$20,000 for a total loan amount received of CAD$60,000 ($47,000) under the program. The CEBA loan is interest-free with no principal payments required until December 31, 2022, after which the remaining loan balance is converted to a three year term loan at 5% annual interest paid monthly. If the Company repays 66.6% of the principal amount prior to December 31, 2022, there will be loan forgiveness of 33.3% up to a maximum of CAD$20,000.

In January 2022, the Canadian government announced the extension of the CEBA loan repayment deadline and interest-free period from December 31, 2022 to December 31, 2023. Accordingly, the CEBA loan is interest-free with no principal payments required until December 31, 2023, after which the remaining loan balance is converted to a two year term loan at 5% annual interest paid monthly. If the Company repays 66.6% of the principal amount prior to December 31, 2023, there will be loan forgiveness of 33.3% up to a maximum of CAD$20,000.

~~14.~~15. STOCKHOLDERS' EQUITY (DEFICIT)

At The Market Offering

On March 16, 2021, the Company entered into a Sales Agreement (the “Sales Agreement”) with A.G.P./Alliance Global Partners (“A.G.P,”), with respect to an at-the-market offering program (“ATM”) pursuant to which the Company may offer and sell, from time to time, shares of its common stock, par value $0.50 per share, having an aggregate sales price of up to $25 million (subject to certain limitations set forth in the Sales Agreement and applicable securities laws, rules and regulations), through or to A.G.P as the Company’s sales agent or as principal. Sales of our common stock under the ATM, if any, will be made by any methods deemed to be “at the market offerings” as defined in Rule 415(a)(4) under the Securities Act, including sales made directly on the NYSE American, on any other existing trading market for our Common Stock, or to or through a market maker. Shares of common stock sold under the ATM are offered pursuant to the Company’s Registration Statement on Form S-3 (File No. 333-254365), filed with the Securities and Exchange Commission on March 16, 2021, and declared effective on March 26, 2021 (the "Registration Statement”), and the prospectus dated March 26, 2021, included in the Registration Statement.

~~The sale of shares under~~During the ~~ATM began in May 2021 and in fiscal 2021,~~six months ended March 31, 2022, the Company sold ~~1,167,987~~509,467 shares of common stock resulting in net proceeds of ~~$3,784,000~~$2,356,000 after commissions and fees of ~~$123,000. No shares were sold under the ATM during the three months ended December 31, 2021.~~$75,000 and ATM-related professional services of $22,000.

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~~15.~~16. CONTINGENCIES

Legal and Regulatory Matters

Barnwell is routinely involved in disputes with third parties that occasionally require litigation. In addition, Barnwell is required to maintain compliance with all current governmental controls and regulations in the ordinary course of business. Barnwell’s management is not aware of any claims or litigation involving Barnwell that are likely to have a material adverse effect on its results of operations, financial position or liquidity.

In the ~~three months~~quarter ended December 31, 2021, it was determined that a contract drilling segment well completed in the period did not meet the contract specifications for plumbness under a gyroscopic plumbness test which the contract required. While the well did pass the cage plumbness test, the contract uses the gyroscopic test as the measure of plumbness. Barnwell and the customer currently have a verbal arrangement where Barnwell will provide for centralizers and armored cabling and a warranty agreement, however Barnwell’s management believes the plumbness deviation is not impactful to the performance of the submersible pumps that will be installed in the well. Accordingly, while costs for the centralizers and armored cabling have been accrued, no accrual has been recorded as of ~~December~~March 31, ~~2021~~2022 for the warranty as there is no probable or estimable contingent liability.

~~16.~~17. INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS


	Six months ended March 31,
	2022		2021
Supplemental disclosure of cash flow information:
Cash paid during the year for:

Income taxes paid, net	$	302,000	$	85,000

Capital expenditure accruals related to oil and natural gas exploration and development increased ~~$1,851,000~~$443,000 during the ~~three~~six months ended ~~December~~March 31, ~~2021~~2022 and decreased ~~$225,000~~$381,000 during the ~~three~~six months ended ~~December~~March 31, ~~2020.~~2021. Additionally, capital expenditure accruals related to oil and natural gas asset retirement obligations increased ~~$304,000~~$2,341,000 during the ~~three~~six months ended ~~December~~March 31, ~~2021~~2022 and decreased ~~$176,000~~$12,000 during the ~~three~~six months ended ~~December~~March 31, ~~2020.~~2021.

~~17.~~18. RELATED PARTY TRANSACTIONS

Kaupulehu Developments is entitled to receive payments from the sales of lots and/or residential units by KD I and KD II. KD I and KD II are part of the Kukio Resort Land Development Partnerships in which Barnwell holds indirect 19.6% and 10.8% non-controlling ownership interests, respectively, accounted for under the equity method of investment. The percentage of sales payments are part of transactions which took place in 2004 and 2006 where Kaupulehu Developments sold its leasehold interests in Increment I and Increment II to KD I's and KD II's predecessors in interest, respectively, which was prior to Barnwell’s affiliation with KD I and KD II which commenced on November 27, 2013, the acquisition date of our ownership interest in the Kukio Resort Land Development Partnerships. Changes to the arrangement above, effective March 7, 2019, are discussed in Note 3.4.

During the ~~three~~six months ended ~~December~~March 31, ~~2021, Kaupulehu Developments~~2022, Barnwell received ~~$600,000~~$1,295,000 in percentage of sales payments from KD I1 from the sale of 36 single-family lots within Phase II of Increment I. During the ~~three~~six months ended ~~December~~March 31, ~~2020, Kaupulehu Developments~~2021, Barnwell received $485,000 in percentage of sales payments from KD I1 from the sale of 2 single-family lots within Phase II of Increment I.

