10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

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

For the quarterly period ended December 31, 2019

or

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

Commission File Number 1-5103 

BARNWELL INDUSTRIES, INC.

(Exact name of registrant as specified in its charter) 

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

1100 Alakea Street, Suite 2900, Honolulu, Hawaii	96813
(Address of principal executive offices)	(Zip code)

(808) 531-8400

(Registrant’s telephone number, including area code)

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

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

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

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

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

Large accelerated filer	o		Accelerated filer	o
Non-accelerated filer	o	(Do not check if a smaller reporting company)	Smaller reporting company	x
			Emerging growth company	o

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

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

As of February 7, 2020 there were 8,277,160 shares of common stock, par value $0.50, outstanding.

BARNWELL INDUSTRIES, INC.

AND SUBSIDIARIES

INDEX

PART I.	FINANCIAL INFORMATION:
Item 1.	Financial Statements (Unaudited)
	Condensed Consolidated Balance Sheets - December 31, 2019 and September 30, 2019	3
	Condensed Consolidated Statements of Operations - three months ended December 31, 2019 and 2018	4
	Condensed Consolidated Statements of Comprehensive Income (Loss) - three months ended December 31, 2019 and 2018	5
	Condensed Consolidated Statements of Equity - three months ended December 31, 2019 and 2018	6
	Condensed Consolidated Statements of Cash Flows - three months ended December 31, 2019 and 2018	7
	Notes to Condensed Consolidated Financial Statements	8
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	25
Item 4.	Controls and Procedures	36
PART II.	OTHER INFORMATION:
Item 1A.	Risk Factors	37
Item 6.	Exhibits	39
	Signature	40
	Index to Exhibits	41

PART I - FINANCIAL INFORMATION

ITEM 1.    FINANCIAL STATEMENTS

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	December 31, 2019			September 30, 2019
ASSETS
Current assets:
Cash and cash equivalents	$	2,399,000		$	4,613,000
Accounts and other receivables, net of allowance for doubtful accounts of: $45,000 at December 31, 2019; $44,000 at September 30, 2019	3,220,000			1,884,000
Income taxes receivable	379,000			386,000
Operating lease right-of-use asset held for sale	2,226,000			—
Other current assets	1,681,000			1,821,000
Total current assets	9,905,000			8,704,000
Income taxes receivable, net of current portion	230,000			230,000
Asset for retirement benefits	1,393,000			—
Investments	937,000			980,000
Operating lease right-of-use assets	331,000			—
Property and equipment	76,560,000			72,522,000
Accumulated depletion, depreciation, and amortization	(66,034,000		)	(64,134,000		)
Property and equipment, net	10,526,000			8,388,000
Total assets	$	23,322,000		$	18,302,000
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	1,109,000		$	1,223,000
Accrued capital expenditures	1,984,000			287,000
Accrued compensation	159,000			205,000
Accrued operating and other expenses	1,097,000			1,079,000
Operating lease liability held for sale	2,441,000			—
Current portion of operating lease liabilities	108,000			—
Current portion of asset retirement obligation	720,000			330,000
Other current liabilities	1,055,000			1,644,000
Total current liabilities	8,673,000			4,768,000
Deferred rent	—			193,000
Operating lease liabilities	230,000			—
Liability for retirement benefits	4,609,000			5,785,000
Asset retirement obligation	6,097,000			6,059,000
Deferred income tax liabilities	159,000			168,000
Total liabilities	19,768,000			16,973,000
Commitments and contingencies
Equity:
Common stock, par value $0.50 per share; authorized, 20,000,000 shares: 8,445,060 issued at December 31, 2019 and September 30, 2019	4,223,000			4,223,000
Additional paid-in capital	1,350,000			1,350,000
Retained earnings	445,000			859,000
Accumulated other comprehensive loss, net	(273,000		)	(2,917,000		)
Treasury stock, at cost: 167,900 shares at December 31, 2019 and September 30, 2019	(2,286,000		)	(2,286,000		)
Total stockholders' equity	3,459,000			1,229,000
Non-controlling interests	95,000			100,000
Total equity	3,554,000			1,329,000
Total liabilities and equity	$	23,322,000		$	18,302,000

See Notes to Condensed Consolidated Financial Statements

3

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

	Three months ended   December 31,
	2019			2018
Revenues:
Oil and natural gas	$	2,141,000		$	1,232,000
Contract drilling	2,646,000			1,163,000
Sale of interest in leasehold land	—			165,000
Gas processing and other	63,000			35,000
	4,850,000			2,595,000
Costs and expenses:
Oil and natural gas operating	1,213,000			1,337,000
Contract drilling operating	1,814,000			1,316,000
General and administrative	1,496,000			1,548,000
Depletion, depreciation, and amortization	705,000			819,000
Impairment of assets	—			2,170,000
Interest expense	—			4,000
	5,228,000			7,194,000
Loss before equity in loss of affiliates and income taxes	(378,000		)	(4,599,000		)
Equity in loss of affiliates	(43,000		)	(79,000		)
Loss before income taxes	(421,000		)	(4,678,000		)
Income tax benefit	(2,000		)	(105,000		)
Net loss	(419,000		)	(4,573,000		)
Less: Net (loss) earnings attributable to non-controlling interests	(5,000		)	27,000
Net loss attributable to Barnwell Industries, Inc.	$	(414,000	)	$	(4,600,000	)
Basic and diluted net loss per common share attributable to Barnwell Industries, Inc. stockholders	$	(0.05	)	$	(0.56	)
Weighted-average number of common shares outstanding:
Basic and diluted	8,277,160			8,277,160

See Notes to Condensed Consolidated Financial Statements

4

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(Unaudited)

	Three months ended   December 31,
	2019			2018
Net loss	$	(419,000	)	$	(4,573,000	)
Other comprehensive income (loss):
Foreign currency translation adjustments, net of taxes of $0	5,000			(413,000		)
Retirement plans:
Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	60,000			17,000
Net actuarial gains arising during the period, net of taxes of $0	880,000			—
Curtailment gain, net of taxes of $0	1,699,000			—
Total other comprehensive income (loss)	2,644,000			(396,000		)
Total comprehensive income (loss)	2,225,000			(4,969,000		)
Less: Comprehensive (loss) income attributable to non-controlling interests	(5,000		)	27,000
Comprehensive income (loss) attributable to Barnwell Industries, Inc.	$	2,230,000		$	(4,996,000	)

See Notes to Condensed Consolidated Financial Statements

5

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

Three months ended December 31, 2019 and 2018

(Unaudited)

	Shares Outstanding	Common Stock		Additional Paid-In Capital		Retained Earnings			Accumulated Other Comprehensive Loss			Treasury Stock			Non-controlling Interests			Total Equity
Balance at September 30, 2018	8,277,160	$	4,223,000	$	1,350,000	$	13,253,000		$	(514,000	)	$	(2,286,000	)	$	213,000		$	16,239,000
Cumulative impact from the adoption of ASU No. 2014-09	—	—		—		20,000			—			—			—			20,000
Distributions to non-controlling interests	—	—		—		—			—			—			(107,000		)	(107,000		)
Net (loss) earnings	—	—		—		(4,600,000		)	—			—			27,000			(4,573,000		)
Foreign currency translation adjustments, net of taxes of $0	—	—		—		—			(413,000		)	—			—			(413,000		)
Retirement plans:
Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	—	—		—		—			17,000			—			—			17,000
Balance at December 31, 2018	8,277,160	$	4,223,000	$	1,350,000	$	8,673,000		$	(910,000	)	$	(2,286,000	)	$	133,000		$	11,183,000
Balance at September 30, 2019	8,277,160	$	4,223,000	$	1,350,000	$	859,000		$	(2,917,000	)	$	(2,286,000	)	$	100,000		$	1,329,000
Net loss	—	—		—		(414,000		)	—			—			(5,000		)	(419,000		)
Foreign currency translation adjustments, net of taxes of $0	—	—		—		—			5,000			—			—			5,000
Retirement plans:
Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	—	—		—		—			60,000			—			—			60,000
Net actuarial gains arising during the period, net of taxes of $0	—	—		—		—			880,000			—			—			880,000
Curtailment gain, net of taxes of $0									1,699,000									1,699,000
Balance at December 31, 2019	8,277,160	$	4,223,000	$	1,350,000	$	445,000		$	(273,000	)	$	(2,286,000	)	$	95,000		$	3,554,000

See Notes to Condensed Consolidated Financial Statements

6

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three months ended   December 31,
	2019			2018
Cash flows from operating activities:
Net loss	$	(419,000	)	$	(4,573,000	)
Adjustments to reconcile net loss to net cash
used in operating activities:
Equity in loss of affiliates	43,000			79,000
Depletion, depreciation, and amortization	705,000			819,000
Impairment of assets	—			2,170,000
Retirement benefits expense	71,000			54,000
Accretion of asset retirement obligation	134,000			150,000
Income tax receivable, noncurrent	—			(31,000		)
Non-cash rent expense	30,000			22,000
Deferred income tax benefit	(9,000		)	(72,000		)
Asset retirement obligation payments	(2,000		)	(33,000		)
Share-based compensation benefit	—			(24,000		)
Retirement plan contributions and payments	(2,000		)	(2,000		)
Sale of interest in leasehold land, net of fees paid	—			(124,000		)
(Decrease) increase from changes in current assets and liabilities	(1,917,000		)	567,000
Net cash used in operating activities	(1,366,000		)	(998,000		)
Cash flows from investing activities:
Proceeds from the maturity of certificates of deposit	—			741,000
Net proceeds from sale of interest in leasehold land	—			124,000
Distribution from equity investees in excess of earnings	—			352,000
Proceeds from sale of oil and natural gas assets	594,000			633,000
Payments to acquire oil and natural gas properties	—			(355,000		)
Capital expenditures - oil and natural gas	(1,444,000		)	(108,000		)
Capital expenditures - all other	(13,000		)	(96,000		)
Net cash (used in) provided by investing activities	(863,000		)	1,291,000
Cash flows from financing activities:
Distributions to non-controlling interests	—			(107,000		)
Net cash used in financing activities	—			(107,000		)
Effect of exchange rate changes on cash and cash equivalents	15,000			(53,000		)
Net (decrease) increase in cash and cash equivalents	(2,214,000		)	133,000
Cash and cash equivalents at beginning of period	4,613,000			5,965,000
Cash and cash equivalents at end of period	$	2,399,000		$	6,098,000

See Notes to Condensed Consolidated Financial Statements

7

BARNWELL INDUSTRIES, INC.

AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1.    SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Principles of Consolidation

The condensed consolidated financial statements include the accounts of Barnwell Industries, Inc. and all majority-owned subsidiaries (collectively referred to herein as “Barnwell,” “we,” “our,” “us,” or the “Company”), including a 77.6%-owned land investment general partnership (Kaupulehu Developments) and a 75%-owned land investment partnership (KD Kona 2013 LLLP). All significant intercompany accounts and transactions have been eliminated.

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

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

Unaudited Interim Financial Information

The accompanying unaudited condensed consolidated financial statements and notes have been prepared by Barnwell in accordance with the rules and regulations of the United States (“U.S.”) Securities and Exchange Commission. Accordingly, certain information and footnote disclosures normally included in the annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to those rules and regulations, although the Company believes that the disclosures made are adequate to make the information not misleading. These condensed consolidated financial statements and notes should be read in conjunction with the consolidated financial statements and notes thereto included in Barnwell’s September 30, 2019 Annual Report on Form 10-K, as amended by our Form 10-K/A Amendment No. 1 and Form 10-K/A Amendment No. 2. The Condensed Consolidated Balance Sheet as of September 30, 2019 has been derived from audited consolidated financial statements.

In the opinion of management, all adjustments (which include only normal recurring adjustments) necessary to present fairly the financial position at December 31, 2019, results of operations, comprehensiveincome (loss), equity and cash flows for the three months ended December 31, 2019 and 2018, have been made. The results of operations for the period ended December 31, 2019 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

8

retirement plans, contract drilling estimated costs to complete, proved oil and natural gas reserves, and the carrying value of other assets, and such assumptions may impact the amount at which such items are recorded.

Significant Accounting Policies

Other than the accounting policies implemented in connection with the adoption of Accounting Standards Update (“ASU”) No. 2016-02, “Leases (Topic 842)” discussed in Note 11, 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 and Form 10-K/A Amendment No. 2.

Recently Adopted Accounting Pronouncements

In February 2016, the Financial Accounting Standards Board (“FASB”) issued ASU No. 2016-02, “Leases (Topic 842),” which requires an entity to recognize a right-of-use (“ROU”) asset and a lease liability on the balance sheet for all leases with terms greater than 12 months at the lease commencement date. The Company adopted the provisions of this ASU effective October 1, 2019. See Note 11 “Leases” for the required disclosures related to the impact of adopting this standard.

In February 2018, the FASB issued ASU No. 2018-02, “Reclassification of Certain Tax Effects From Accumulated Other Comprehensive Income,” which allows a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the Tax Cuts and Jobs Act of 2017. The Company adopted the provisions of this ASU effective October 1, 2019. The adoption of this update did not have an impact on Barnwell's consolidated financial statements.

In July 2018, the FASB issued ASU No. 2018-09, “Codification Improvements,” which provides further clarification to the codification literature. The Company adopted the provisions of this ASU effective October 1, 2019. The adoption of this update did not have an impact on Barnwell's consolidated financial statements.

2.    LOSS PER COMMON SHARE

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

Options to purchase 60,000 and 318,750 shares of common stock were excluded from the computation of diluted shares for the three months ended December 31, 2019 and 2018, respectively, as their inclusion would have been anti-dilutive.

9

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

	Three months ended December 31, 2019
	Net Loss (Numerator)			Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(414,000	)	8,277,160	$	(0.05	)
Effect of dilutive securities -
common stock options	—			—
Diluted net loss per share	$	(414,000	)	8,277,160	$	(0.05	)

	Three months ended December 31, 2018
	Net Loss (Numerator)			Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(4,600,000	)	8,277,160	$	(0.56	)
Effect of dilutive securities -
common stock options	—			—
Diluted net loss per share	$	(4,600,000	)	8,277,160	$	(0.56	)

3.    INVESTMENTS

A summary of Barnwell’s non-current investments is as follows:

	December 31, 2019		September 30, 2019
Investment in Kukio Resort Land Development Partnerships	$	887,000	$	930,000
Investment in leasehold land interest – Lot 4C	50,000		50,000
Total non-current investments	$	937,000	$	980,000

Investment in Kukio Resort Land Development Partnerships

On November 27, 2013, Barnwell, through a wholly-owned subsidiary, entered into two limited liability limited partnerships, KD Kona 2013 LLLP and KKM Makai, LLLP (“KKM”), and indirectly acquired a 19.6% non-controlling ownership interest in each of KD Kukio Resorts, LLLP, KD Maniniowali, LLLP and KD Kaupulehu, LLLP (“KDK”) for $5,140,000. These entities, collectively referred to hereinafter as the “Kukio Resort Land Development Partnerships,” own certain real estate and development rights interests in the Kukio, Maniniowali and Kaupulehu portions of Kukio Resort, a private residential community on the Kona coast of the island of Hawaii, as well as Kukio Resort’s real estate sales office operations. KDK holds interests in KD Acquisition, LLLP (“KD I”) and KD Acquisition II, LP, formerly KD Acquisition II, LLLP (“KD II”). KD I is the developer of Kaupulehu Lot 4A Increment I (“Increment I”), and KD II is the developer of Kaupulehu Lot 4A Increment II (“Increment II”). Barnwell's ownership interests in the Kukio Resort Land Development Partnerships is accounted for using the equity method of accounting. The partnerships derive income from the sale of residential parcels, of which 19 lots remain to be sold at Increment I as of December 31, 2019, as well as from commissions on real estate sales by the real estate sales office.