Mr. Colin R. O'Farrell, a member of the Board of Directors of the Company ~~effective July 12, 2021,~~through March 7, 2022, is the sole member of Four Pines Operating LLC which owns a 25% interest in Gros Ventre. In

February 2021, Gros Ventre and BOK, a wholly-owned subsidiary of Barnwell, entered into the Teton Operating Agreement of Teton Barnwell, an entity formed for the purpose of directly investing in oil and natural gas exploration and development in Oklahoma. Under the terms of the Teton Operating Agreement, Gros Ventre makes no capital contributions and receives 2% of the profits of Teton Barnwell. Additionally, as the manager of Teton Barnwell, Gros ~~Ventre~~Venture is paid an annual asset management fee equal to 1% of the cumulative capital contributions made to Teton Barnwell as compensation for its management services.

~~18.~~19. SUBSEQUENT EVENTS

~~Oil and Natural Gas Property Acquisitions~~

Subsequent to ~~December~~March 31, ~~2021,~~2022, Barnwell ~~acquired additional working interests in oil and natural gas properties located~~received net cash distributions in the ~~Twining area~~amount of ~~Alberta, Canada for consideration of approximately $1,250,000. The purchase price per the agreement was adjusted for customary purchase price adjustments to reflect the economic activity~~$385,000 from the ~~effective date to the closing date. The final determination~~Kukio Resort Land Development Partnerships. Financial results of ~~the customary adjustments to the purchase price has not yet been made, however it is not expected to result in a material adjustment. This transaction~~this distribution will be reflected in Barnwell's quarter ending ~~March 31,~~June 30, 2022.

In May 2022, Barnwell’s stockholders approved the amendment to increase the Company’s number of authorized shares of common stock from 20,000,000 to 40,000,000 shares and approved the amendments to the Company’s 2018 Equity Incentive Plan (the “2018 Plan”) which included the amendment to increase the total number of shares of stock authorized for awards granted under the 2018 Plan from 800,000 to 1,600,000 shares amongst other amendments.

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, 2021, “Risk Factors” section of Barnwell’s Quarterly Report on Form 10-Q for the period ended December 31, 2021, and “Risk Factors” section of this Quarterly Report filed on Form 10-Q. Investors should not place undue reliance on these forward-looking statements, as they speak only as of the date of filing of this Form 10-Q, and Barnwell expressly disclaims any obligation or undertaking to publicly release any updates or revisions to any forward-looking statements contained herein.

Critical Accounting Policies and Estimates

Management has determined that our most critical accounting policies and estimates are those related to the full-cost ceiling calculation and depletion of our oil and natural gas properties, the estimation of our contract drilling segment's revenues and expenses, and the calculation of our income taxes, all of which are discussed in our Annual Report on Form 10-K, as amended by our Form 10-K/A Amendment ~~No. 1,~~No.1, for the fiscal year ended September 30, 2021. There have been no significant changes to these critical accounting policies and estimates during the three and six months ended ~~December~~March 31, ~~2021.~~2022. We continue to monitor our accounting policies to ensure proper application of current rules and regulations.

Impact of COVID-19

In March 2020, the World Health Organization declared the COVID-19 outbreak a global pandemic and the United States and Canadian governments declared the virus a national emergency shortly thereafter. The ongoing global health crisis (including resurgences) resulting from the pandemic have, and continue to, disrupt the normal operations of many businesses, including the temporary closure or scale-back of business operations and/or the imposition of either quarantine or remote work or meeting requirements for employees, either by government order or on a voluntary basis. While the outbreak recently appeared to be trending downward, particularly as vaccination rates increased, new variants of COVID-19 continue emerging, including the Omicron variant, spreading throughout the U.S. and globally

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and causing significant disruptions. The global economy, our markets and our business have been, and may continue to be, materially and adversely affected by COVID-19.

The COVID-19 outbreak materially and adversely affected our business operations and financial condition as a result of the deteriorating market outlook, the global economic recession and weakened liquidity. Although demand for oil and oil prices has ~~recovered~~increased significantly from the lows of March through May of 2020, uncertainty regarding future oil prices ~~has impacted and~~ continues to ~~impact the Company’s financial condition and outlook.~~exist. While the Company’s contract drilling segment remained operational throughout fiscal 2020 and 2021 and continues to work, the continuing potential impact of COVID-19 on the health of our contract drilling segment's crews is uncertain, and any work stoppage or discontinuation of contracts currently in backlog could result in a material adverse impact to the Company’s financial condition and outlook. Though availability of vaccines and reopening of state and local economies has improved the outlook for recovery from COVID-19's impacts, the impact of new, more contagious or lethal variants that may emerge, and the effectiveness of COVID-19 vaccines against variants and the related responses by governments, including reinstated government-imposed lockdowns or other measures, cannot be predicted at this time. Both the health and economic aspects of the COVID-19 pandemic remain highly fluid and the future course of each is uncertain. We cannot foresee whether the outbreak of COVID-19 will be effectively contained on a sustained basis, nor can we predict the severity and duration of its impact. If the ~~outbreak~~impact of COVID-19 is not effectively and timely controlled on a sustained basis going forward, our business operations and financial condition may be materially and adversely affected by 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.

Impact of Recently Issued Accounting Standards on Future Filings

In June 2016, the Financial Accounting Standards Board (“FASB”) issued ASU No. 2016-13, “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments,” which replaces the incurred loss model with an expected loss model referred to as the current expected credit loss (“CECL”) model. The CECL model is applicable to the measurement of credit losses on financial assets measured at amortized cost, including but not limited to trade receivables. This ASU is effective for annual reporting periods beginning after December 15, 2022, and interim periods within those annual periods. The FASB has subsequently issued other related ASUs which amend ASU 2016-13 to provide clarification and additional guidance. The Company is currently evaluating the impact of these standards.

Overview

Barnwell is engaged in the following lines of business: 1) acquiring, developing, producing and selling oil and natural gas in Canada and Oklahoma (oil and natural gas segment), 2) investing in land interests in Hawaii (land investment segment), and 3) drilling wells and installing and repairing water pumping systems in Hawaii (contract drilling segment).

Oil and Natural Gas Segment

Barnwell is involved in the acquisition and development of oil and natural gas properties in Canada where we initiate and participate in acquisition and developmental operations for oil and natural gas on properties in which we have an interest, and evaluate proposals by third parties with regard to

2629

participation in such exploratory and developmental operations elsewhere. Additionally, through its wholly-owned subsidiary BOK, Barnwell is indirectly involved in several non-operated oil and natural gas investments in Oklahoma.

Land Investment Segment

Through Barnwell’s 77.6% interest in Kaupulehu Developments, 75% interest in KD Kona, and 34.45% non-controlling interest in KKM Makai, the Company’s land investment interests include the following:

•The right to receive percentage of sales payments from KD I resulting from the sale of single-family residential lots by KD I, within Increment I of the 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~~10% 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.~~I. Increment I is an area zoned for approximately 80 single-family lots, of which ~~six~~three remained to be sold at ~~December~~March 31, ~~2021, and a beach club on the portion of the property bordering the Pacific Ocean, and is partially developed.~~2022.

•The right to receive 15% of the distributions of KD II, the cost of which is to be solely borne by KDK out of its 55% ownership interest in KD II, plus a priority payout of 10% of KDK's cumulative net profits derived from Increment II sales subsequent to Phase 2A, up to a maximum of $3,000,000. Such interests are limited to distributions or net profits interests and Barnwell does not have any partnership interest in KD II or KDK through its interest in Kaupulehu Developments. Barnwell also has rights to three single-family residential lots in Phase 2A of Increment II, and four single-family residential lots in phases subsequent to Phase 2A when such lots are developed by KD II, all at no cost to Barnwell. Barnwell is committed to commence construction of improvements within 90 days of the transfer of the four lots in the phases subsequent to Phase 2A as a condition of the transfer of such lots. Also, in addition to Barnwell's existing obligations to pay professional fees to certain parties based on percentages of its gross receipts, Kaupulehu Developments is now also obligated to pay an amount equal to 0.72% and 0.20% of the cumulative net profits of KD II to KD Development, LLC and a pool of various individuals, respectively, all of whom are partners of KKM and are unrelated to Barnwell. The remaining acreage within Increment II is not yet under development, and there is no assurance that development of such acreage will in fact occur. No definitive development plans have been made by the developer of Increment II as of the date of this report.

•An indirect 19.6% non-controlling ownership interest in KD Kukio Resorts, LLLP, KD Maniniowali, LLLP and KD I and an indirect 10.8% non-controlling ownership interest in KD II through KDK. These entities 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~~commissions on real estate sales by the real estate sales office and revenues resulting from the sale of private club memberships.

•Approximately 1,000 acres of vacant leasehold land zoned conservation in the Kaupulehu Lot 4C area, which currently has no development potential without both a development agreement with the lessor and zoning reclassification.

Contract Drilling Segment

Barnwell drills water and water monitoring wells and installs and repairs water pumping systems in Hawaii. Contract drilling results are highly dependent upon the quantity, dollar value and timing of contracts awarded by governmental and private entities and can fluctuate significantly.

Results of Operations

Summary

The net earnings attributable to Barnwell for the three months ended ~~December~~March 31, ~~2021~~2022 totaled ~~$1,073,000,~~$2,052,000, a ~~$489,000 increase~~$2,908,000 improvement in operating results from a net ~~earnings~~loss of ~~$584,000~~$856,000 for the three months ended ~~December~~March 31, ~~2020.~~2021. The following factors affected the results of operations for the three months ended ~~December~~March 31, ~~2021~~2022 as compared to the prior year period:

•A $1,783,000 improvement in oil and natural gas segment operating results, before income taxes, due primarily to a significant increase in oil and natural gas prices in the current period as compared to the same period in the prior ~~year:~~year and new production from wells drilled in Oklahoma;

•A ~~$1,941,000~~$1,136,000 increase in equity in income from affiliates as a result of increased operating results of the Kukio Resort Development Partnerships; and

•A $695,000 increase in land investment segment operating results, before non-controlling interests’ share of such profits, due to the sale of three lots in the current period, whereas there were no lot sales in the same period in the prior year.

The net earnings attributable to Barnwell for the six months ended March 31, 2022 totaled $3,125,000, a $3,397,000 improvement in operating results from a net loss of $272,000 for the six months ended March 31, 2021. The following factors affected the results of operations for the six months ended March 31, 2022 as compared to the prior year period:

•A $3,724,000 improvement in oil and natural gas segment operating results, before income taxes, due in part to a ceiling test impairment of $630,000 in the prior year period, whereas there was no such ceiling test impairment in the current year period. Also contributing to the increase was ana significant increase in oil and natural gas prices in the current period as compared to the same period in the prior ~~year;~~year and new production from wells drilled in Oklahoma;

•A ~~$909,000~~$1,289,000 increase in equity in income from affiliates as a result of increased operating results of the Kukio Resort Development Partnerships;

•An $810,000 increase in land investment segment operating results, before non-controlling interests’ share of such profits, due to the sale of six lots in the current period, whereas there were two lot sales in the same period in the prior year;

•An $897,000 decrease in contract drilling segment operating results, before income taxes, primarily due to a significant well drilling contract in the prior year period that was essentially completed as of December 31, 2020; and

•A ~~$645,000~~$958,000 increase in general and administrative expenses primarily due to increases in share-based compensation expense, compensation costs, and professional fees related to legal and consulting services in the current year period as compared to the same period in the prior ~~year.~~year, partially offset by a reduction in stockholder costs related to the cooperation and support agreement with the MRMP Stockholders in the prior year period as compared to the current year period.