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In March 2019, KD II admitted a new development partner, Replay Kaupulehu Development, LLC (“Replay”), a party unrelated to Barnwell, in an effort to move forward with development of the remainder of Increment II at Kaupulehu. Effective March 7, 2019, KDK and Replay hold ownership interests of 55% and 45%, respectively, of KD II. Accordingly, Barnwell has a 10.8% indirect non-controlling ownership interest in KD II through KDK as of that date that will continue to be accounted for using the equity method of accounting. Barnwell continues to have an indirect 19.6% non-controlling ownership interest in KD Kukio Resorts, LLLP, KD Maniniowali, LLLP, and KD I.

There were no cash distributions from the Kukio Resort Land Development Partnership for the three months ended December 31, 2019. During the three months ended December 31, 2018, Barnwell received net cash distributions in the amount of $314,000 from the Kukio Resort Land Development Partnerships after distributing $38,000 to non-controlling interests.

Barnwell has the right to receive distributions from its non-controlling interest in KKM in proportion to its partner capital sharing ratio of 34.45%. Barnwell is entitled to a 100% preferred return up to $1,000,000 from KKM on any allocated equity in income of the Kukio Resort Land Development Partnerships for cumulative distributions to all of its partners in excess of $45,000,000 from those partnerships. Cumulative distributions from the Kukio Resort Land Development Partnerships have reached the $45,000,000 threshold. However, because we have no control over the distributions from the Kukio Resort Land Development Partnerships and the ability of the Kukio Resort Land Development Partnerships to make such distributions is dependent upon their future sales of lots, we have not recorded any estimated potential preferred return from KKM in our equity in income to date. However, if sufficient distributions are made by the Kukio Resort Land Development Partnerships in the future, Barnwell will have equity in income of affiliates for the recognition of the preferred return. There is no assurance that any future distributions and resulting preferred returns will occur.

Equity in loss of affiliates was $43,000 and $79,000for the three months ended December 31, 2019 and 2018, respectively. The equity in the underlying net assets of the Kukio Resort Land Development Partnerships exceeds the carrying value of the investment in affiliates by approximately $296,000 as of December 31, 2019, which is attributable to differences in the value of capitalized development costs and a note receivable. The basis difference will be recognized as the partnerships sell lots and recognize the associated costs and sell memberships for the Kuki`o Golf and Beach Club for which the receivable relates. There was an immaterial basis difference adjustment for the three months ended December 31, 2019. The basis difference adjustment of $1,000, for the three months ended December 31, 2018, increased equity in income of affiliates.

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

	Three months ended   December 31,
	2019			2018
Revenue	$	1,766,000		$	1,948,000
Gross profit	$	796,000		$	646,000
Net loss	$	(168,000	)	$	(158,000	)

Sale of Interest in Leasehold Land

Kaupulehu Developments has the right to receive payments from KD I and KD II resulting from the sale of lots and/or residential units within Increment I and Increment II by KD I and KD II (see Note 14).

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With respect to Increment I, Kaupulehu Developments is entitled to receive payments from KD I based on the following percentages of the gross receipts from KD I’s sales of single-family residential lots in Increment I: 10% of such aggregate gross proceeds greater than $100,000,000 up to $300,000,000; and 14% of such aggregate gross proceeds in excess of $300,000,000. The total amount of gross proceeds from single-family lot sales was $216,400,000 through December 31, 2019. No single-family lots were sold during the three months ended December 31, 2019 and 19 single-family lots, of the 80 lots developed within Increment I, remained to be sold as of December 31, 2019.

Under the terms of the former Increment II agreement with KD II, Kaupulehu Developments was entitled to receive payments from KD II resulting from the sale of lots and/or residential units by KD II within Increment II. Through March 6, 2019, the payments were based on a percentage of gross receipts from KD II's sales ranging from 8% to 10% of the price of improved or unimproved lots or 2.60% to 3.25% of the price of units constructed on a lot, to be determined in the future depending upon a number of variables, including whether the lots are sold prior to improvement. Two ocean front parcels approximately two to three acres in size fronting the ocean were developed within Increment II by KD II, of which one was sold in fiscal 2017 and one was sold in fiscal 2016. The remaining acreage within Increment II is not yet under development.

Through March 6, 2019, Kaupulehu Developments was also entitled to receive 50% of distributions otherwise payable from KD II to its members after the members of KD II have received distributions equal to the original basis of capital invested in the project, up to $8,000,000. Through March 6, 2019, a cumulative total of $3,500,000 was received from KD II under this arrangement, out of the $8,000,000 maximum. The former arrangement also included the rights to three single-family residential lots in Phase 2 of Increment II when developed, at no cost to Barnwell, with a commitment by Barnwell to begin to construct a residence upon each lot within six months of transfer.

Concurrent with the transaction whereby KD II admitted Replay as a new development partner, Kaupulehu Developments entered into new agreements with KD II whereby the aforementioned terms of the former Increment II arrangement were eliminated and Kaupulehu Developments will instead be entitled to 15% of the distributions of KD II, the cost of which is to be solely borne by KDK out of its 55% ownership interest in KD II, plus a priority payout of 10% of KDK’s cumulative net profits derived from Increment II sales subsequent to Phase 2A, up to a maximum of $3,000,000 as to the priority payout. Such interests are limited to distributions or net profits interests and Barnwell will not have any partnership interests in KD II or KDK through its interest in Kaupulehu Developments. The new arrangement also gives Barnwell rights to 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, in compensation for the agreement of these parties to admit the new development partner for Increment II. Such compensation will be reflected as the obligation becomes probable and the amount of the obligation can be reasonably estimated. The new agreements also specify that Kaupulehu Developments was to be paid $1,000,000 by KD II prior to admission of Replay as a partner. This $1,000,000 payment had already been received in June 2018 and is included in the $3,500,000 cumulative total as of March 6, 2019 discussed above.

The Increment I percentage of sales arrangement between Barnwell and KD I remains unchanged.

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

	Three months ended   December 31,
	2019		2018
Sale of interest in leasehold land:
Revenues - sale of interest in leasehold land	$	—	$	165,000
Fees - included in general and administrative expenses	—		(20,000		)
Sale of interest in leasehold land, net of fees paid	$	—	$	145,000

Investment in Leasehold Land Interest - Lot 4C

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

4.    OIL AND NATURAL GAS PROPERTIES

Dispositions

In October 2019, Barnwell entered into a purchase and sale agreement with an independent third party and sold its interests in properties located in the Progress area of Alberta, Canada. The sales price per the agreement was adjusted for customary purchase price adjustments to $594,000 in order to, among other things, reflect an economic effective date of October 1, 2019. The final determination of the customary adjustments to the purchase price has not yet been made however it is not expected to result in a material adjustment. The proceeds were credited to the full cost pool, with no gain or loss recognized, as the sale did not result in a significant alteration of the relationship between capitalized costs and proved reserves.

There were no oil and natural gas property dispositions during the three months ended December 31, 2018. The $633,000 of proceeds from sale of oil and gas properties included in the Condensed Consolidated Statement of Cash Flows for the three months ended December 31, 2018 represents the refund of income taxes previously withheld from what otherwise would have been proceeds on the previous years' oil and natural gas property sales.

Acquisitions

There were no significant amounts paid for oil and natural gas property acquisitions during the three months ended December 31, 2019.

In the quarter ended December 31, 2018, Barnwell acquired additional working interests in oil and natural gas properties located in the Wood River and Twining areas of Alberta, Canada for cash consideration of $355,000. The purchase prices per the agreements were adjusted for customary purchase price adjustments to reflect the economic activity from the effective date to the closing date. The customary purchase price adjustments were finalized in the quarter ended June 30, 2019 and resulted in an immaterial adjustment.

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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 no ceiling test impairment during the three months ended December 31, 2019. There was a ceiling test impairment of $2,170,000 during the three months ended December 31, 2018.

Changes in the 12-month rolling average first-day-of-the-month prices for oil, natural gas and natural gas liquids prices, the value of reserve additions as compared to the amount of capital expenditures to obtain them, and changes in production rates and estimated levels of reserves, future development costs and the market value of unproved properties, impact the determination of the maximum carrying value of oil and natural gas properties. In addition, the ceiling test is also impacted by any changes in management's quarterly evaluation of the Company's ability to fund the approximately $12,000,000 of future capital expenditures necessary over the next five years to develop the proved undeveloped reserves that are largely in the Twining areas of Alberta, Canada, the value of which is included in the calculation of the ceiling limitation. If facts, circumstances, estimates and assumptions underlying management's assessment of the Company's ability to fund such capital expenditures change such that it is no longer reasonably certain that all of the approximately $12,000,000 of capital expenditures necessary to develop the proved undeveloped reserves can be made, it is likely that we will incur a further ceiling test impairment at that time.

5.    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 Employee Retirement Plan (“SERP”), a noncontributory supplemental retirement benefit plan which covers certain current and former employees of Barnwell for amounts exceeding the limits allowed under the Pension Plan, and a postretirement medical insurance benefits plan (“Postretirement Medical”) covering eligible U.S. employees.

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

	Pension Plan						SERP						Postretirement Medical
	Three months ended December 31,
	2019			2018			2019			2018			2019		2018
Service cost	$	50,000		$	50,000		$	3,000		$	9,000		$	—	$	—
Interest cost	83,000			93,000			18,000			21,000			20,000		25,000
Expected return on plan assets	(163,000		)	(161,000		)	—			—			—		—
Amortization of prior service cost (credit)	1,000			1,000			(1,000		)	(1,000		)	—		—
Amortization of net actuarial loss	35,000			3,000			5,000			1,000			20,000		13,000
Curtailment cost (income)	53,000			—			(53,000		)	—			—		—
Net periodic benefit cost (income)	$	59,000		$	(14,000	)	$	(28,000	)	$	30,000		$	40,000	$	38,000

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

On December 12, 2019, the Company’s Board of Directors approved a resolution to freeze all future benefit accruals for all participants under the Company’s Pension Plan and SERP effective December 31, 2019. Accordingly, the Company remeasured the projected benefit obligation of the Pension Plan and SERP

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as of December 31, 2019. As a result of the remeasurement, the Company recorded a $880,000 actuarial gain in accumulated other comprehensive loss during the quarter ended December 31, 2019. The actuarial gain was primarily due to an increase in the market value of Pension Plan assets as well as an increase in the discount rate for both plans during the period. The impact of the Pension Plan and SERP plan freeze resulted in a $1,699,000 reduction in unrecognized pension benefit costs that were previously included in accumulated other comprehensive loss, with a corresponding benefit in other comprehensive income.

No contributions will be made to the Pension Plan during fiscal 2020. The SERP and Postretirement Medical plans are unfunded, and Barnwell funds benefits when payments are made. Expected payments under the Postretirement Medical plan and the SERP for fiscal 2020 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.

6.    INCOME TAXES

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

	Three months ended   December 31,
	2019			2018
United States	$	(147,000	)	$	(1,124,000	)
Canada	(269,000		)	(3,581,000		)
	$	(416,000	)	$	(4,705,000	)

The components of the income tax benefit are as follows:

	Three months ended   December 31,
	2019			2018
Current	$	7,000		$	(33,000	)
Deferred	(9,000		)	(72,000		)
	$	(2,000	)	$	(105,000	)

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 and any amounts estimated to be realizable through tax carryback strategies, 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.

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7.    REVENUE FROM CONTRACTS WITH CUSTOMERS

Disaggregation of Revenue

The following tables provides information about disaggregated revenue by revenue streams, reportable segments, geographical region, and timing of revenue recognition for the three months ended December 31, 2019 and 2018.

		Three months ended December 31, 2019
		Oil and natural gas		Contract drilling		Land investment		Other		Total
Revenue streams:
	Oil	$	1,725,000	$	—	$	—	$	—	$	1,725,000
	Natural gas	322,000		—		—		—		322,000
	Natural gas liquids	94,000		—		—		—		94,000
	Drilling and pump	—		2,646,000		—		—		2,646,000
	Contingent residual payments	—		—		—		—		—
	Other	—		—		—		56,000		56,000
	Total revenues before interest income	$	2,141,000	$	2,646,000	$	—	$	56,000	$	4,843,000
Geographical regions:
	United States	$	—	$	2,646,000	$	—	$	7,000	$	2,653,000
	Canada	2,141,000		—		—		49,000		2,190,000
	Total revenues before interest income	$	2,141,000	$	2,646,000	$	—	$	56,000	$	4,843,000
Timing of revenue recognition:
	Goods transferred at a point in time	$	2,141,000	$	—	$	—	$	56,000	$	2,197,000
	Services transferred over time	—		2,646,000		—		—		2,646,000
	Total revenues before interest income	$	2,141,000	$	2,646,000	$	—	$	56,000	$	4,843,000

		Three months ended December 31, 2018
		Oil and natural gas		Contract drilling		Land investment		Other		Total
Revenue streams:
	Oil	$	896,000	$	—	$	—	$	—	$	896,000
	Natural gas	162,000		—		—		—		162,000
	Natural gas liquids	174,000		—		—		—		174,000
	Drilling and pump	—		1,163,000		—		—		1,163,000
	Contingent residual payments	—		—		165,000		—		165,000
	Other	—		—		—		14,000		14,000
	Total revenues before interest income	$	1,232,000	$	1,163,000	$	165,000	$	14,000	$	2,574,000
Geographical regions:
	United States	$	—	$	1,163,000	$	165,000	$	—	$	1,328,000
	Canada	1,232,000		—		—		14,000		1,246,000
	Total revenues before interest income	$	1,232,000	$	1,163,000	$	165,000	$	14,000	$	2,574,000
Timing of revenue recognition:
	Goods transferred at a point in time	$	1,232,000	$	—	$	165,000	$	14,000	$	1,411,000
	Services transferred over time	—		1,163,000		—		—		1,163,000
	Total revenues before interest income	$	1,232,000	$	1,163,000	$	165,000	$	14,000	$	2,574,000

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Contract Balances

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

	December 31, 2019		September 30, 2019
Accounts receivables from contracts with customers	$	2,862,000	$	1,322,000
Contract assets	551,000		344,000
Contract liabilities	1,043,000		1,633,000

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

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

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

When the Company receives consideration, or such consideration is unconditionally due, from a customer prior to transferring goods or services to the customer under the terms of a sales contract, the Company records deferred revenue, which represents a contract liability. Such deferred revenue typically results from billings in excess of costs and estimated earnings on uncompleted contracts. As of December 31, 2019 and September 30, 2019, the Company had $1,043,000 and $1,633,000, respectively, included in “Other current liabilities” on the balance sheet for those performance obligations expected to be completed in the next twelve months.

During the three months ended December 31, 2019 and 2018, the amount of revenue recognized that was previously included in contract liabilities as of the beginning of the respective period was $1,480,000 and $21,000, 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.

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Performance Obligations

The Company’s remaining performance obligations for drilling and pump installation contracts (hereafter referred to as “backlog”) represent the unrecognized revenue value of the Company’s contract commitments. The Company’s backlog may vary significantly each reporting period based on the timing of major new contract commitments. In addition, our customers have the right, under some infrequent circumstances, to terminate contracts or defer the timing of the Company’s services and their payments to us. Nearly all of the Company's contract drilling segment contracts have original expected durations of one year or less. At December 31, 2019, the Company had three contract drilling jobs with original expected durations of greater than one year. For these contracts, approximately 78% of the remaining performance obligation of $2,556,000 is expected to be recognized as revenue in the next twelve months and the remaining, thereafter. At September 30, 2019, the Company had three contract drilling jobs with original durations of greater than one year. For those contracts, approximately 79% of the remaining performance obligation of $2,866,000 was expected to be recognized as revenue in the next twelve months and the remaining, thereafter.

Contract Fulfillment Costs

Preconstruction costs, which include costs such as set-up and mobilization, are capitalized and allocated across all performance obligations and deferred and amortized over the contract term on a progress towards completion basis. As of December 31, 2019 and September 30, 2019, the Company had $258,000 and $296,000, respectively, in unamortized preconstruction costs related to contracts that were not completed. During the three months ended December 31, 2019 and 2018, the amortization of preconstruction costs related to contracts were not material and were included in the accompanying Condensed Consolidated Statements of Operations. Additionally, no impairment charges in connection with the Company’s preconstruction costs were recorded during the three months ended December 31, 2019 and 2018.