General

Barnwell conducts operations in the U.S. and Canada. Consequently, Barnwell is subject to foreign currency translation and transaction gains and losses due to fluctuations of the exchange rates between the Canadian dollar and the U.S. dollar. Barnwell cannot accurately predict future fluctuations of the exchange rates and the impact of such fluctuations may be material from period to period. To date, we have not entered into foreign currency hedging transactions.

The average exchange rate of the Canadian dollar to the U.S. dollar ~~increased 3%~~remained unchanged in the three months ended ~~December~~March 31, ~~2021~~2022 and increased 2% in the six months ended March 31, 2022, as compared to the same ~~period~~periods in the prior ~~year, and the~~year. The exchange rate of the Canadian dollar to the U.S. dollar increased 1%2% at ~~December~~March 31, ~~2021~~2022, as compared to September 30, 2021. 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 liabilities are greater than its Canadian dollar assets; therefore, increases or decreases in the value of the Canadian dollar to the U.S. dollar generate other comprehensive loss or income, respectively. Other comprehensive income and losses are not included in net ~~earnings.~~earnings and net loss. Other

comprehensive ~~loss~~income due to foreign currency translation adjustments, net of taxes, for the three months ended ~~December~~March 31, ~~2021~~2022 was ~~$25,000,~~$12,000, a ~~$209,000~~$97,000 change from other comprehensive loss due to foreign currency translation adjustments, net of taxes, of ~~$234,000~~$85,000 for the same period in the prior year. Other comprehensive loss due to foreign currency translation adjustments, net of taxes, for the six months ended March 31, 2022 was $13,000, a $306,000 change from other comprehensive loss due to foreign currency translation adjustments, net of taxes, of $319,000 for the same period in the prior year. There were no taxes on other comprehensive ~~loss~~income (loss) due to foreign currency translation adjustments in the three and six months ended ~~December~~March 31, ~~2021~~2022 and ~~2020~~2021 due to a full valuation allowance on the related deferred tax ~~assets.~~asset.

Oil and ~~natural gas~~Natural Gas

The following tables set forth Barnwell’s average prices per unit of production and net production volumes. Production amounts reported are net of royalties.

Average Price Per Unit
Three months ended Increase
December 31, (Decrease)
2021 2020 $ %
Natural Gas (Mcf)* $ 4.08 $ 2.12 $ 1.96 92 %
Oil (Bbls)** $ 68.50 $ 35.48 $ 33.02 93 %
Liquids (Bbls)** $ 31.04 $ 21.96 $ 9.08 41 %


		Net Production						Average Price Per Unit
		Three months ended		Increase				Three months ended				Increase
		December 31,		(Decrease)				March 31,				(Decrease)
		2021	2020	Units	%			2022		2021		$		%
Natural Gas (Mcf)*	Natural Gas (Mcf)*	205,000	171,000	34,000	20	%	Natural Gas (Mcf)*	$	3.93	$	2.57	$	1.36	53	%
Oil (Bbls)**	Oil (Bbls)**	39,000	39,000	—	—		Oil (Bbls)**	$	87.64	$	50.03	$	37.61	75	%
Liquids (Bbls)**	Liquids (Bbls)**	13,000	6,000	7,000	117	%	Liquids (Bbls)**	$	61.70	$	31.60	$	30.10	95	%


	Average Price Per Unit
	Six months ended				Increase
	March 31,				(Decrease)
	2022		2021		$		%
Natural Gas (Mcf)*	$	4.00	$	2.35	$	1.65	70	%
Oil (Bbls)**	$	78.43	$	42.66	$	35.77	84	%
Liquids (Bbls)**	$	44.37	$	26.36	$	18.01	68	%


	Net Production
	Three months ended		Increase
	March 31,		(Decrease)
	2022	2021	Units	%
Natural Gas (Mcf)*	215,000	175,000	40,000	23	%
Oil (Bbls)**	42,000	38,000	4,000	11	%
Liquids (Bbls)**	10,000	5,000	5,000	100	%


	Net Production
	Six months ended		Increase
	March 31,		(Decrease)
	2022	2021	Units	%
Natural Gas (Mcf)*	420,000	346,000	74,000	21	%
Oil (Bbls)**	81,000	77,000	4,000	5	%
Liquids (Bbls)**	23,000	11,000	12,000	109	%

* 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 ~~$1,568,000 of~~a $2,430,000 operating profit before general and administrative expenses in the three months ended ~~December~~March 31, ~~2021,~~2022, an increase in operating results of ~~$1,941,000~~$1,783,000 as compared to the $647,000 operating profit before general and administrative expenses generated during the same period of the prior year.

The oil and natural gas segment generated a ~~$373,000~~$3,998,000 operating ~~loss~~profit before general and administrative expenses in the six months ended March 31, 2022, an increase in operating results of $3,724,000 as compared to the $274,000 operating profit before general and administrative expenses generated during the same period of the prior year. There was no ceiling test impairment during the three months ended March 31, 2022 and 2021. There was no ceiling test impairment during the six months ended March 31, 2022 and a $630,000 ceiling test impairment included in the operating loss in the prior year period, whereas there was no ceiling test impairment in the current year period due to an increase in the historical average first-day-of-the-month prices during the ~~12-month period~~six months ended ~~December~~March 31, ~~2021, as compared to those historical prices in~~2021.

Our Oklahoma operations generated $727,000 (30%) and $1,464,000 (37%) of our oil and natural gas segment operating profits for the ~~prior year period.~~three and six months ended March 31, 2022, respectively.

Oil and natural gas revenues increased ~~$2,033,000 (108%~~$2,581,000 (101%) and $4,614,000 (104%) for the three and six months ended ~~December~~March 31, ~~2021,~~2022, respectively, as compared to the same ~~period~~periods in the prior year, primarily due to ~~93% and 92%~~significant increases in oil and natural gas prices ~~respectively,~~as compared to the same periods in the prior year. Additionally, production increased due to new wells drilled in the Twining area and ~~117% and 20% increases~~Oklahoma, as well as due to additional working interests acquired in ~~natural gas liquids and natural gas production, respectively, primarily from new~~the Twining area. The increase in production from ~~Oklahoma properties. New oil~~these areas was partially offset by declines in non-core area production ~~from~~as some of these non-core

areas were sold in the ~~Oklahoma properties offset~~prior year, and Canadian net production also decreased as a result of higher royalty rates due to higher prices in the ~~decline in oil production from Canadian properties.~~ current year periods.

Oil and natural gas operating expenses increased ~~$481,000 (34%~~$367,000 (21%) and $848,000 (27%) for the three and six months ended ~~December~~March 31, ~~2021,~~2022, respectively, as compared to the same periods in the prior year, ~~period, primarily~~ due to ~~higher~~production from the new wells drilled in the Twining area and Oklahoma, as well as due to additional working interests acquired in the Twining area. The increase was also partially attributable to workovers, repairs, higher utilities and hauling costs, ~~at the Twining area,~~and restart costs for certain acquired wells, as well as ~~restart costs~~due to a minor pipeline leak that required remediation.

Oil and natural gas segment depletion increased $431,000 (295%) and $672,000 (197%) for the ~~Twining wells acquired in the previous fiscal year. The increase was partially offset by a decrease in costs due to lower production from Canadian properties in the current year period~~three and six months ended March 31, 2022, respectively, as compared to the ~~prior year period. Oil and natural gas~~

~~segment depletion increased $241,000 (124%) for the three months ended December 31, 2021, as compared to~~same periods in the prior ~~year period, primarily~~year. The increases were due to ~~$157,000 in~~ depletion ~~due~~attributable to production in Oklahoma, whereas there was no such depletion in the ~~three months ended December 31, 2020~~prior year periods, and ~~an increase~~increases in the depletion rate ~~due primarily to~~for Canadian properties as the result of the drilling of three new wells at the Twining ~~area. The depletion rate prior to~~area, the ~~drilling~~acquisition of additional working interests in the ~~three new wells was lower due to impact of prior ceiling test impairments on~~Twining area, and facilities development costs in the ~~depletion base.~~Twining area.

All seven of the non-operated wells in Oklahoma that the Company participated in drilling in the year ended September 30, 2021 were producing induring the ~~three~~six months ended ~~December~~March 31, ~~2021.~~2022. The Company’s share of net production from these wells plus one well with a minor overriding royalty interest totaled ~~6,000~~11,000 barrels of oil, ~~9,000~~14,000 barrels of natural gas liquids, and ~~67,000~~123,000 Mcf of natural gas for total revenues of ~~$964,000~~$1,956,000 during the ~~three~~six months ended ~~December~~March 31, ~~2021.~~2022. Our Oklahoma production is from shale oil wells that as a rule have steep production declines and accordingly, we estimate that their production will decline significantly.

Oil prices continue to be volatile over time and thus the Company is unable to reasonably predict future oil, natural gas and natural gas liquids prices and the impacts future prices will have on the Company.

Sale of ~~interest~~Interest in ~~leasehold land~~Leasehold Land

Kaupulehu Developments is entitled to receive a percentage of the gross receipts from the sales of lots and/or residential units in Increment I by KD I.

The following table summarizes the revenues received from KD I and the amount of fees directly related to such revenues:


		Three months ended December 31,					Three months ended March 31,				Six months ended March 31,
		2021		2020			2022		2021		2022		2021
Sale of interest in leasehold land:	Sale of interest in leasehold land:					Sale of interest in leasehold land:
Revenues – sale of interest in leasehold land		$	600,000	$	485,000
Revenues - sale of interest in leasehold land						Revenues - sale of interest in leasehold land	$	695,000	$	—	$	1,295,000	$	485,000
Fees - included in general and administrative expenses	Fees - included in general and administrative expenses	(73,000)		(59,000)		Fees - included in general and administrative expenses	(85,000)		—		(158,000)		(59,000)
Sale of interest in leasehold land, net of fees paid	Sale of interest in leasehold land, net of fees paid	$	527,000	$	426,000	Sale of interest in leasehold land, net of fees paid	$	610,000	$	—	$	1,137,000	$	426,000

During the three months ended ~~December~~March 31, ~~2021, Kaupulehu Developments~~2022, Barnwell received ~~$600,000~~$695,000 in percentage of sales payments from KD I from the sale of three single-family lots within Phase II of Increment I. ~~During~~No lots were sold during the three months ended ~~December~~March 31, ~~2020, Kaupulehu Developments~~2021.

During the six months ended March 31, 2022, Barnwell received $1,295,000 in percentage of sales payments from KD I from the sale of six single-family lots within Phase II of Increment I. During the six months ended March 31, 2021, Barnwell received $485,000 in percentage of sales payments from KD I1 from the sale of two single-family lots within Phase II of Increment I.

As of ~~December~~March 31, ~~2021, six~~2022, three single-family lots of the 80 lots developed within Increment I remained to be sold. The Company does not have a controlling interest in Increments I and II, and there is no assurance with regards to the amounts of future sales from Increments I and II, or that the remaining acreage within Increment II will be developed. No definitive development plans have been made by the developer of Increment II as of the date of this report.