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8.    SEGMENT INFORMATION

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

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

	Three months ended   December 31,
	2019			2018
Revenues:
Oil and natural gas	$	2,141,000		$	1,232,000
Contract drilling	2,646,000			1,163,000
Land investment	—			165,000
Other	56,000			14,000
Total before interest income	4,843,000			2,574,000
Interest income	7,000			21,000
Total revenues	$	4,850,000		$	2,595,000
Depletion, depreciation, and amortization:
Oil and natural gas	$	606,000		$	749,000
Contract drilling	85,000			57,000
Other	14,000			13,000
Total depletion, depreciation, and amortization	$	705,000		$	819,000
Impairment:
Oil and natural gas	$	—		$	2,170,000
Total impairment	$	—		$	2,170,000
Operating profit (loss) (before general and administrative expenses):
Oil and natural gas	$	322,000		$	(3,024,000	)
Land investment	—			165,000
Contract drilling	747,000			(210,000		)
Other	42,000			1,000
Total operating profit (loss)	1,111,000			(3,068,000		)
Equity in loss of affiliates:
Land investment	(43,000		)	(79,000		)
General and administrative expenses	(1,496,000		)	(1,548,000		)
Interest expense	—			(4,000		)
Interest income	7,000			21,000
Loss before income taxes	$	(421,000	)	$	(4,678,000	)

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9.    ACCUMULATED OTHER COMPREHENSIVE LOSS

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

	Three months ended   December 31,
	2019			2018
Foreign currency translation:
Beginning accumulated foreign currency translation	$	691,000		$	925,000
Change in cumulative translation adjustment before reclassifications	5,000			(413,000		)
Income taxes	—			—
Net current period other comprehensive income (loss)	5,000			(413,000		)
Ending accumulated foreign currency translation	696,000			512,000
Retirement plans:
Beginning accumulated retirement plans benefit cost	(3,608,000		)	(1,439,000		)
Amortization of net actuarial loss and prior service cost	60,000			17,000
Net actuarial gains arising during the period	2,579,000			—
Income taxes	—			—
Net current period other comprehensive income	2,639,000			17,000
Ending accumulated retirement plans benefit cost	(969,000		)	(1,422,000		)
Accumulated other comprehensive loss, net of taxes	$	(273,000	)	$	(910,000	)

The amortization of accumulated other comprehensive loss components for the retirement plans are included in the computation of net periodic benefit cost (income) which is a component of “General and administrative” expenses on the accompanying Condensed Consolidated Statements of Operations (see Note 5 for additional details).

10.    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

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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.

11.    LEASES

On October 1, 2019, the Company adopted ASU No. 2016-02, “Leases (Topic 842),” using the modified retrospective transition approach and applied the new standard to leases in place as of the adoption date. Results for reporting periods prior to October 1, 2019 have not been adjusted. The Company elected the package of practical expedients allowed upon adoption of Accounting Standards Codification (“ASC”) 842 which, among other things, allowed us to (1) not reassess whether any expired or existing contracts contain leases, (2) carry forward the historical lease classification, and (3) not have to reassess any initial direct cost of any expired or existing leases.

As a result of the adoption of ASC 842, the Company recorded operating lease right-of-use (“ROU”) assets of $2,589,000 and corresponding total operating lease liabilities of $2,589,000 in the Condensed Consolidated Balance Sheets as of October 1, 2019. There was no impact to retained earnings or the Condensed Consolidated Statements of Operations.

The Company’s ROU assets and lease liabilities primarily relate to non-cancelable operating leases for our Canadian office space, our contract drilling maintenance and storage yard, and our leasehold land interest for Lot 4C held by Kaupulehu Developments. Management determines if a contract is or contains a lease at inception of the contract or modification of the contract. A contract is or contains a lease if the contract conveys the right to control the use of the asset for a period in exchange for consideration.

Operating lease ROU assets and liabilities are recognized based on the present value of future minimum lease payments over the expected lease term at commencement date. The Company’s leases do not provide a readily determinable implicit rate; therefore, management uses the Company’s incremental borrowing rate to discount lease payments based on information available at lease commencement. Our lease terms may include options to extend or terminate the lease when it is reasonably certain we will exercise that potion. Lease expense for minimum lease payments is recognized on a straight-line basis over the expected lease terms.

The Company has lease agreements with lease and non-lease components and the non-lease components are excluded in the calculation of the ROU asset and lease liability and expensed as incurred. None of the Company’s lease agreements contain material residual value guarantees or material restrictions or covenants.

A ROU asset and corresponding lease liability is not recorded for leases with an initial term of 12 months or less (short-term leases) as the Company recognizes lease expense for these leases as incurred over the lease term.

In the quarter ended December 31, 2019, Barnwell initiated discussions with a potential buyer of Barnwell's leasehold interest in its three-quarter of an acre contract drilling segment maintenance and storage yard in Honolulu, Hawaii. The lease has terms that are favorable as compared to market lease rates for comparable properties in the area. The ROU asset related to this lease has been classified as “Operating lease right-of-use asset held for sale” and the related lease liability is included in the “Operating lease liability held for sale” in the Condensed Consolidated Balance Sheet as of December 31, 2019.

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Leases recorded on the balance sheet consist of the following:

		December 31, 2019
Assets:
	Operating lease right-of-use asset held for sale	$	2,226,000
	Operating lease right-of-use assets	331,000
	Total right-of-use assets	$	2,557,000
Liabilities:
	Operating lease liability held for sale	$	2,441,000
	Current portion of operating lease liabilities	108,000
	Operating lease liabilities	230,000
	Total lease liabilities	$	2,779,000

The components of lease expenses are as follows:

	Three months ended December 31, 2019
Operating lease cost	$	102,000
Short-term lease cost	17,000
Total lease cost	$	119,000

Supplemental information related to leases is as follows:

		December 31, 2019
Cash paid for amounts included in the measurement of lease liabilities:
	Operating cash flows from operating leases	$	64,000
Operating leases:
	Weighted-average remaining lease term (in years)	24.6
	Weighted-average discount rate	6.77%

The remaining lease payments for our operating leases as of December 31, 2019, are as follows:

Fiscal year ending:
Remainder of 2020	$	194,000
2021	258,000
2022	202,000
2023	193,000
2024	193,000
Thereafter through 2047	5,574,000
Total lease payments	6,614,000
Less: amounts representing interest	(3,835,000		)
Present value of lease liabilities	$	2,779,000

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12.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.

During the quarter ended December 31, 2019, the Company experienced the failure of a hole opener which broke apart leaving pieces in the bottom of the well.  If the Company is unable to overcome this impediment to completing the well it may have to abandon the well and drill a new well for which the potential exposure estimated to be incurred would range from $1,400,000 to $1,600,000.  Efforts to remove the items from the well are currently ongoing. No contingent liability has been recorded at December 31, 2019 as the likelihood of the Company needing to abandon the well and drill a new well is not probable.

In the year ended September 30, 2019, two of the water wells drilled by the contract drilling segment for one customer were determined to not meet the contract specifications for plumbness. Management believes the degrees of deviation for both wells are not impactful to the performance of the submersible pumps that will be installed in those wells. Accordingly, no contingent liability has been recorded at December 31, 2019 as the likelihood of any impact is not probable. However, per the contracts, both of which are with one customer, a failure to meet the contract plumbness specification allows the customer to demand the drilling of a new well at no cost to the customer as well as potential liquidated damages. If the customer makes such a demand, the potential exposure for both wells combined is estimated to range from $2,000,000 to $3,000,000. Negotiations with the customer are currently ongoing.

13.    INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

	Three months ended   December 31,
	2019		2018
Supplemental disclosure of cash flow information:
Cash paid (received) during the year for:
Income taxes refunded, net	$	—	$	(866,000	)

Capital expenditure accruals related to oil and natural gas exploration and development increased $1,661,000 during the three months ended December 31, 2019 and decreased $66,000 during the three months ended December 31, 2018. Additionally, capital expenditure accruals related to oil and natural gas asset retirement obligations increased $323,000 and $146,000 during the three months ended December 31, 2019 and 2018, respectively.

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14.    RELATED PARTY TRANSACTIONS

Kaupulehu Developments is entitled to receive payments from the sales of lots and/or residential units by KD I and KD II. Through March 6, 2019, Kaupulehu Developments was also entitled to receive 50% of any future distributions otherwise payable from KD II to its members up to $8,000,000, of which $3,500,000 was received. KD I and KD II are part of the Kukio Resort Land Development Partnerships in which Barnwell holds indirect 19.6% and 10.8% non-controlling ownership interests, respectively, accounted for under the equity method of investment. The percentage of sales payments and percentage of distribution payments are part of transactions which took place in 2004 and 2006 where Kaupulehu Developments sold its leasehold interests in Increment I and Increment II to KD I's and KD II's predecessors in interest, respectively, which was prior to Barnwell’s affiliation with KD I and KD II which commenced on November 27, 2013, the acquisition date of our ownership interest in the Kukio Resort Land Development Partnerships. Changes to the arrangement above, effective March 7, 2019, are discussed in Note 3.

No lots were sold during the three months ended December 31, 2019. During the three months ended December 31, 2018, Barnwell received $165,000 in percentage of sales payments from KD I from the sale of one lot within Phase II of Increment I.

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ITEM 2.    MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Cautionary Statement Relevant to Forward-Looking Information

For the Purpose Of “Safe Harbor” Provisions Of The

Private Securities Litigation Reform Act of 1995

This Form 10-Q, and the documents incorporated herein by reference, contain “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995 ("PSLRA"). A forward-looking statement is one which is based on current expectations of future events or conditions and does not relate to historical or current facts. These statements include various estimates, forecasts, projections of Barnwell’s future performance, statements of Barnwell’s plans and objectives, and other similar statements. All such statements we make are forward-looking statements made under the safe harbor of the PSLRA, except to the extent such statements relate to the operations of a partnership or limited liability company. Forward-looking statements include phrases such as “expects,” “anticipates,” “intends,” “plans,” “believes,” “predicts,” “estimates,” “assumes,” “projects,” “may,” “will,” “will be,” “should,” or similar expressions. Although Barnwell believes that its current expectations are based on reasonable assumptions, it cannot assure that the expectations contained in such forward-looking statements will be achieved. Forward-looking statements involve risks, uncertainties and assumptions which could cause actual results to differ materially from those contained in such statements. The risks, uncertainties and other factors that might cause actual results to differ materially from Barnwell’s expectations are set forth in the “Forward-Looking Statements” and “Risk Factors” sections of Barnwell’s Annual Report on Form 10-K for the year ended September 30, 2019. Investors should not place undue reliance on these forward-looking statements, as they speak only as of the date of filing of this Form 10-Q, and Barnwell expressly disclaims any obligation or undertaking to publicly release any updates or revisions to any forward-looking statements contained herein.

Critical Accounting Policies and Estimates

Management has determined that our most critical accounting policies and estimates are those related to the full-cost ceiling calculation and depletion of our oil and natural gas properties, the estimation of our contract drilling segment's revenues and expenses, and the calculation of our income taxes, all of which are discussed in our Annual Report on Form 10-K, as amended by our Form 10-K/A Amendment No. 1 and Form 10-K/A Amendment No. 2, for the fiscal year ended September 30, 2019. There have been no significant changes to these critical accounting policies and estimates during the three months ended December 31, 2019. We continue to monitor our accounting policies to ensure proper application of current rules and regulations.

Current Outlook

Our ability to sustain our business depends on sufficient oil and natural gas operating cash flows, which are highly sensitive to potentially volatile oil and natural gas prices, sufficient contract drilling operating cash flows, which are subject to potentially large changes in demand, sufficient future land investment segment proceeds and distributions from the Kukio Resort Land Development Partnerships, the timing of which are both highly uncertain and not within Barnwell’s control, and our ability to fund our needed oil and natural gas capital expenditures and the level of success of such capital expenditures, as well as our ability to fund oil and natural gas asset retirement obligations and ongoing operating and general and administrative expenses.

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Management believes our current cash balances and estimated future operating cash flows will be sufficient to fund the Company's estimated cash outflows for the next 12 months from the date of this report. The estimated future operating cash flows are based on management's probable estimates and assumes oil and natural gas prices do not decline and contract drilling jobs do not encounter unforeseen difficulties and are completed without unforeseen delays or stoppages. The estimated future operating cash flows are also based on management's estimates of operating cash flows from the drilling of oil and natural gas wells to convert proved undeveloped reserves to proved producing reserves, as well as the cash outflows required for the drilling of such wells. If actual results are less than management's estimates and if we are then unable to obtain financing or if the financing is not obtained in sufficient time or is not of sufficient magnitude to sustain our business, or if unforeseen circumstances arise that impair our ability to sustain our business, the Company will need to consider further sales of our assets or alternative strategies, or we may be forced to wind down our operations, either through liquidation or bankruptcy, and we may not be able to continue as a going concern beyond February 2021.

Impact of Recently Issued Accounting Standards on Future Filings

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

In August 2018, the FASB issued ASU No. 2018-13, “Fair Value Measurement: Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement,” which provides changes to certain fair value disclosure requirements. This ASU is effective for annual reporting periods beginning after December 15, 2019 and interim periods within those annual periods, with early adoption permitted. The adoption of this update is not expected to have a material impact on Barnwell's consolidated financial statements.

In August 2018, the FASB issued ASU No. 2018-14, “Compensation - Retirement Benefits-Defined Benefit Plans - General: Disclosure Framework-Changes to the Disclosure Requirements for Defined Benefit Plans,” which provides changes to certain pension and postretirement plan disclosures. This ASU is effective for annual reporting periods ending after December 15, 2020, with early adoption permitted. The adoption of this update is not expected to have a material impact on Barnwell's consolidated financial statements.

In October 2018, the FASB issued ASU No. 2018-17, “Consolidation: Targeted Improvements to Related Party Guidance for Variable Interest Entities,” which modifies the guidance related to indirect interests held through related parties under common control for determining whether fees paid to decision makers and service providers are variable interest. This ASU is effective for annual reporting periods beginning after December 15, 2019 and interim periods within those annual periods, with early adoption permitted. The adoption of this update is not expected to have a material impact on Barnwell's consolidated financial statements.

In December 2019, the FASB issued ASU No. 2019-12, “Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes,” which enhances and simplifies various aspects of the income tax accounting

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guidance in ASC 740. This ASU is effective for annual reporting periods beginning after December 15, 2020 and interim periods within those annual periods, with early adoption permitted. The adoption of this update is not expected to have a material impact on Barnwell's consolidated financial statements.

Overview

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

Oil and Natural Gas Segment

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

Land Investment Segment

Through Barnwell’s 77.6% interest in Kaupulehu Developments, a Hawaii general partnership, 75% interest in KD Kona 2013 LLLP, a Hawaii limited liability limited partnership, and 34.45% non-controlling interest in KKM Makai, LLLP, a Hawaii limited liability limited partnership, the Company’s land investment interests include the following:

• The right to receive percentage of sales payments from KD I resulting from the sale of single-family residential lots by KD I, within Increment I of the approximately 870 acres of the Kaupulehu Lot 4A area located in the North Kona District of the island of Hawaii. Kaupulehu Developments is entitled to receive payments from KD I based on the following percentages of the gross receipts from KD I’s sales at Increment I: 10% of such aggregate gross proceeds greater than $100,000,000 up to $300,000,000; and 14% of such aggregate gross proceeds in excess of $300,000,000. Increment I is an area zoned for approximately 80 single-family lots, of which 19 remained to be sold at December 31, 2019, and a beach club on the portion of the property bordering the Pacific Ocean, and is partially developed.

• Prior to March 7, 2019, the right to receive percentage of sales payments from KD II resulting from the sale of lots and/or residential units by KD II, within Increment II of Kaupulehu Lot 4A. Increment II is the remaining portion of the approximately 870-acre property and is zoned for single-family and multi-family residential units and a golf course and clubhouse. Kaupulehu Developments was entitled to receive payments from KD II based on a percentage of the gross receipts from KD II’s sales ranging from 8% to 10% of the price of improved or unimproved lots or 2.60% to 3.25% of the price of units constructed on a lot, to be determined in the future depending upon a number of variables, including whether the lots are sold prior to improvement. Kaupulehu Developments was also entitled to receive 50% of any future distributions otherwise payable from KD II to it members up to $8,000,000, of which $3,500,000 had been received. Two ocean front parcels approximately two to three acres in size fronting the ocean were developed and sold within Increment II by KD II, and Kaupulehu Developments received percentage of sales payments from those sales. The remaining acreage within Increment II is not yet developed. In February 2019, KD II was granted a 20-year time extension of the allowed zoning for the project that would have otherwise expired in April 2019.

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As of March 7, 2019, with the admission of Replay as a new development partner of Increment II, the ownership interests in KD II of KDK and Replay were changed to 55% and 45%, respectively. Additionally, Kaupulehu Developments has the 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, in compensation for the agreement of these parties to admit the new development partner for Increment II.

• Prior to March 7, 2019, we had an indirect 19.6% non-controlling ownership interest in KD Kukio Resorts, KD Maniniowali and KDK. As of March 7, 2019, with the admission of Replay as a new development partner of Increment II, we now have a 10.8% non-controlling ownership interest in KD II through KDK. Our indirect interest in the other entities remain unchanged. These entities own certain real estate and development rights interests in the Kukio, Maniniowali and Kaupulehu portions of Kukio Resort, a private residential community on the Kona coast of the island of Hawaii, as well as Kukio Resort’s real estate sales office operations. KDK was the developer of Kaupulehu Lot 4A Increments I and II. The partnerships derive income from the sale of residential parcels as well as from commission on real estate sales by the real estate sales office. KD I has engaged Replay as a consultant to assist with the sales and marketing strategy of Increment I. Replay does not have an ownership interest in KD I.

• Approximately 1,000 acres of vacant leasehold land zoned conservation in the Kaupulehu Lot 4C area located adjacent to the 870-acre Lot 4A described above, which currently has no development potential without both a development agreement with the lessor and zoning reclassification.

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.

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Results of Operations

Summary

The net loss attributable to Barnwell for the three months ended December 31, 2019 totaled $414,000, a $4,186,000increase in operating results from a net loss of $4,600,000 for the three months ended December 31, 2018. The following factors affected the results of operations for the three months ended December 31, 2019 as compared to the same period in the prior year:

• A $3,346,000 improvement in oil and natural gas segment operating results, before income taxes, due primarily to a ceiling test impairment of $2,170,000 in the prior period, whereas there was no such ceiling test impairment in the current period, and a 90% increase in oil prices; and

• A $957,000 improvement in contract drilling segment operating results, before income taxes, primarily resulting from increased activity attributable to a significant well drilling contract.

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 remained unchanged in the three months ended December 31, 2019 as compared to the same period in the prior year, and the exchange rate of the Canadian dollar to the U.S. dollar increased2% at December 31, 2019 as compared to September 30, 2019. Accordingly, the assets, liabilities, stockholders’ equity and revenues and expenses of Barnwell’s subsidiaries operating in Canada have been adjusted to reflect the change in the exchange rates. Barnwell’s Canadian dollar assets are greater than its Canadian dollar liabilities; therefore, increases or decreases in the value of the Canadian dollar to the U.S. dollar generate other comprehensive income or loss, respectively. Other comprehensive income and losses are not included in net loss. Other comprehensive income due to foreign currency translation adjustments, net of taxes, for the three months ended December 31, 2019 was $5,000, a $418,000 change from other comprehensive loss due to foreign currency translation adjustments, net of taxes, of $413,000 for the same period in the prior year. There were no taxes on other comprehensive income (loss) due to foreign currency translation adjustments in the three months ended December 31, 2019 and 2018 due to a full valuation allowance on the related deferred tax assets.

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Oil and natural gas

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

	Average Price Per Unit
	Three months ended				Increase
	December 31,				(Decrease)
	2019		2018		$			%
Natural Gas (Mcf)*	$	1.84	$	1.15	$	0.69		60	%
Oil (Bbls)**	$	48.76	$	25.60	$	23.16		90	%
Liquids (Bbls)**	$	18.71	$	34.86	$	(16.15	)	(46	%)

	Net Production
	Three months ended		Increase
	December 31,		(Decrease)
	2019	2018	Units	%
Natural Gas (Mcf)*	168,000	140,000	28,000	20	%
Oil (Bbls)**	35,000	35,000	—	—	%
Liquids (Bbls)**	5,000	5,000	—	—	%

_______________________________________

*            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 $322,000 of operating profit before general and administrative expenses in the three months ended December 31, 2019, an increase in operating results of $3,346,000 as compared to a $3,024,000 operating loss during the same period of the prior year. The operating loss for the prior year period included a $2,170,000 ceiling test impairment, whereas there was no ceiling test impairment in the current year period.

Oil and natural gas revenues increased $909,000 (74%) for the three months ended December 31, 2019, as compared to the same period in the prior year, primarily due to higher oil and natural gas prices as compared to the same period in the prior year. Oil and natural gas operating expenses decreased $124,000 (9%) for the three months ended December 31, 2019, as compared to the prior year period, as the prior year period included repair costs at the Twining property whereas there were no such repair costs in the current year period. Oil and natural gas segment depletion decreased$143,000 (19%) for the three months ended December 31, 2019, as compared to the prior year period, primarily due to a decrease in the depletion rate as a result of ceiling test impairments in the prior fiscal year.

Oil production declines in the current period as compared to the same period of the prior year, due to downtime at certain properties, were offset by increased production from a new well drilled in the Spirit River area which began production in November 2019 and contributed approximately one-quarter of the total oil production for the current year period.

Additionally, a new well was drilled at the Twining area in the current year period. The water infused into the formation during the fracing phase is currently being extracted and the oil cut has been increasing as extraction continues. Production levels for this well are not yet known. As of December 31, 2019, the Company has spent a total of $2,500,000 in capital expenditures on this well. If this well proves to be

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sufficiently successful, the Company plans to drill a second well in the Twining area later this fiscal year, subject to adequate funds and market conditions, to further convert proved undeveloped reserves into proved producing reserves. However, if this well is not sufficiently successful, our cash flows and liquidity will be impaired and our ability to make the required future capital expenditures to convert the Twining area’s proved undeveloped reserves into proved producing reserves, currently estimated to be approximately $12,000,000, could be significantly impaired as well. Such a change in the Company’s estimated business plans would likely result in a significant ceiling test impairment and could result in an inability to sustain our business if asset sales or alternative strategies are not sufficient. While our interests in the Twining area may be sold to generate liquidity as an alternative strategy, the outcome of the newly drilled well will likely have a significant impact on our ability to liquidate our Twining interest or on the amount of the proceeds the Company might receive upon such a liquidation.

Sale of interest in 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. Prior to March 7, 2019, Kaupulehu Developments was also entitled to receive percentage of sales payments from the sales of lots and/or residential units in Increment II by KD II and entitled to receive 50% of any future distributions otherwise payable from KD II to its members up to $8,000,000, of which $3,500,000 was received. Effective March 7, 2019, Kaupulehu Developments' arrangements with regard to payments from the sales of lots and/or residential units in Increment II were changed, as detailed in the Overview section above.

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

	Three months ended   December 31,
	2019		2018
Sale of interest in leasehold land:
Revenues – sale of interest in leasehold land	$	—	$	165,000
Fees - included in general and administrative expenses	—		(20,000		)
Sale of interest in leasehold land, net of fees paid	$	—	$	145,000

No lots were sold during the three months ended December 31, 2019. During the three months ended December 31, 2018, Barnwell received $165,000 in percentage of sales payments from KD I from the sale of one single-family lot within Phase II of Increment I.

As of December 31, 2019, 19 single-family lots, of the 80 lots developed within Increment I, remained to be sold. As discussed in the Overview section above, Replay was admitted as a new development partner of Increment II on March 7, 2019. The Company does not have a controlling interest in Increments I and II, and there is no assurance with regards to the amounts of future sales from Increments I and II.

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Contract drilling

Contract drilling revenues and contract drilling costs increased$1,483,000 (128%) and $498,000 (38%), respectively, for the three months ended December 31, 2019, as compared to the same period in the prior year. The contract drilling segment generated a $747,000 operating profit before general and administrative expenses in the three months ended December 31, 2019, an increase in operating results of $957,000 as compared to a $210,000 operating loss during the same period of the prior year. The increase in operating results was primarily due to a significant well drilling contract for multiple wells that is based on a fixed rate per day or fixed rate per hour, depending upon the activity, as opposed to the Company's typical contracts that are based on a fixed price per lineal foot drilled. Up to three drilling rigs were being used at this job during the current year period with crews working extended hours.

During the quarter ended December 31, 2019, the Company experienced the failure of a hole opener which broke apart leaving pieces in the bottom of the well.  If the Company is unable to overcome this impediment to completing the well it may have to abandon the well and drill a new well for which the potential exposure estimated to be incurred would range from $1,400,000 to $1,600,000.  Efforts to remove the items from the well are currently ongoing. No contingent liability has been recorded at December 31, 2019 as the likelihood of the Company needing to abandon the well and drill a new well is not probable.

In the year ended September 30, 2019, two of the water wells drilled by the contract drilling segment for one customer were determined to not meet the contract specifications for plumbness. Management believes the degrees of deviation for both wells are not impactful to the performance of the submersible pumps that will be installed in those wells. Accordingly, no contingent liability has been recorded at December 31, 2019 as the likelihood of any impact is not probable. However, per the contracts, both of which are with one customer, a failure to meet the contract plumbness specification allows the customer to demand the drilling of a new well at no cost to the customer as well as potential liquidated damages. If the customer makes such a demand, the potential exposure for both wells combined is estimated to range from $2,000,000 to $3,000,000. Negotiations with the customer are currently ongoing.

Contract drilling revenues and costs are not seasonal in nature, but can fluctuate significantly based on the awarding and timing of contracts, which are determined by contract drilling customer demand. There has been a significant decrease in demand for water well drilling contracts in recent years that has generally led to increased competition for available contracts and lower margins on awarded contracts. The Company is unable to predict the near-term and long-term availability of water well drilling and pump installation and repair contracts as a result of this volatility in demand.

Depletion, depreciation, and amortization

Depletion, depreciation, and amortization decreased$114,000 (14%) for the three months ended December 31, 2019, as compared to the same period in the prior year, primarily due to a decrease in the depletion rate as a result of ceiling test impairments in the prior fiscal year as discussed in the “Oil and natural gas” section above.

Impairment of assets

Under the full cost method of accounting, the Company performs quarterly oil and natural gas ceiling test calculations. There was no ceiling test impairment during the three months ended December 31, 2019. There was a ceiling test impairment of $2,170,000 during the three months ended December 31, 2018.

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Changes in the 12-month rolling average first-day-of-the-month prices for oil, natural gas and natural gas liquids prices, the value of reserve additions as compared to the amount of capital expenditures to obtain them, and changes in production rates and estimated levels of reserves, future development costs and the market value of unproved properties, impact the determination of the maximum carrying value of oil and natural gas properties. In addition, the ceiling test is also impacted by any changes in management's quarterly evaluation of the Company's ability to fund the approximately $12,000,000 of future capital expenditures necessary over the next five years to develop the proved undeveloped reserves that are largely in the Twining areas of Alberta, Canada, the value of which is included in the calculation of the ceiling limitation. If facts, circumstances, estimates and assumptions underlying management's assessment of the Company's ability to fund such capital expenditures change such that it is no longer reasonably certain that all of the approximately $12,000,000 of capital expenditures necessary to develop the proved undeveloped reserves can be made, it is likely that we will incur a further ceiling test impairment at that time.

Equity in loss of affiliates

Barnwell’s investment in the Kukio Resort Land Development Partnerships is accounted for using the equity method of accounting. Barnwell was allocated partnership losses of $43,000 and $79,000 during the three months ended December 31, 2019 and 2018, respectively. The change is due to the investee partnerships' improved operating results for the three months ended December 31, 2019, as compared to the same period in the prior year.

Income taxes

Barnwell’s effective consolidated income tax benefit rate for the three months ended December 31, 2019, after adjusting loss before income taxes for non-controlling interests, was nil, as compared to an effective income tax benefit rate of 2% for the three months ended December 31, 2018. 

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 and any amounts estimated to be realizable through tax carryback strategies, are not estimated to have a future benefit as tax credits or deductions. Income from our non-controlling interest in the Kukio Resort Land Development Partnerships is treated as non-unitary for state of Hawaii unitary filing purposes, thus unitary Hawaii losses provide limited sheltering of such non-unitary income.

Net (loss) earnings attributable to non-controlling interests

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

Net loss attributable to non-controlling interests for the three months ended December 31, 2019 totaled $5,000, as compared to net earnings attributable to non-controlling interests of $27,000 for the same period in the prior year. The decrease of $32,000 is primarily due to percentage of sales proceeds received in the prior fiscal year period, whereas there were no percentage of sale proceeds received in the current period.

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Liquidity and Capital Resources

Barnwell’s primary sources of liquidity are cash on hand, cash flow generated by operations, and land investment segment proceeds. At December 31, 2019, Barnwell had $1,232,000 in working capital.

Cash Flows

Cash flows used in operations totaled $1,366,000 for the three months ended December 31, 2019, as compared to $998,000 for the same period in the prior year. This $368,000increase in operating cash flows used was primarily due to changes in working capital, primarily attributed to the timing of receivables and contract liabilities in the current period as compared to the prior year period.

Cash flows used in investing activities totaled $863,000 during the three months ended December 31, 2019, as compared to $1,291,000 of net cash provided by investing activities during the same period of the prior year. This $2,154,000 decrease in investing cash flows was primarily due to $741,000 in maturities of certificates of deposit in the prior fiscal year period as compared to none in the current year period, and an increase of $1,336,000 in oil and natural gas capital expenditures attributed to new wells drilled in the Twining and Spirit River areas in the current period as compared to the prior year period.

There was no cash flows from financing activities during the three months ended December 31, 2019. Net cash flows used in financing activities totaled $107,000 for the three months ended December 31, 2018. The $107,000 change in financing cash flows was due to a decrease in distributions to non-controlling interests in the current year period as compared to the prior year period.

Oil and Natural Gas and Other Capital Expenditures

Barnwell’s oil and natural gas capital expenditures, including accrued capital expenditures and excluding additions and revisions to estimated asset retirement obligations, totaled $3,105,000 for the three months ended December 31, 2019, as compared to $397,000 for the same period in the prior year. In the quarter ended December 31, 2019, Barnwell participated in the drilling of one gross (0.28 net) development well in the Spirit River area that began production in November 2019 and contributed approximately one-quarter of the total oil production for the current year period. Also in the quarter ended December 31, 2019, Barnwell drilled one gross (1.00 net) development well in the Twining area that represents the commencement of development of the Company's proved undeveloped reserves in that area. The water infused into the formation during the fracing phase is currently being extracted and the oil cut has been increasing as extraction continues. Production levels for this well are not yet known.

Barnwell estimates that investments in oil and natural gas properties for fiscal 2020 will range from $3,400,000 to $5,700,000. 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 as well as the determination of the success of our first well drilled at Twining which is still being evaluated.

Oil and Natural Gas Properties Acquisitions and Dispositions

Dispositions

In October 2019, Barnwell entered into a purchase and sale agreement with an independent third party and sold its interests in properties located in the Progress area of Alberta, Canada. The sales price per the agreement was adjusted for customary purchase price adjustments to $594,000 in order to, among other

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things, reflect an economic effective date of October 1, 2019. The final determination of the customary adjustments to the purchase price has not yet been made however it is not expected to result in a material adjustment. The proceeds were credited to the full cost pool, with no gain or loss recognized, as the sale did not result in significant alteration of the relationship between capitalized costs and proved reserves. Progress contributed 3% of oil and natural gas liquids net revenues and 10% of natural gas net revenues in the year ended September 30, 2019.