Contract ~~drilling~~Drilling

Contract drilling revenues and contract drilling costs decreased ~~$1,066,000 (55%~~$571,000 (41%) and ~~$128,000 (12%~~$547,000 (37%), respectively, for the three months ended ~~December~~March 31, ~~2021,~~2022, as compared to the same period in the prior year. The contract drilling segment generated a ~~$151,000~~$141,000 operating loss before general and administrative expenses in the three months ended ~~December~~March 31, ~~2021,~~2022, an increase in operating results of $12,000 as compared to the $153,000 operating loss generated during the same period of the prior year.

Contract drilling revenues and contract drilling costs decreased $1,637,000 (49%) and $675,000 (26%), respectively, for the six months ended March 31, 2022, as compared to the same period in the prior year. The contract drilling segment generated a $292,000 operating loss before general and administrative expenses in the six months ended March 31, 2022, a decrease in operating results of ~~$909,000~~$897,000 as compared to ~~a $758,000~~the $605,000 operating profit generated during the same period of the prior year.

The ~~decrease~~decreases in contract drilling revenues and contract drilling costs for the three and six months ended ~~December~~March 31, ~~2021~~2022 as compared to the same periods in the prior year is due to decreased water well drilling activity and a lower amount of revenue and costs recognized for uninstalled materials installations in the current year periods as compared to the same periods in the prior year. The decrease in operating results discussed above for the six months ended March 31, 2022 as compared to the same period inof the prior year is primarily due to a significant well drilling contract in the prior year period. The significant well drilling contract was for multiple wells and was based on a fixed rate per day or fixed rate per hour, depending upon the activity, as opposed to the Company's typical contracts that are based on a fixed price per lineal foot drilled. Up to two drilling rigs were being used at this job during the prior year period with crews working extended hours. This contract generated a significant amount of operating profit in the prior year period. However, activity related to this relatively high margin contract was ~~essentially~~ completed in the prior year quarter ~~ended December 31, 2020~~ and thus ~~contract drilling revenues and costs have decreased in the current year period as compared~~did not contribute to ~~the same period of the prior year.~~operating results from that point forward.

armored cabling have been accrued, no accrual has been recorded as of ~~December~~March 31, ~~2021~~2022 for the warranty as there is no probable or estimable contingent liability.

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. The continuing potential impact of COVID-19 on the health of our contract drilling segment's crew is uncertain, and any work stoppage or discontinuation of contracts currently in backlog due to COVID-19 impacts could result in a material adverse impact to the Company’s financial condition and outlook.

General and ~~administrative expenses~~Administrative Expenses

General and administrative expenses increased ~~$645,000 (54%~~$313,000 (16%) for the three months ended ~~December~~March 31, ~~2021,~~2022 as compared to the same period in the prior year. The increase was primarily due to ~~increases~~an increase of $520,000 in ~~share-based compensation expense, compensation costs and~~ professional fees related to legal and consulting services in the current year period as compared to the same period in the prior ~~year.~~

~~Depletion, depreciation,~~year, partially offset by a reduction of $298,000 in stockholder costs related to the cooperation and ~~amortization~~

~~Depletion, depreciation,~~support agreement with the MRMP Stockholders in the prior year period as compared to the current year period. General and ~~amortization~~administrative expenses increased ~~$207,000 (75%~~$958,000 (31%) for the ~~three~~six months ended ~~December~~March 31, ~~2021,~~2022 as compared to the same period in the prior year. The increase was primarily due to due to increases of $276,000 in share-based compensation expense, $166,000 in compensation costs, and $659,000 in professional fees related to legal and consulting services in the current year period as compared to the same period in the prior year, ~~primarily~~partially offset by a reduction of $298,000 in stockholder costs related to the cooperation and support agreement with the MRMP Stockholders in the prior year period as compared to the current year period.

Depletion, Depreciation, and Amortization

Depletion, depreciation, and amortization increased $391,000 (172%) and $598,000 (119%) for the three and six months ended March 31, 2022, respectively, as compared to the same periods in the prior year. The increases were due to ~~$157,000 in~~ depletion ~~due~~attributable to production in Oklahoma, whereas there was no such depletion in the ~~three months ended December 31, 2020~~prior year periods, and ~~an increase~~increases in the depletion rate ~~due primarily to~~for Canadian properties as the result of the drilling of three new wells at the Twining area, ~~as discussed~~the acquisition of additional working interests in the ~~“Oil~~Twining area, and ~~natural gas” section above.~~facilities development costs in the Twining area.

Impairment of ~~assets~~Assets

Under the full cost method of accounting, the Company performs quarterly oil and natural gas ceiling test calculations. There was no ceiling test impairment during the three months ended ~~December~~March 31, 2022 and 2021. There was no ceiling test impairment during the six months ended March 31, 2022 and a $630,000 ceiling test impairment during the ~~three~~six months ended ~~December~~March 31, ~~2020.~~2021.

Equity in ~~income~~Income of ~~affiliates~~Affiliates

Barnwell recognized equity in income of affiliates of ~~$1,207,000~~$1,760,000 and $2,967,000 during the three and six months ended ~~December~~March 31, ~~2021,~~2022, respectively, as compared to ~~$1,054,000~~equity in income of affiliates of $624,000 and $1,678,000 during the three and six months ended ~~December~~March 31, ~~2020.~~2021, respectively. The increase ~~was~~in partnership income is primarily due to the Kukio Resort Land Development Partnerships' sale of ~~three~~six lots during the current year, ~~period~~of which three lots were sold in the quarter ended March 31, 2022, as compared to two lot sales in the prior year period, and more club memberships sold, partially offset by $459,000 in preferred return payments received from KKM in the prior year period as compared to none in the current year period.

recorded as equity in income of affiliates. Accordingly, the amount of equity in income of affiliates recognized in the ~~three~~six months ended ~~December~~March 31, ~~2021~~2022 was equivalent to the ~~$1,207,000~~$2,967,000 of distributions received in that period.

Income ~~taxes~~Taxes

Barnwell’s effective consolidated income tax rate, ~~for the three months ended December 31, 2021,~~ after adjusting earnings (loss) before income taxes for non-controlling interests, was ~~9%,~~6% and 7% for the three and six months ended March 31, 2022, respectively, as compared to ~~an effective income tax rate of 10%~~(4)% and (55)% for the three and six months ended ~~December~~March 31, ~~2020.~~

2021.

previously been recognized due to the Company's continuing full valuation allowance, are estimated to be partially utilized in the current year periods as the recognized benefit is now more likely than not.

Net ~~earnings attributable~~Earnings Attributable to ~~non-controlling interests~~

Non-controlling Interests

Earnings and losses attributable to non-controlling interests represent the non-controlling interests’ share of revenues and expenses related to the various partnerships and joint ventures in which Barnwell has controlling interests and consolidates.

Net earnings attributable to non-controlling interests totaled $346,000 and $613,000 for the three and six months ended ~~December~~March 31, ~~2021 totaled $267,000,~~2022, respectively, as compared to net earnings attributable to non-controlling interests of ~~$159,000~~$62,000 and $221,000 for the same ~~period~~periods in the prior year. The ~~increase~~changes of ~~$108,000 is~~$284,000 (458%) and $392,000 (177%) for the three and six months, respectively, are primarily due to increases in the amount of ~~Kukio Resort Land Development Partnerships'~~equity in income of affiliates and percentage of sales ~~proceeds received~~revenues in the current year ~~period~~periods as compared to the same ~~period~~periods in the prior year.

Liquidity and Capital Resources

Barnwell’s primary sources of liquidity are cash on hand, cash flow generated by operations, land investment segment proceeds, and starting in fiscal 2021, funds generated by the ATM program. At ~~December~~March 31, ~~2021,~~2022, Barnwell had ~~$10,676,000~~$11,026,000 in working capital.

Cash Flows

Cash flows provided by ~~operating activities~~operations totaled ~~$909,000~~$1,699,000 for the ~~three~~six months ended ~~December~~March 31, ~~2021,~~2022, as compared to cash flows ~~provided by operating activities~~used in operations of ~~$80,000~~$338,000 for the same period in the prior year. This ~~$829,000~~$2,037,000 change in operating cash flows was primarily due to higher operating results, before non-cash impairment expenses, for the oil and natural gas segment, which was partially offset by significantly lower operating results for the contract drilling segment in the current year period as compared to the prior year period. Additionally, the change was also due to an increase in distributions of income from the Kukio Resort Land Development Partnerships in the current year period as compared to the prior year period and fluctuations in working capital.

Cash flows ~~provided by~~used in investing activities totaled ~~$194,000~~$5,141,000 during the ~~three~~six months ended ~~December~~March 31, ~~2021,~~2022, as compared to cash flows provided by investing activities of ~~$875,000~~$413,000 during the

same period of the prior year. This ~~$681,000 decrease~~$5,554,000 change in investing cash flows was primarily due to an increase of ~~$338,000 in oil and natural gas capital expenditures, an increase of $317,000~~$1,563,000 in payments to acquire oil and natural gas properties and ~~a decrease~~an increase of ~~$813,000~~$4,671,000 in ~~distributions from equity investees in excess of earnings received in the prior year period as compared to none in the current year period,~~cash paid for oil and natural gas capital expenditures, partially offset by a $687,000 increase in proceeds from the sale of contract drilling assets in the current year period as compared to none in the prior year period.

Cash flows ~~used in~~provided by financing activities totaled ~~$251,000 during~~$1,799,000 for the ~~three~~six months ended ~~December~~March 31, ~~2021,~~2022, as compared to cash flows used in financing activities of ~~$217,000~~$285,000 for the six months ended March 31, 2021. The $2,084,000 change in financing cash flows was primarily attributed to $2,356,000 in proceeds from issuance of stock, net of costs, related to the Company's ATM offering in the current year period as compared to none in the prior year period, which was partially offset by an increase of $248,000 in distributions to non-controlling interests in the current year period as compared to the same period in the prior year.

Canada Emergency Business Account Loan

In the quarter ended December 31, 2020, the Company’s Canadian subsidiary, Barnwell of Canada, received a loan of CAD$40,000 (in Canadian dollars) under the Canada Emergency Business Account (“CEBA”) loan program for small businesses. In the quarter ended March 31, 2021, the Company applied for an increase to our CEBA loan and received an additional CAD$20,000 for a total loan amount received of CAD$60,000 ($47,000) under the program. In January 2022, the Canadian government announced the extension of the CEBA ~~program announced an extension to the~~loan repayment deadline and interest-free period from December 31, 2022 to December 31, 2023. Accordingly, the CEBA loan is interest-free with no principal payments required until December 31, 2023, after which the remaining loan balance is converted to a two year term loan at 5% annual interest paid monthly. If the Company repays 66.6% of the principal amount prior to December 31, 2023, there will be loan forgiveness of 33.3% up to a maximum of CAD$20,000.

At The Market Offering

On March 16, 2021, the Company entered into a Sales Agreement (the “Sales Agreement”) with A.G.P./Alliance Global Partners (“A.G.P,”), with respect to the ATM pursuant to which the Company may offer and sell, from time to time, shares of its common stock, par value $0.50 per share, having an aggregate sales price of up to $25 million (subject to certain limitations set forth in the Sales Agreement and applicable securities laws, rules and regulations), through or to A.G.P as the Company’s sales agent or as principal. Sales of our common stock under the ATM, if any, will be made by any methods deemed to be “at the market offerings” as defined in Rule 415(a)(4) under the Securities Act, including sales made directly on the NYSE American, on any other existing trading market for our Common Stock, or to or through a market maker. Shares of common stock sold under the ATM are offered pursuant to the Company’s Registration Statement on Form S-3 (File No. 333-254365), filed with the Securities and Exchange Commission on March 16, 2021, and declared effective on March 26, 2021 (the "Registration Statement”), and the prospectus dated March 26, 2021, included in the Registration Statement.