There were no oil and natural gas property dispositions during the three months ended December 31, 2018. The $633,000 of proceeds from sale of oil and gas properties included in the Consolidated Statement of Cash Flows for the three months ended December 31, 2018 primarily represents the refund of income taxes previously withheld from what otherwise would have been proceeds on the previous years' oil and natural gas property sales.

In January 2020, Barnwell engaged a broker to market its non-core oil and natural gas properties in areas other than at Twining, where Barnwell has directed its development focus. Barnwell intends to use the proceeds from the sales of these properties as an additional source of liquidity for its future capital expenditures to convert proved undeveloped reserves to proved producing reserves in the Twining area, as well as for general corporate needs.

Acquisitions

There were no significant amounts paid for oil and natural gas property acquisitions during the three months ended December 31, 2019.

In the quarter ended December 31, 2018, Barnwell acquired additional working interests in oil and natural gas properties located in the Wood River and Twining areas of Alberta, Canada for cash consideration of $355,000. The purchase prices per the agreements were adjusted for customary purchase price adjustments to reflect the economic activity from the effective date to the closing date. The customary purchase price adjustments were finalized in the quarter ended June 30, 2019 and resulted in an immaterial adjustment.

Other

In the quarter ended December 31, 2019, Barnwell initiated discussions with a potential buyer of Barnwell's leasehold interest in its three-quarter of an acre contract drilling segment maintenance and storage yard in Honolulu, Hawaii. The lease has terms that are favorable as compared to market lease rates for comparable properties in the area. Barnwell intends to use the proceeds from the sale of this lease as an additional source of liquidity for its future cash needs.

NYSE American Continued Listing Standard

On January 13, 2020, the Company received notification (the “Deficiency Letter”) from the NYSE American stating that it is not in compliance with certain NYSE American continued listing standards relating to stockholders’ equity. Specifically, the Deficiency Letter stated that the Company is not in compliance with Section 1003(a)(i) of the NYSE American Company Guide, which requires an issuer to have stockholders’ equity of $2.0 million or more if it reported losses from continuing operations and/or net losses in two of its three most recent fiscal years and Section 1003(a)(ii) of the NYSE American Company Guide, which requires an issuer to have stockholders’ equity of $4.0 million or more if it has reported losses from continuing operations and/or net losses in three of its four most recent fiscal years. The Deficiency Letter

35

noted that the Company had stockholders’ equity of $1.2 million as of September 30, 2019, and has reported losses in fiscal years ended September 30, 2019, September 30, 2018 and September 30, 2016.

The Company was required to submit a plan to the NYSE American by February 12, 2020, advising of actions it has taken or will take to regain compliance with the continued listing standards by July 13, 2021. The Company submitted a plan by the deadline. The NYSE American will review the Company’s plan and make a determination as to whether the Company has made a reasonable demonstration of its ability to regain compliance with Section 1003(a)(i) and Section 1003(a)(ii) by July 13, 2021. The NYSE American notification does not affect our business operations or the current listing of our shares on the NYSE American, and does not represent any change or amendment to our consolidated financial statements or to our 2019 Form 10-K, as amended by Form 10-K/A Amendment No. 1 and Form 10-K/A Amendment No. 2.

ITEM 4.    CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

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

As of December 31, 2019, an evaluation was carried out by Barnwell’s Chief Executive Officer and Chief Financial Officer of the effectiveness of Barnwell’s disclosure controls and procedures. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that Barnwell’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) were effective as of December 31, 2019 to ensure that information required to be disclosed by Barnwell in the reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the Securities Exchange Act of 1934 and the rules thereunder.

Changes in Internal Control Over Financial Reporting

There was no change in Barnwell’s internal control over financial reporting during the quarter ended December 31, 2019 that materially affected, or is reasonably likely to materially affect, Barnwell’s internal control over financial reporting.

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PART II - OTHER INFORMATION

ITEM 1A.    RISK FACTORS

We are updating the risk factor disclosure in “Item 1A. Risk Factors” in our Annual Report on Form 10-K, as amended by our Form 10-K/A Amendment No. 1 and Form 10-K/A Amendment No. 2, for the fiscal year ended September 30, 2019 by adding the discussion below.

Risk Factor Relating to Our Stock

Our failure to maintain continued compliance with the listing requirements of the NYSE American exchange could result in the delisting of our common stock.

Our common stock is listed on the NYSE American. The rules of NYSE American provide that shares be delisted from trading, if, among other things, the Company has failed to comply with its listing agreements relating to stockholders’ equity. For example, the NYSE American may consider suspending trading in, or removing the listing of, securities of an issuer that has stockholders’ equity of less than (i) $6.0 million if such issuer has sustained losses from continuing operations and/or net losses in its five most recent fiscal years, (ii) $4.0 million if such issuer has sustained losses from continuing operations and/or net losses in three of its four most recent fiscal years, and (iii) $2.0 million if such issuer has sustained losses from continuing operations and/or net losses in two of its three most recent fiscal years. As of September 30, 2019, the Company had stockholders’ equity of approximately $1.2 million, and we may not be able to maintain stockholders’ equity in the future. Even if an issuer has a stockholders’ deficit, the NYSE American will not normally consider delisting securities of an issuer that fails to meet these requirements if the issuer has (1) average global market capitalization of at least $50,000,000; or total assets and revenue of $50,000,000 in its last fiscal year, or in two of its last three fiscal years; and (2) the issuer has at least 1,100,000 shares publicly held, a market value of publicly held shares of at least $15,000,000 and 400 round lot shareholders.  As of September 30, 2019, the Company’s total value of market capitalization was approximately $4,304,000. As such, we do not currently meet these exceptions and there is a risk that our common stock may be delisted as a result of our failure to meet the minimum stockholders' equity requirement for continued listing. The NYSE American provides for an 18-month “cure period” for the Company to regain the minimum stockholders’ equity requirement, however if the Company is unable to do so, the NYSE American may delist the Company’s common stock.

On January 13, 2020, the Company received a Deficiency Letter from the NYSE American stating that it is not in compliance with certain NYSE American continued listing standards relating to stockholders’ equity. Specifically, the Deficiency Letter stated that the Company is not in compliance with Section 1003(a)(i) of the NYSE American Company Guide, which requires an issuer to have stockholders’ equity of $2.0 million or more if it reported losses from continuing operations and/or net losses in two of its three most recent fiscal years and Section 1003(a)(ii) of the NYSE American Company Guide, which requires an issuer to have stockholders’ equity of $4.0 million or more if it has reported losses from continuing operations and/or net losses in three of its four most recent fiscal years. The Deficiency Letter noted that the Company had stockholders’ equity of $1.2 million as of September 30, 2019, and has reported losses in fiscal years ended September 30, 2019, September 30, 2018 and September 30, 2016.

The Company was required to submit a plan to the NYSE American by February 12, 2020, advising of actions it has taken or will take to regain compliance with the continued listing standards by July 13, 2021. The Company submitted a plan by the deadline. The NYSE American will review the Company’s plan and make a determination as to whether the Company has made a reasonable demonstration of its ability to regain

37

compliance with Section 1003(a)(i) and Section 1003(a)(ii) by July 13, 2021; provided, however, even if the NYSE American accepts the plan, if the Company is not in compliance with the continued listing standards by July 31, 2021 or if the Company does not make progress consistent with the plan during the plan period, the NYSE American will initiate delisting proceedings as it deems appropriate.

38

ITEM 6.    EXHIBITS

Exhibit Number	Description
31.1	Certification of Chief Executive Officer Pursuant To Section 302 of the Sarbanes-Oxley Act of 2002
31.2	Certification of Chief Financial Officer Pursuant To Section 302 of the Sarbanes-Oxley Act of 2002
32	Certification Pursuant To Section 906 of the Sarbanes-Oxley Act of 2002
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema Document
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document
101.LAB	XBRL Taxonomy Extension Label Linkbase Document
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document

39

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 12, 2020	/s/ Russell M. Gifford
		Russell M. Gifford
		Chief Financial Officer,
		Executive Vice President,
		Treasurer and Secretary

40

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	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema Document
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document
101.LAB	XBRL Taxonomy Extension Label Linkbase Document
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document

41

EX-31.1

Exhibit No. 31.1

Certifications

I, Alexander C. Kinzler, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Barnwell Industries, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;    

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	February 12, 2020	/s/ Alexander C. Kinzler
		Alexander C. Kinzler
		President, Chief Executive Officer, Chief Operating Officer, General Counsel

EX-31.2

Exhibit No. 31.2

Certifications

I, Russell M. Gifford, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Barnwell Industries, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;    

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	February 12, 2020	/s/ Russell M. Gifford
		Russell M. Gifford
		Executive Vice President, Chief Financial Officer

EX-32

Exhibit No. 32

Barnwell Industries, Inc.

Certification Pursuant to

Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the Quarterly Report of Barnwell Industries, Inc. (the “Company”) on Form 10-Q for the quarter ended December 31, 2019 as filed with the Securities and Exchange Commission (the “Report”), each of the undersigned officers of the Company does hereby certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to his knowledge:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated:	February 12, 2020	/s/ Alexander C. Kinzler
		Name: Alexander C. Kinzler
		Title: President, Chief Executive Officer, Chief Operating Officer, General Counsel
Dated:	February 12, 2020	/s/ Russell M. Gifford
		Name: Russell M. Gifford
		Title: Executive Vice President, Chief Financial Officer

The foregoing certification is being furnished solely pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code) and is not being filed as part of the Form 10-Q or as a separate disclosure document.

A signed original of the written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

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LEASES (Tables)

3 Months Ended

Dec. 31, 2019

Leases [Abstract]

Lease assets and liabilities

Leases recorded on the balance sheet consist of the following:

		December 31, 2019
Assets:
	Operating lease right-of-use asset held for sale	$	2,226,000
	Operating lease right-of-use assets	331,000
	Total right-of-use assets	$	2,557,000
Liabilities:
	Operating lease liability held for sale	$	2,441,000
	Current portion of operating lease liabilities	108,000
	Operating lease liabilities	230,000
	Total lease liabilities	$	2,779,000

Lease costs

The components of lease expenses are as follows:

	Three months ended December 31, 2019
Operating lease cost	$	102,000
Short-term lease cost	17,000
Total lease cost	$	119,000

Supplemental lease information

Supplemental information related to leases is as follows:

		December 31, 2019
Cash paid for amounts included in the measurement of lease liabilities:
	Operating cash flows from operating leases	$	64,000
Operating leases:
	Weighted-average remaining lease term (in years)	24.6
	Weighted-average discount rate	6.77%

Operating lease maturity schedule

The remaining lease payments for our operating leases as of December 31, 2019, are as follows:

Fiscal year ending:
Remainder of 2020	$	194,000
2021	258,000
2022	202,000
2023	193,000
2024	193,000
Thereafter through 2047	5,574,000
Total lease payments	6,614,000
Less: amounts representing interest	(3,835,000		)
Present value of lease liabilities	$	2,779,000

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INVESTMENTS - SUMMARY OF INVESTMENTS (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Sep. 30, 2019
Investment Holdings [Line Items]
Total non-current investments	$ 937	$ 980
Investment in Kukio Resort Land Development Partnerships
Investment Holdings [Line Items]
Total non-current investments	887	930
Investment in leasehold land interest – Lot 4C
Investment Holdings [Line Items]
Total non-current investments	$ 50	$ 50

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FAIR VALUE MEASUREMENTS

3 Months Ended

Dec. 31, 2019

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

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.

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INCOME TAXES

3 Months Ended

Dec. 31, 2019

Income Tax Disclosure [Abstract]

INCOME TAXES

INCOME TAXES

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

	Three months ended   December 31,
	2019			2018
United States	$	(147,000	)	$	(1,124,000	)
Canada	(269,000		)	(3,581,000		)
	$	(416,000	)	$	(4,705,000	)

The components of the income tax benefit are as follows:

	Three months ended   December 31,
	2019			2018
Current	$	7,000		$	(33,000	)
Deferred	(9,000		)	(72,000		)
	$	(2,000	)	$	(105,000	)

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 and any amounts estimated to be realizable through tax carryback strategies, 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.

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LOSS PER COMMON SHARE

3 Months Ended

Dec. 31, 2019

Earnings Per Share [Abstract]

LOSS PER COMMON SHARE

LOSS PER COMMON SHARE

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

Options to purchase 60,000 and 318,750 shares of common stock were excluded from the computation of diluted shares for the three months ended December 31, 2019 and 2018, respectively, as their inclusion would have been anti-dilutive.

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

	Three months ended December 31, 2019
	Net Loss (Numerator)			Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(414,000	)	8,277,160	$	(0.05	)
Effect of dilutive securities -
common stock options	—			—
Diluted net loss per share	$	(414,000	)	8,277,160	$	(0.05	)

	Three months ended December 31, 2018
	Net Loss (Numerator)			Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(4,600,000	)	8,277,160	$	(0.56	)
Effect of dilutive securities -
common stock options	—			—
Diluted net loss per share	$	(4,600,000	)	8,277,160	$	(0.56	)

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RELATED PARTY TRANSACTIONS (Details) $ in Thousands	3 Months Ended		5 Months Ended
	Dec. 31, 2019 USD ($)	Dec. 31, 2018 USD ($) lot	Mar. 06, 2019 USD ($)
Kaupulehu Developments
Related party transactions
Revenues - sale of interest in leasehold land	$ 0	$ 165
Kaupulehu Developments | KD Kaupulehu LLLP Increment II
Related party transactions
Percent of Increment II distributions			50.00%
Gain contingency, unrecorded amount			$ 8,000
50% of Increment II distributions received			$ 3,500
Kaupulehu Developments | KD Kaupulehu, LLLP | Investment in land development partnerships
Related party transactions
Revenues - sale of interest in leasehold land		$ 165
Kaupulehu Developments | KD Kaupulehu, LLLP | Investment in land development partnerships | Increment I
Related party transactions
Number of single family lots sold | lot		1
KD Acquisition, LLLP | Investment in land development partnerships
Related party transactions
Ownership interest acquired	19.60%
KD Acquisition II, LP | Barnwell Industries Inc | Investment in land development partnerships
Related party transactions
Ownership interest acquired	10.80%

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CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Revenues:
Revenues	$ 4,850	$ 2,595
Costs and expenses:
General and administrative	1,496	1,548
Depletion, depreciation, and amortization	705	819
Impairment of assets	0	2,170
Interest expense	0	4
Total costs and expenses	5,228	7,194
Loss before equity in loss of affiliates and income taxes	(378)	(4,599)
Equity in loss of affiliates	(43)	(79)
Loss before income taxes	(421)	(4,678)
Income tax benefit	(2)	(105)
Net loss	(419)	(4,573)
Less: Net (loss) earnings attributable to non-controlling interests	(5)	27
Net loss attributable to Barnwell Industries, Inc.	$ (414)	$ (4,600)
Basic and diluted net loss per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share)	$ (0.05)	$ (0.56)
Weighted-average number of common shares outstanding:
Basic and diluted (in shares)	8,277	8,277
Oil and natural gas
Revenues:
Revenues	$ 2,141	$ 1,232
Costs and expenses:
Costs and expenses	1,213	1,337
Depletion, depreciation, and amortization	606	749
Impairment of assets	0	2,170
Contract drilling
Revenues:
Revenues	2,646	1,163
Costs and expenses:
Costs and expenses	1,814	1,316
Depletion, depreciation, and amortization	85	57
Land investment
Revenues:
Revenues	0	165
Gas processing and other
Revenues:
Revenues	63	35
Costs and expenses:
Depletion, depreciation, and amortization	$ 14	$ 13

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LEASES - SUPPLEMENTAL LEASE INFORMATION (Details) $ in Thousands	3 Months Ended
	Dec. 31, 2019 USD ($)
Leases [Abstract]
Operating cash flows from operating leases	$ 64
Operating lease, weighted average remaining lease term (in years)	24 years 7 months
Operating lease, weighted average discount rate	6.77%

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CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Parenthetical) - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Statement of Stockholders' Equity [Abstract]
Foreign currency translation adjustments, taxes	$ 0	$ 0
Amortization of accumulated other comprehensive loss into net periodic benefit cost, taxes	0	0
Net actuarial gains arising during the period, taxes	0	0
Curtailment gain, taxes	$ 0	$ 0

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OIL AND NATURAL GAS PROPERTIES (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Oil and Natural Gas Properties [Line Items]
Proceeds from sale of oil and natural gas assets	$ 594	$ 633
Impairment of assets	0	2,170
Future capital expenditure, development of proved undeveloped reserves, over next five yearsp	12,000
Wood River and Twining
Oil and Natural Gas Properties [Line Items]
Acquisition costs		$ 355
Barnwell Industries Inc | Progress
Oil and Natural Gas Properties [Line Items]
Proceeds from sale of oil and natural gas assets	$ 594

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REVENUE FROM CONTRACTS WITH CUSTOMERS - CONTRACT BALANCES (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Sep. 30, 2019
Revenue from Contract with Customer [Abstract]
Accounts receivables from contracts with customers	$ 2,862	$ 1,322
Contract assets	551	344
Contract liabilities	$ 1,043	$ 1,633

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RETIREMENT PLANS (Tables)

3 Months Ended

Dec. 31, 2019

Retirement Benefits [Abstract]

Schedule of components of net periodic benefit cost (income)

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

	Pension Plan						SERP						Postretirement Medical
	Three months ended December 31,
	2019			2018			2019			2018			2019		2018
Service cost	$	50,000		$	50,000		$	3,000		$	9,000		$	—	$	—
Interest cost	83,000			93,000			18,000			21,000			20,000		25,000
Expected return on plan assets	(163,000		)	(161,000		)	—			—			—		—
Amortization of prior service cost (credit)	1,000			1,000			(1,000		)	(1,000		)	—		—
Amortization of net actuarial loss	35,000			3,000			5,000			1,000			20,000		13,000
Curtailment cost (income)	53,000			—			(53,000		)	—			—		—
Net periodic benefit cost (income)	$	59,000		$	(14,000	)	$	(28,000	)	$	30,000		$	40,000	$	38,000

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RELATED PARTY TRANSACTIONS

3 Months Ended

Dec. 31, 2019

Related Party Transactions [Abstract]

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS

Kaupulehu Developments is entitled to receive payments from the sales of lots and/or residential units by KD I and KD II. Through March 6, 2019, Kaupulehu Developments was also entitled to receive 50% of any future distributions otherwise payable from KD II to its members up to $8,000,000, of which $3,500,000 was received. KD I and KD II are part of the Kukio Resort Land Development Partnerships in which Barnwell holds indirect 19.6% and 10.8% non-controlling ownership interests, respectively, accounted for under the equity method of investment. The percentage of sales payments and percentage of distribution payments are part of transactions which took place in 2004 and 2006 where Kaupulehu Developments sold its leasehold interests in Increment I and Increment II to KD I's and KD II's predecessors in interest, respectively, which was prior to Barnwell’s affiliation with KD I and KD II which commenced on November 27, 2013, the acquisition date of our ownership interest in the Kukio Resort Land Development Partnerships. Changes to the arrangement above, effective March 7, 2019, are discussed in Note 3.

No lots were sold during the three months ended December 31, 2019. During the three months ended December 31, 2018, Barnwell received $165,000 in percentage of sales payments from KD I from the sale of one lot within Phase II of Increment I.

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RETIREMENT PLANS (Details) - USD ($)	1 Months Ended	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2019	Dec. 31, 2018
Retirement plans
Curtailment gain, net of taxes of $0		$ 1,699,000	$ 0
Other disclosures
Net actuarial gains arising during the period		880,000	0
Reduction in unrecognized benefit costs previously included in AOCL		(60,000)	(17,000)
Pension Plan
Net periodic benefit cost:
Service cost		50,000	50,000
Interest cost		83,000	93,000
Expected return on plan assets		(163,000)	(161,000)
Amortization of prior service cost (credit)		1,000	1,000
Amortization of net actuarial loss		35,000	3,000
Curtailment cost (income)		53,000	0
Net periodic benefit cost (income)		59,000	(14,000)
Other disclosures
Estimated future Pension Plan contributions	$ 0	0
SERP
Net periodic benefit cost:
Service cost		3,000	9,000
Interest cost		18,000	21,000
Expected return on plan assets		0	0
Amortization of prior service cost (credit)		(1,000)	(1,000)
Amortization of net actuarial loss		5,000	1,000
Curtailment cost (income)		(53,000)	0
Net periodic benefit cost (income)		(28,000)	30,000
Postretirement Medical
Net periodic benefit cost:
Service cost		0	0
Interest cost		20,000	25,000
Expected return on plan assets		0	0
Amortization of prior service cost (credit)		0	0
Amortization of net actuarial loss		20,000	13,000
Curtailment cost (income)		0	0
Net periodic benefit cost (income)		40,000	$ 38,000
Pension Plan and SERP
Retirement plans
Curtailment gain, net of taxes of $0	1,699,000
Other disclosures
Net actuarial gains arising during the period		$ 880,000
Reduction in unrecognized benefit costs previously included in AOCL	$ 1,699,000

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REVENUE FROM CONTRACTS WITH CUSTOMERS - NARRATIVE (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Sep. 30, 2019
Disaggregation of Revenue [Line Items]
Contract with customer, liability, current	$ 1,043		$ 1,633
Contract with customer, liability, revenue recognized	1,480	$ 21
Revenue, remaining performance obligation (backlog)	$ 2,556		$ 2,866
Percentage anticipated to be recognized in next 12 months	78.00%		79.00%
Capitalized contract cost net, preconstruction	$ 258		$ 296
Minimum
Disaggregation of Revenue [Line Items]
Contract receivable retainage percentage	5.00%
Maximum
Disaggregation of Revenue [Line Items]
Contract receivable retainage percentage	10.00%

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INVESTMENTS (Tables)

3 Months Ended

Dec. 31, 2019

Investments, All Other Investments [Abstract]

Summary of investments

A summary of Barnwell’s non-current investments is as follows:

	December 31, 2019		September 30, 2019
Investment in Kukio Resort Land Development Partnerships	$	887,000	$	930,000
Investment in leasehold land interest – Lot 4C	50,000		50,000
Total non-current investments	$	937,000	$	980,000

Summarized financial information for the land development partnerships

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

	Three months ended   December 31,
	2019			2018
Revenue	$	1,766,000		$	1,948,000
Gross profit	$	796,000		$	646,000
Net loss	$	(168,000	)	$	(158,000	)

Summary of increment I and increment II percentage of sales payment revenues received

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

	Three months ended   December 31,
	2019		2018
Sale of interest in leasehold land:
Revenues - sale of interest in leasehold land	$	—	$	165,000
Fees - included in general and administrative expenses	—		(20,000		)
Sale of interest in leasehold land, net of fees paid	$	—	$	145,000

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INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

3 Months Ended

Dec. 31, 2019

Supplemental Cash Flow Elements [Abstract]

INFORMATION RELATING TO THE CONSOLIDATED STATEMENTS OF CASH FLOWS

INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

	Three months ended   December 31,
	2019		2018
Supplemental disclosure of cash flow information:
Cash paid (received) during the year for:
Income taxes refunded, net	$	—	$	(866,000	)

Capital expenditure accruals related to oil and natural gas exploration and development increased $1,661,000 during the three months ended December 31, 2019 and decreased $66,000 during the three months ended December 31, 2018. Additionally, capital expenditure accruals related to oil and natural gas asset retirement obligations increased $323,000 and $146,000 during the three months ended December 31, 2019 and 2018, respectively.

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INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Tables)

3 Months Ended

Dec. 31, 2019

Supplemental Cash Flow Elements [Abstract]

Schedule of supplemental cash flow information

	Three months ended   December 31,
	2019		2018
Supplemental disclosure of cash flow information:
Cash paid (received) during the year for:
Income taxes refunded, net	$	—	$	(866,000	)

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INVESTMENTS - INVESTMENT IN KUKIO RESORT LAND DEVELOPMENT PARTNERSHIP (Details) $ in Thousands		3 Months Ended
	Nov. 27, 2013 USD ($) partnership	Dec. 31, 2019 USD ($) lot	Dec. 31, 2018 USD ($)	Mar. 07, 2019
Investment Holdings [Line Items]
Equity in loss of affiliates		$ (43)	$ (79)
Investment in land development partnerships
Investment Holdings [Line Items]
Number of limited liability limited partnerships formed | partnership	2
Cash distribution from equity method investment		0	314
Cumulative cash distributions from Kukio Resort Land Development Partnerships, made to date		45,000
Equity in loss of affiliates		(43)	(79)
Difference between carrying amount and underlying equity		$ 296
Basis difference adjustment			1
KD Kukio Resorts LLLP | Investment in land development partnerships
Investment Holdings [Line Items]
Ownership interest acquired	19.60%
Indirectly Acquired Interest | Investment in land development partnerships
Investment Holdings [Line Items]
Aggregate cost	$ 5,140
KD Acquisition, LLLP | Investment in land development partnerships
Investment Holdings [Line Items]
Ownership interest acquired		19.60%
KD Maniniowali LLLP | Investment in land development partnerships
Investment Holdings [Line Items]
Ownership interest acquired	19.60%
KKM Makai LLLP | Investment in land development partnerships
Investment Holdings [Line Items]
Ownership interest acquired	34.45%
KD Kaupulehu, LLLP | Investment in land development partnerships
Investment Holdings [Line Items]
Ownership interest acquired	19.60%
KD Kaupulehu LLLP Increment I | Investment in land development partnerships
Investment Holdings [Line Items]
Number of residential lots remaining to be sold | lot		19
KD Kaupulehu, LLLP | KD Acquisition II, LP | Investment in land development partnerships
Investment Holdings [Line Items]
Ownership interest acquired				55.00%
Replay | KD Acquisition II, LP | Investment in land development partnerships
Investment Holdings [Line Items]
Ownership interest acquired				45.00%
Barnwell Industries Inc | KD Acquisition II, LP | Investment in land development partnerships
Investment Holdings [Line Items]
Ownership interest acquired		10.80%
Barnwell Hawaiian Properties, Inc. | KKM Makai LLLP
Investment Holdings [Line Items]
Preferred return to be received as a percentage from KKM	100.00%
Non-controlling Interests | Investment in land development partnerships
Investment Holdings [Line Items]
Cash distribution from equity method investment			$ 38
Maximum | Barnwell Hawaiian Properties, Inc. | KKM Makai LLLP
Investment Holdings [Line Items]
Preferred return, amount, from KKM	$ 1,000
Minimum | Investment in land development partnerships
Investment Holdings [Line Items]
Cumulative cash distributions from Kukio Resort Land Development Partnerships, threshold	$ 45,000

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RETIREMENT PLANS

3 Months Ended

Dec. 31, 2019

Retirement Benefits [Abstract]

RETIREMENT PLANS

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 Employee Retirement Plan (“SERP”), a noncontributory supplemental retirement benefit plan which covers certain current and former employees of Barnwell for amounts exceeding the limits allowed under the Pension Plan, and a postretirement medical insurance benefits plan (“Postretirement Medical”) covering eligible U.S. employees.

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

	Pension Plan						SERP						Postretirement Medical
	Three months ended December 31,
	2019			2018			2019			2018			2019		2018
Service cost	$	50,000		$	50,000		$	3,000		$	9,000		$	—	$	—
Interest cost	83,000			93,000			18,000			21,000			20,000		25,000
Expected return on plan assets	(163,000		)	(161,000		)	—			—			—		—
Amortization of prior service cost (credit)	1,000			1,000			(1,000		)	(1,000		)	—		—
Amortization of net actuarial loss	35,000			3,000			5,000			1,000			20,000		13,000
Curtailment cost (income)	53,000			—			(53,000		)	—			—		—
Net periodic benefit cost (income)	$	59,000		$	(14,000	)	$	(28,000	)	$	30,000		$	40,000	$	38,000

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

On December 12, 2019, the Company’s Board of Directors approved a resolution to freeze all future benefit accruals for all participants under the Company’s Pension Plan and SERP effective December 31, 2019. Accordingly, the Company remeasured the projected benefit obligation of the Pension Plan and SERP as of December 31, 2019. As a result of the remeasurement, the Company recorded a $880,000 actuarial gain in accumulated other comprehensive loss during the quarter ended December 31, 2019. The actuarial gain was primarily due to an increase in the market value of Pension Plan assets as well as an increase in the discount rate for both plans during the period. The impact of the Pension Plan and SERP plan freeze resulted in a $1,699,000 reduction in unrecognized pension benefit costs that were previously included in accumulated other comprehensive loss, with a corresponding benefit in other comprehensive income.

No contributions will be made to the Pension Plan during fiscal 2020. The SERP and Postretirement Medical plans are unfunded, and Barnwell funds benefits when payments are made. Expected payments under the Postretirement Medical plan and the SERP for fiscal 2020 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.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

3 Months Ended

Dec. 31, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Principles of Consolidation

The condensed consolidated financial statements include the accounts of Barnwell Industries, Inc. and all majority-owned subsidiaries (collectively referred to herein as “Barnwell,” “we,” “our,” “us,” or the “Company”), including a 77.6%-owned land investment general partnership (Kaupulehu Developments) and a 75%-owned land investment partnership (KD Kona 2013 LLLP). All significant intercompany accounts and transactions have been eliminated.

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

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

Unaudited Interim Financial Information

The accompanying unaudited condensed consolidated financial statements and notes have been prepared by Barnwell in accordance with the rules and regulations of the United States (“U.S.”) Securities and Exchange Commission. Accordingly, certain information and footnote disclosures normally included in the annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to those rules and regulations, although the Company believes that the disclosures made are adequate to make the information not misleading. These condensed consolidated financial statements and notes should be read in conjunction with the consolidated financial statements and notes thereto included in Barnwell’s September 30, 2019 Annual Report on Form 10-K, as amended by our Form 10-K/A Amendment No. 1 and Form 10-K/A Amendment No. 2. The Condensed Consolidated Balance Sheet as of September 30, 2019 has been derived from audited consolidated financial statements.

In the opinion of management, all adjustments (which include only normal recurring adjustments) necessary to present fairly the financial position at December 31, 2019, results of operations, comprehensiveincome (loss), equity and cash flows for the three months ended December 31, 2019 and 2018, have been made. The results of operations for the period ended December 31, 2019 are not necessarily indicative of the operating results for the full year.

Use of Estimates in the Preparation of Condensed Consolidated Financial Statements

The preparation of the condensed consolidated financial statements in conformity with U.S. GAAP requires management of Barnwell to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Actual results could differ significantly from those estimates. Significant assumptions are required in the valuation of deferred tax assets, asset retirement obligations, share-based payment arrangements, obligations for retirement plans, contract drilling estimated costs to complete, proved oil and natural gas reserves, and the carrying value of other assets, and such assumptions may impact the amount at which such items are recorded.

Significant Accounting Policies

Other than the accounting policies implemented in connection with the adoption of Accounting Standards Update (“ASU”) No. 2016-02, “Leases (Topic 842)” discussed in Note 11, 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 and Form 10-K/A Amendment No. 2.

Recently Adopted Accounting Pronouncements

In February 2016, the Financial Accounting Standards Board (“FASB”) issued ASU No. 2016-02, “Leases (Topic 842),” which requires an entity to recognize a right-of-use (“ROU”) asset and a lease liability on the balance sheet for all leases with terms greater than 12 months at the lease commencement date. The Company adopted the provisions of this ASU effective October 1, 2019. See Note 11 “Leases” for the required disclosures related to the impact of adopting this standard.