During the six months ended March 31, 2022, the Company sold 509,467 shares of common stock resulting in net proceeds of $2,356,000 after commissions and fees of $75,000 and ATM-related professional services of $22,000.

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 ~~$2,870,000~~$2,796,000 and $5,666,000 for the three and six months ended ~~December~~March 31, ~~2021,~~2022, respectively, as compared to ~~$139,000~~$32,000 and $171,000 for the same ~~period~~periods in the prior year.

The Company participated in the drilling of one operated and two non-operated for a total of three gross (1.6 net) wells in the Twining area of Alberta, Canada. The ~~drilling phases of the~~ wells were ~~largely complete as of December 31, 2021, with completion of those wells to occur~~completed and ~~expected production commencing~~began producing in ~~the latter part of~~ the three months ending March 31, 2022. Capital expenditures incurred for the drilling ~~phase~~ of these wells in the ~~three~~six months ended ~~December~~March 31, ~~2021~~2022 totaled approximately ~~$2,350,000.~~

~~All seven of the non-operated wells in Oklahoma that the Company participated in drilling in the year ended September 30, 2021 were producing in the three months ended December 31, 2021.~~$4,258,000.

Barnwell estimates that investments in oil and natural gas properties for fiscal 2022 will range from ~~$7,000,000~~$8,300,000 to ~~$9,500,000.~~$13,300,000. This estimated amount may increase or decrease as dictated by cash flows and management's assessment of the oil and natural gas environment and prospects.

Oil and Natural Gas ~~Properties~~Property Acquisitions

34In January 2022, Barnwell acquired additional working interests in oil and natural gas properties located in the Twining area of Alberta, Canada for consideration of $1,246,000. The purchase price per the agreement was adjusted for customary purchase price adjustments to reflect the economic activity from the effective date to the closing date. The final determination of the customary adjustments to the purchase price has not yet been made, however, it is not expected to result in a material adjustment. Barnwell also assumed $1,500,000 in asset retirement obligations associated with the acquisition.

There were no oil and natural gas working interest acquisitions during the ~~three~~six months ended ~~December~~March 31, ~~2020.~~2021.

ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

We have established disclosure controls and procedures to ensure that material information relating to Barnwell, including its consolidated subsidiaries, is made known to the officers who certify Barnwell’s financial reports and to other members of executive management and the Board of Directors.

As of ~~December~~March 31, ~~2021,~~2022, an evaluation was carried out by Barnwell’s Chief Executive Officer and Chief Financial Officer of the effectiveness of Barnwell’s disclosure controls and procedures. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that Barnwell’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) were effective as of ~~December~~March 31, ~~2021~~2022 to ensure that information required to be disclosed by Barnwell in the reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the Securities Exchange Act of 1934 and the rules thereunder.

Changes in Internal Control Over Financial Reporting

There was no change in Barnwell’s internal control over financial reporting during the quarter ended ~~December~~March 31, ~~2021~~2022 that materially affected, or is reasonably likely to materially affect, Barnwell’s internal control over financial reporting.

3540

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, for the fiscal year ended September 30, 2021 by adding the discussion below.

Risk Related to Oil and Natural Gas Segment

Actual revenues and operating expenses for our Oklahoma properties may differ from our estimates.

As revenue and operating expense information from our royalty and non-operated working interest properties in Oklahoma are generally received several months after the production month, the Company accrues for revenue and operating expenses by estimating our share of production volumes and costs based on data provided by the operator of the properties and product spot prices, and are subsequently adjusted to actual amounts in the period of receipt of actual data. Any identified differences between estimated revenue and operating cost estimates and actual data historically have not been significant, however at this time there is limited history to date and thus there is no assurance that actual information will not vary significantly from our estimates.

3641

ITEM 6. EXHIBITS


Exhibit Number						Description

31.1						Certification of Chief Executive Officer Pursuant To Section 302 of the Sarbanes-Oxley Act of 2002

31.2						Certification of Chief Financial Officer Pursuant To Section 302 of the Sarbanes-Oxley Act of 2002

32						Certification Pursuant To Section 906 of the Sarbanes-Oxley Act of 2002

101.INS						Inline XBRL Instance Document

101.SCH						Inline XBRL Taxonomy Extension Schema Document

101.CAL						Inline XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF						Inline XBRL Taxonomy Extension Definition Linkbase Document

101.LAB						Inline XBRL Taxonomy Extension Label Linkbase Document

101.PRE						Inline XBRL Taxonomy Extension Presentation Linkbase Document

104						Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

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 11,~~May 13, 2022	/s/ Russell M. Gifford
		Russell M. Gifford
		Executive Vice President,
		Chief Financial Officer,
		Treasurer and Secretary

3843

INDEX TO EXHIBITS


Exhibit Number						Description

31.1						Certification of Chief Executive Officer Pursuant To Section 302 of the Sarbanes-Oxley Act of 2002

31.2						Certification of Chief Financial Officer Pursuant To Section 302 of the Sarbanes-Oxley Act of 2002

32						Certification Pursuant To Section 906 of the Sarbanes-Oxley Act of 2002

101.INS						Inline XBRL Instance Document

101.SCH						Inline XBRL Taxonomy Extension Schema Document

101.CAL						Inline XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF						Inline XBRL Taxonomy Extension Definition Linkbase Document

101.LAB						Inline XBRL Taxonomy Extension Label Linkbase Document

101.PRE						Inline XBRL Taxonomy Extension Presentation Linkbase Document

104						Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

3944