In February 2018, the FASB issued ASU No. 2018-02, “Reclassification of Certain Tax Effects From Accumulated Other Comprehensive Income,” which allows a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the Tax Cuts and Jobs Act of 2017. The Company adopted the provisions of this ASU effective October 1, 2019. The adoption of this update did not have an impact on Barnwell's consolidated financial statements.

In July 2018, the FASB issued ASU No. 2018-09, “Codification Improvements,” which provides further clarification to the codification literature. The Company adopted the provisions of this ASU effective October 1, 2019. The adoption of this update did not have an impact on Barnwell's consolidated financial statements.

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

3 Months Ended

Dec. 31, 2019

Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]

ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)

ACCUMULATED OTHER COMPREHENSIVE LOSS

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

	Three months ended   December 31,
	2019			2018
Foreign currency translation:
Beginning accumulated foreign currency translation	$	691,000		$	925,000
Change in cumulative translation adjustment before reclassifications	5,000			(413,000		)
Income taxes	—			—
Net current period other comprehensive income (loss)	5,000			(413,000		)
Ending accumulated foreign currency translation	696,000			512,000
Retirement plans:
Beginning accumulated retirement plans benefit cost	(3,608,000		)	(1,439,000		)
Amortization of net actuarial loss and prior service cost	60,000			17,000
Net actuarial gains arising during the period	2,579,000			—
Income taxes	—			—
Net current period other comprehensive income	2,639,000			17,000
Ending accumulated retirement plans benefit cost	(969,000		)	(1,422,000		)
Accumulated other comprehensive loss, net of taxes	$	(273,000	)	$	(910,000	)

The amortization of accumulated other comprehensive loss components for the retirement plans are included in the computation of net periodic benefit cost (income) which is a component of “General and administrative” expenses on the accompanying Condensed Consolidated Statements of Operations (see Note 5 for additional details).

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Cash flows from operating activities:
Net loss	$ (419)	$ (4,573)
Adjustments to reconcile net loss to net cash used in operating activities:
Equity in loss of affiliates	43	79
Depletion, depreciation, and amortization	705	819
Impairment of assets	0	2,170
Retirement benefits expense	71	54
Accretion of asset retirement obligation	134	150
Income tax receivable, noncurrent	0	(31)
Non-cash rent expense	30	22
Deferred income tax benefit	(9)	(72)
Asset retirement obligation payments	(2)	(33)
Share-based compensation benefit	0	(24)
Retirement plan contributions and payments	(2)	(2)
Sale of interest in leasehold land, net of fees paid	0	(124)
(Decrease) increase from changes in current assets and liabilities	(1,917)	567
Net cash used in operating activities	(1,366)	(998)
Cash flows from investing activities:
Proceeds from the maturity of certificates of deposit	0	741
Net proceeds from sale of interest in leasehold land	0	124
Distribution from equity investees in excess of earnings	0	352
Proceeds from sale of oil and natural gas assets	594	633
Payments to acquire oil and natural gas properties	0	(355)
Capital expenditures - oil and natural gas	(1,444)	(108)
Capital expenditures - all other	(13)	(96)
Net cash (used in) provided by investing activities	(863)	1,291
Cash flows from financing activities:
Distributions to non-controlling interests	0	(107)
Net cash used in financing activities	0	(107)
Effect of exchange rate changes on cash and cash equivalents	15	(53)
Net (decrease) increase in cash and cash equivalents	(2,214)	133
Cash and cash equivalents at beginning of period	4,613	5,965
Cash and cash equivalents at end of period	$ 2,399	$ 6,098

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INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Supplemental disclosure of cash flow information:
Income taxes refunded, net	$ 0	$ (866)
Oil and natural gas
Supplemental disclosures of cash flow information:
Increase (decrease) in capital expenditure accruals related to oil and natural gas exploration and development	1,661	(66)
Increase (decrease) in capital expenditure accruals related to oil and natural gas asset retirement obligations	$ 323	$ 146

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Document and Entity Information - shares	3 Months Ended
	Dec. 31, 2019	Feb. 07, 2020
Document and Entity Information
Entity Registrant Name	BARNWELL INDUSTRIES INC
Entity Central Index Key	0000010048
Document Type	10-Q
Document Period End Date	Dec. 31, 2019
Amendment Flag	false
Current Fiscal Year End Date	--09-30
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		8,277,160
Entity Small Business	true
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q1

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Statement of Comprehensive Income [Abstract]
Net loss	$ (419,000)	$ (4,573,000)
Other comprehensive income (loss):
Foreign currency translation adjustments, net of taxes of $0	5,000	(413,000)
Retirement plans:
Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	60,000	17,000
Net actuarial gains arising during the period, net of taxes of $0	880,000	0
Curtailment gain, net of taxes of $0	1,699,000	0
Total other comprehensive income (loss)	2,644,000	(396,000)
Total comprehensive income (loss)	2,225,000	(4,969,000)
Less: Comprehensive (loss) income attributable to non-controlling interests	(5,000)	27,000
Comprehensive income (loss) attributable to Barnwell Industries, Inc.	$ 2,230,000	$ (4,996,000)

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LEASES - LEASE COSTS (Details) $ in Thousands	3 Months Ended
	Dec. 31, 2019 USD ($)
Leases [Abstract]
Operating lease cost	$ 102
Short-term lease cost	17
Total lease cost	$ 119

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INVESTMENTS - INVESTMENT IN LEASEHOLD LAND INTEREST - LOT 4C (Details)	Dec. 31, 2019 a
Investment in leasehold land interest – Lot 4C
Investment Holdings [Line Items]
Area of land (in acres)	1,000

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REVENUE FROM CONTRACTS WITH CUSTOMERS - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Revenue before interest income	$ 4,843	$ 2,574
Oil
Disaggregation of Revenue [Line Items]
Revenue before interest income	1,725	896
Natural gas
Disaggregation of Revenue [Line Items]
Revenue before interest income	322	162
Natural gas liquids
Disaggregation of Revenue [Line Items]
Revenue before interest income	94	174
Drilling and pump
Disaggregation of Revenue [Line Items]
Revenue before interest income	2,646	1,163
Contingent residual payments
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	165
Other
Disaggregation of Revenue [Line Items]
Revenue before interest income	56	14
United States
Disaggregation of Revenue [Line Items]
Revenue before interest income	2,653	1,328
Canada
Disaggregation of Revenue [Line Items]
Revenue before interest income	2,190	1,246
Goods transferred at a point in time
Disaggregation of Revenue [Line Items]
Revenue before interest income	2,197	1,411
Services transferred over time
Disaggregation of Revenue [Line Items]
Revenue before interest income	2,646	1,163
Oil and natural gas
Disaggregation of Revenue [Line Items]
Revenue before interest income	2,141	1,232
Oil and natural gas | Oil
Disaggregation of Revenue [Line Items]
Revenue before interest income	1,725	896
Oil and natural gas | Natural gas
Disaggregation of Revenue [Line Items]
Revenue before interest income	322	162
Oil and natural gas | Natural gas liquids
Disaggregation of Revenue [Line Items]
Revenue before interest income	94	174
Oil and natural gas | Drilling and pump
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Oil and natural gas | Contingent residual payments
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Oil and natural gas | Other
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Oil and natural gas | United States
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Oil and natural gas | Canada
Disaggregation of Revenue [Line Items]
Revenue before interest income	2,141	1,232
Oil and natural gas | Goods transferred at a point in time
Disaggregation of Revenue [Line Items]
Revenue before interest income	2,141	1,232
Oil and natural gas | Services transferred over time
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Contract drilling
Disaggregation of Revenue [Line Items]
Revenue before interest income	2,646	1,163
Contract drilling | Oil
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Contract drilling | Natural gas
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Contract drilling | Natural gas liquids
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Contract drilling | Drilling and pump
Disaggregation of Revenue [Line Items]
Revenue before interest income	2,646	1,163
Contract drilling | Contingent residual payments
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Contract drilling | Other
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Contract drilling | United States
Disaggregation of Revenue [Line Items]
Revenue before interest income	2,646	1,163
Contract drilling | Canada
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Contract drilling | Goods transferred at a point in time
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Contract drilling | Services transferred over time
Disaggregation of Revenue [Line Items]
Revenue before interest income	2,646	1,163
Land investment
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	165
Land investment | Oil
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Land investment | Natural gas
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Land investment | Natural gas liquids
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Land investment | Drilling and pump
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Land investment | Contingent residual payments
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	165
Land investment | Other
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Land investment | United States
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	165
Land investment | Canada
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Land investment | Goods transferred at a point in time
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	165
Land investment | Services transferred over time
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Other
Disaggregation of Revenue [Line Items]
Revenue before interest income	56	14
Other | Oil
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Other | Natural gas
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Other | Natural gas liquids
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Other | Drilling and pump
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Other | Contingent residual payments
Disaggregation of Revenue [Line Items]
Revenue before interest income	0	0
Other | Other
Disaggregation of Revenue [Line Items]
Revenue before interest income	56	14
Other | United States
Disaggregation of Revenue [Line Items]
Revenue before interest income	7	0
Other | Canada
Disaggregation of Revenue [Line Items]
Revenue before interest income	49	14
Other | Goods transferred at a point in time
Disaggregation of Revenue [Line Items]
Revenue before interest income	56	14
Other | Services transferred over time
Disaggregation of Revenue [Line Items]
Revenue before interest income	$ 0	$ 0

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Sep. 30, 2019
Changes in foreign currency translation
Beginning accumulated foreign currency translation	$ 691	$ 925
Change in cumulative translation adjustment before reclassifications	5	(413)
Income taxes	0	0
Net current period other comprehensive income (loss)	5	(413)
Ending accumulated foreign currency translation	696	512
Changes in retirement plans
Beginning accumulated retirement plans benefit cost	(3,608)	(1,439)
Amortization of net actuarial loss and prior service cost	60	17
Net actuarial gains arising during the period	2,579	0
Net current period other comprehensive income	2,639	17
Income taxes	0	0
Ending accumulated retirement plans benefit cost	(969)	(1,422)
Accumulated other comprehensive loss, net of taxes	$ (273)	$ (910)	$ (2,917)

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INCOME TAXES (Tables)

3 Months Ended

Dec. 31, 2019

Income Tax Disclosure [Abstract]

Components of income (loss) before income taxes, after adjusting the earnings (loss) for non-controlling interests

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

	Three months ended   December 31,
	2019			2018
United States	$	(147,000	)	$	(1,124,000	)
Canada	(269,000		)	(3,581,000		)
	$	(416,000	)	$	(4,705,000	)

Schedule of components of the income tax provision (benefit)

The components of the income tax benefit are as follows:

	Three months ended   December 31,
	2019			2018
Current	$	7,000		$	(33,000	)
Deferred	(9,000		)	(72,000		)
	$	(2,000	)	$	(105,000	)

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

3 Months Ended

Dec. 31, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Principles of Consolidation

Principles of Consolidation

The condensed consolidated financial statements include the accounts of Barnwell Industries, Inc. and all majority-owned subsidiaries (collectively referred to herein as “Barnwell,” “we,” “our,” “us,” or the “Company”), including a 77.6%-owned land investment general partnership (Kaupulehu Developments) and a 75%-owned land investment partnership (KD Kona 2013 LLLP). All significant intercompany accounts and transactions have been eliminated.

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

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

Unaudited Interim Financial Information

Unaudited Interim Financial Information

The accompanying unaudited condensed consolidated financial statements and notes have been prepared by Barnwell in accordance with the rules and regulations of the United States (“U.S.”) Securities and Exchange Commission. Accordingly, certain information and footnote disclosures normally included in the annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to those rules and regulations, although the Company believes that the disclosures made are adequate to make the information not misleading. These condensed consolidated financial statements and notes should be read in conjunction with the consolidated financial statements and notes thereto included in Barnwell’s September 30, 2019 Annual Report on Form 10-K, as amended by our Form 10-K/A Amendment No. 1 and Form 10-K/A Amendment No. 2. The Condensed Consolidated Balance Sheet as of September 30, 2019 has been derived from audited consolidated financial statements.

In the opinion of management, all adjustments (which include only normal recurring adjustments) necessary to present fairly the financial position at December 31, 2019, results of operations, comprehensiveincome (loss), equity and cash flows for the three months ended December 31, 2019 and 2018, have been made. The results of operations for the period ended December 31, 2019 are not necessarily indicative of the operating results for the full year.

Use of Estimates in the Preparation of Condensed Consolidated Financial Statements

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.

Recently Adopted Accounting Pronouncements

Recently Adopted Accounting Pronouncements

In February 2016, the Financial Accounting Standards Board (“FASB”) issued ASU No. 2016-02, “Leases (Topic 842),” which requires an entity to recognize a right-of-use (“ROU”) asset and a lease liability on the balance sheet for all leases with terms greater than 12 months at the lease commencement date. The Company adopted the provisions of this ASU effective October 1, 2019. See Note 11 “Leases” for the required disclosures related to the impact of adopting this standard.

In February 2018, the FASB issued ASU No. 2018-02, “Reclassification of Certain Tax Effects From Accumulated Other Comprehensive Income,” which allows a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the Tax Cuts and Jobs Act of 2017. The Company adopted the provisions of this ASU effective October 1, 2019. The adoption of this update did not have an impact on Barnwell's consolidated financial statements.

In July 2018, the FASB issued ASU No. 2018-09, “Codification Improvements,” which provides further clarification to the codification literature. The Company adopted the provisions of this ASU effective October 1, 2019. The adoption of this update did not have an impact on Barnwell's consolidated financial statements.

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LEASES

3 Months Ended

Dec. 31, 2019

Leases [Abstract]

LEASES

LEASES

On October 1, 2019, the Company adopted ASU No. 2016-02, “Leases (Topic 842),” using the modified retrospective transition approach and applied the new standard to leases in place as of the adoption date. Results for reporting periods prior to October 1, 2019 have not been adjusted. The Company elected the package of practical expedients allowed upon adoption of Accounting Standards Codification (“ASC”) 842 which, among other things, allowed us to (1) not reassess whether any expired or existing contracts contain leases, (2) carry forward the historical lease classification, and (3) not have to reassess any initial direct cost of any expired or existing leases.

As a result of the adoption of ASC 842, the Company recorded operating lease right-of-use (“ROU”) assets of $2,589,000 and corresponding total operating lease liabilities of $2,589,000 in the Condensed Consolidated Balance Sheets as of October 1, 2019. There was no impact to retained earnings or the Condensed Consolidated Statements of Operations.

The Company’s ROU assets and lease liabilities primarily relate to non-cancelable operating leases for our Canadian office space, our contract drilling maintenance and storage yard, and our leasehold land interest for Lot 4C held by Kaupulehu Developments. Management determines if a contract is or contains a lease at inception of the contract or modification of the contract. A contract is or contains a lease if the contract conveys the right to control the use of the asset for a period in exchange for consideration.

Operating lease ROU assets and liabilities are recognized based on the present value of future minimum lease payments over the expected lease term at commencement date. The Company’s leases do not provide a readily determinable implicit rate; therefore, management uses the Company’s incremental borrowing rate to discount lease payments based on information available at lease commencement. Our lease terms may include options to extend or terminate the lease when it is reasonably certain we will exercise that potion. Lease expense for minimum lease payments is recognized on a straight-line basis over the expected lease terms.

The Company has lease agreements with lease and non-lease components and the non-lease components are excluded in the calculation of the ROU asset and lease liability and expensed as incurred. None of the Company’s lease agreements contain material residual value guarantees or material restrictions or covenants.

A ROU asset and corresponding lease liability is not recorded for leases with an initial term of 12 months or less (short-term leases) as the Company recognizes lease expense for these leases as incurred over the lease term.

In the quarter ended December 31, 2019, Barnwell initiated discussions with a potential buyer of Barnwell's leasehold interest in its three-quarter of an acre contract drilling segment maintenance and storage yard in Honolulu, Hawaii. The lease has terms that are favorable as compared to market lease rates for comparable properties in the area. The ROU asset related to this lease has been classified as “Operating lease right-of-use asset held for sale” and the related lease liability is included in the “Operating lease liability held for sale” in the Condensed Consolidated Balance Sheet as of December 31, 2019.

Leases recorded on the balance sheet consist of the following:

		December 31, 2019
Assets:
	Operating lease right-of-use asset held for sale	$	2,226,000
	Operating lease right-of-use assets	331,000
	Total right-of-use assets	$	2,557,000
Liabilities:
	Operating lease liability held for sale	$	2,441,000
	Current portion of operating lease liabilities	108,000
	Operating lease liabilities	230,000
	Total lease liabilities	$	2,779,000

The components of lease expenses are as follows:

	Three months ended December 31, 2019
Operating lease cost	$	102,000
Short-term lease cost	17,000
Total lease cost	$	119,000

Supplemental information related to leases is as follows:

		December 31, 2019
Cash paid for amounts included in the measurement of lease liabilities:
	Operating cash flows from operating leases	$	64,000
Operating leases:
	Weighted-average remaining lease term (in years)	24.6
	Weighted-average discount rate	6.77%

The remaining lease payments for our operating leases as of December 31, 2019, are as follows:

Fiscal year ending:
Remainder of 2020	$	194,000
2021	258,000
2022	202,000
2023	193,000
2024	193,000
Thereafter through 2047	5,574,000
Total lease payments	6,614,000
Less: amounts representing interest	(3,835,000		)
Present value of lease liabilities	$	2,779,000

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REVENUE FROM CONTRACTS WITH CUSTOMERS REVENUE FROM CONTACTS WITH CUSTOMERS

3 Months Ended

Dec. 31, 2019

Revenue from Contract with Customer [Abstract]

REVENUE FROM CONTRACTS WITH CUSTOMERS

REVENUE FROM CONTRACTS WITH CUSTOMERS

Disaggregation of Revenue

The following tables provides information about disaggregated revenue by revenue streams, reportable segments, geographical region, and timing of revenue recognition for the three months ended December 31, 2019 and 2018.

		Three months ended December 31, 2019
		Oil and natural gas		Contract drilling		Land investment		Other		Total
Revenue streams:
	Oil	$	1,725,000	$	—	$	—	$	—	$	1,725,000
	Natural gas	322,000		—		—		—		322,000
	Natural gas liquids	94,000		—		—		—		94,000
	Drilling and pump	—		2,646,000		—		—		2,646,000
	Contingent residual payments	—		—		—		—		—
	Other	—		—		—		56,000		56,000
	Total revenues before interest income	$	2,141,000	$	2,646,000	$	—	$	56,000	$	4,843,000
Geographical regions:
	United States	$	—	$	2,646,000	$	—	$	7,000	$	2,653,000
	Canada	2,141,000		—		—		49,000		2,190,000
	Total revenues before interest income	$	2,141,000	$	2,646,000	$	—	$	56,000	$	4,843,000
Timing of revenue recognition:
	Goods transferred at a point in time	$	2,141,000	$	—	$	—	$	56,000	$	2,197,000
	Services transferred over time	—		2,646,000		—		—		2,646,000
	Total revenues before interest income	$	2,141,000	$	2,646,000	$	—	$	56,000	$	4,843,000

		Three months ended December 31, 2018
		Oil and natural gas		Contract drilling		Land investment		Other		Total
Revenue streams:
	Oil	$	896,000	$	—	$	—	$	—	$	896,000
	Natural gas	162,000		—		—		—		162,000
	Natural gas liquids	174,000		—		—		—		174,000
	Drilling and pump	—		1,163,000		—		—		1,163,000
	Contingent residual payments	—		—		165,000		—		165,000
	Other	—		—		—		14,000		14,000
	Total revenues before interest income	$	1,232,000	$	1,163,000	$	165,000	$	14,000	$	2,574,000
Geographical regions:
	United States	$	—	$	1,163,000	$	165,000	$	—	$	1,328,000
	Canada	1,232,000		—		—		14,000		1,246,000
	Total revenues before interest income	$	1,232,000	$	1,163,000	$	165,000	$	14,000	$	2,574,000
Timing of revenue recognition:
	Goods transferred at a point in time	$	1,232,000	$	—	$	165,000	$	14,000	$	1,411,000
	Services transferred over time	—		1,163,000		—		—		1,163,000
	Total revenues before interest income	$	1,232,000	$	1,163,000	$	165,000	$	14,000	$	2,574,000

Contract Balances

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

	December 31, 2019		September 30, 2019
Accounts receivables from contracts with customers	$	2,862,000	$	1,322,000
Contract assets	551,000		344,000
Contract liabilities	1,043,000		1,633,000

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

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

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

When the Company receives consideration, or such consideration is unconditionally due, from a customer prior to transferring goods or services to the customer under the terms of a sales contract, the Company records deferred revenue, which represents a contract liability. Such deferred revenue typically results from billings in excess of costs and estimated earnings on uncompleted contracts. As of December 31, 2019 and September 30, 2019, the Company had $1,043,000 and $1,633,000, respectively, included in “Other current liabilities” on the balance sheet for those performance obligations expected to be completed in the next twelve months.

During the three months ended December 31, 2019 and 2018, the amount of revenue recognized that was previously included in contract liabilities as of the beginning of the respective period was $1,480,000 and $21,000, respectively.

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

Performance Obligations

The Company’s remaining performance obligations for drilling and pump installation contracts (hereafter referred to as “backlog”) represent the unrecognized revenue value of the Company’s contract commitments. The Company’s backlog may vary significantly each reporting period based on the timing of major new contract commitments. In addition, our customers have the right, under some infrequent circumstances, to terminate contracts or defer the timing of the Company’s services and their payments to us. Nearly all of the Company's contract drilling segment contracts have original expected durations of one year or less. At December 31, 2019, the Company had three contract drilling jobs with original expected durations of greater than one year. For these contracts, approximately 78% of the remaining performance obligation of $2,556,000 is expected to be recognized as revenue in the next twelve months and the remaining, thereafter. At September 30, 2019, the Company had three contract drilling jobs with original durations of greater than one year. For those contracts, approximately 79% of the remaining performance obligation of $2,866,000 was expected to be recognized as revenue in the next twelve months and the remaining, thereafter.

Contract Fulfillment Costs

Preconstruction costs, which include costs such as set-up and mobilization, are capitalized and allocated across all performance obligations and deferred and amortized over the contract term on a progress towards completion basis. As of December 31, 2019 and September 30, 2019, the Company had $258,000 and $296,000, respectively, in unamortized preconstruction costs related to contracts that were not completed. During the three months ended December 31, 2019 and 2018, the amortization of preconstruction costs related to contracts were not material and were included in the accompanying Condensed Consolidated Statements of Operations. Additionally, no impairment charges in connection with the Company’s preconstruction costs were recorded during the three months ended December 31, 2019 and 2018.

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INVESTMENTS

3 Months Ended

Dec. 31, 2019

Investments, All Other Investments [Abstract]

INVESTMENTS

INVESTMENTS

A summary of Barnwell’s non-current investments is as follows:

	December 31, 2019		September 30, 2019
Investment in Kukio Resort Land Development Partnerships	$	887,000	$	930,000
Investment in leasehold land interest – Lot 4C	50,000		50,000
Total non-current investments	$	937,000	$	980,000

Investment in Kukio Resort Land Development Partnerships

On November 27, 2013, Barnwell, through a wholly-owned subsidiary, entered into two limited liability limited partnerships, KD Kona 2013 LLLP and KKM Makai, LLLP (“KKM”), and indirectly acquired a 19.6% non-controlling ownership interest in each of KD Kukio Resorts, LLLP, KD Maniniowali, LLLP and KD Kaupulehu, LLLP (“KDK”) for $5,140,000. These entities, collectively referred to hereinafter as the “Kukio Resort Land Development Partnerships,” own certain real estate and development rights interests in the Kukio, Maniniowali and Kaupulehu portions of Kukio Resort, a private residential community on the Kona coast of the island of Hawaii, as well as Kukio Resort’s real estate sales office operations. KDK holds interests in KD Acquisition, LLLP (“KD I”) and KD Acquisition II, LP, formerly KD Acquisition II, LLLP (“KD II”). KD I is the developer of Kaupulehu Lot 4A Increment I (“Increment I”), and KD II is the developer of Kaupulehu Lot 4A Increment II (“Increment II”). Barnwell's ownership interests in the Kukio Resort Land Development Partnerships is accounted for using the equity method of accounting. The partnerships derive income from the sale of residential parcels, of which 19 lots remain to be sold at Increment I as of December 31, 2019, as well as from commissions on real estate sales by the real estate sales office.

In March 2019, KD II admitted a new development partner, Replay Kaupulehu Development, LLC (“Replay”), a party unrelated to Barnwell, in an effort to move forward with development of the remainder of Increment II at Kaupulehu. Effective March 7, 2019, KDK and Replay hold ownership interests of 55% and 45%, respectively, of KD II. Accordingly, Barnwell has a 10.8% indirect non-controlling ownership interest in KD II through KDK as of that date that will continue to be accounted for using the equity method of accounting. Barnwell continues to have an indirect 19.6% non-controlling ownership interest in KD Kukio Resorts, LLLP, KD Maniniowali, LLLP, and KD I.

There were no cash distributions from the Kukio Resort Land Development Partnership for the three months ended December 31, 2019. During the three months ended December 31, 2018, Barnwell received net cash distributions in the amount of $314,000 from the Kukio Resort Land Development Partnerships after distributing $38,000 to non-controlling interests.

Barnwell has the right to receive distributions from its non-controlling interest in KKM in proportion to its partner capital sharing ratio of 34.45%. Barnwell is entitled to a 100% preferred return up to $1,000,000 from KKM on any allocated equity in income of the Kukio Resort Land Development Partnerships for cumulative distributions to all of its partners in excess of $45,000,000 from those partnerships. Cumulative distributions from the Kukio Resort Land Development Partnerships have reached the $45,000,000 threshold. However, because we have no control over the distributions from the Kukio Resort Land Development Partnerships and the ability of the Kukio Resort Land Development Partnerships to make such distributions is dependent upon their future sales of lots, we have not recorded any estimated potential preferred return from KKM in our equity in income to date. However, if sufficient distributions are made by the Kukio Resort Land Development Partnerships in the future, Barnwell will have equity in income of affiliates for the recognition of the preferred return. There is no assurance that any future distributions and resulting preferred returns will occur.

Equity in loss of affiliates was $43,000 and $79,000for the three months ended December 31, 2019 and 2018, respectively. The equity in the underlying net assets of the Kukio Resort Land Development Partnerships exceeds the carrying value of the investment in affiliates by approximately $296,000 as of December 31, 2019, which is attributable to differences in the value of capitalized development costs and a note receivable. The basis difference will be recognized as the partnerships sell lots and recognize the associated costs and sell memberships for the Kuki`o Golf and Beach Club for which the receivable relates. There was an immaterial basis difference adjustment for the three months ended December 31, 2019. The basis difference adjustment of $1,000, for the three months ended December 31, 2018, increased equity in income of affiliates.

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

	Three months ended   December 31,
	2019			2018
Revenue	$	1,766,000		$	1,948,000
Gross profit	$	796,000		$	646,000
Net loss	$	(168,000	)	$	(158,000	)

Sale of Interest in Leasehold Land

Kaupulehu Developments has the right to receive payments from KD I and KD II resulting from the sale of lots and/or residential units within Increment I and Increment II by KD I and KD II (see Note 14).

With respect to Increment I, Kaupulehu Developments is entitled to receive payments from KD I based on the following percentages of the gross receipts from KD I’s sales of single-family residential lots in Increment I: 10% of such aggregate gross proceeds greater than $100,000,000 up to $300,000,000; and 14% of such aggregate gross proceeds in excess of $300,000,000. The total amount of gross proceeds from single-family lot sales was $216,400,000 through December 31, 2019. No single-family lots were sold during the three months ended December 31, 2019 and 19 single-family lots, of the 80 lots developed within Increment I, remained to be sold as of December 31, 2019.

Under the terms of the former Increment II agreement with KD II, Kaupulehu Developments was entitled to receive payments from KD II resulting from the sale of lots and/or residential units by KD II within Increment II. Through March 6, 2019, the payments were based on a percentage of gross receipts from KD II's sales ranging from 8% to 10% of the price of improved or unimproved lots or 2.60% to 3.25% of the price of units constructed on a lot, to be determined in the future depending upon a number of variables, including whether the lots are sold prior to improvement. Two ocean front parcels approximately two to three acres in size fronting the ocean were developed within Increment II by KD II, of which one was sold in fiscal 2017 and one was sold in fiscal 2016. The remaining acreage within Increment II is not yet under development.

Through March 6, 2019, Kaupulehu Developments was also entitled to receive 50% of distributions otherwise payable from KD II to its members after the members of KD II have received distributions equal to the original basis of capital invested in the project, up to $8,000,000. Through March 6, 2019, a cumulative total of $3,500,000 was received from KD II under this arrangement, out of the $8,000,000 maximum. The former arrangement also included the rights to three single-family residential lots in Phase 2 of Increment II when developed, at no cost to Barnwell, with a commitment by Barnwell to begin to construct a residence upon each lot within six months of transfer.

Concurrent with the transaction whereby KD II admitted Replay as a new development partner, Kaupulehu Developments entered into new agreements with KD II whereby the aforementioned terms of the former Increment II arrangement were eliminated and Kaupulehu Developments will instead be entitled to 15% of the distributions of KD II, the cost of which is to be solely borne by KDK out of its 55% ownership interest in KD II, plus a priority payout of 10% of KDK’s cumulative net profits derived from Increment II sales subsequent to Phase 2A, up to a maximum of $3,000,000 as to the priority payout. Such interests are limited to distributions or net profits interests and Barnwell will not have any partnership interests in KD II or KDK through its interest in Kaupulehu Developments. The new arrangement also gives Barnwell rights to 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, in compensation for the agreement of these parties to admit the new development partner for Increment II. Such compensation will be reflected as the obligation becomes probable and the amount of the obligation can be reasonably estimated. The new agreements also specify that Kaupulehu Developments was to be paid $1,000,000 by KD II prior to admission of Replay as a partner. This $1,000,000 payment had already been received in June 2018 and is included in the $3,500,000 cumulative total as of March 6, 2019 discussed above.

The Increment I percentage of sales arrangement between Barnwell and KD I remains unchanged.

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

	Three months ended   December 31,
	2019		2018
Sale of interest in leasehold land:
Revenues - sale of interest in leasehold land	$	—	$	165,000
Fees - included in general and administrative expenses	—		(20,000		)
Sale of interest in leasehold land, net of fees paid	$	—	$	145,000

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.

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ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Tables)

3 Months Ended

Dec. 31, 2019

Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]

Schedule of changes in each component of accumulated other comprehensive income (loss)

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

	Three months ended   December 31,
	2019			2018
Foreign currency translation:
Beginning accumulated foreign currency translation	$	691,000		$	925,000
Change in cumulative translation adjustment before reclassifications	5,000			(413,000		)
Income taxes	—			—
Net current period other comprehensive income (loss)	5,000			(413,000		)
Ending accumulated foreign currency translation	696,000			512,000
Retirement plans:
Beginning accumulated retirement plans benefit cost	(3,608,000		)	(1,439,000		)
Amortization of net actuarial loss and prior service cost	60,000			17,000
Net actuarial gains arising during the period	2,579,000			—
Income taxes	—			—
Net current period other comprehensive income	2,639,000			17,000
Ending accumulated retirement plans benefit cost	(969,000		)	(1,422,000		)
Accumulated other comprehensive loss, net of taxes	$	(273,000	)	$	(910,000	)

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LOSS PER COMMON SHARE (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Net Loss (Numerator)
Basic	$ (414)	$ (4,600)
Effect of dilutive securities - common stock options	0	0
Diluted	$ (414)	$ (4,600)
Shares (Denominator)
Basic (in shares)	8,277,160	8,277,160
Effect of dilutive securities - common stock options	0	0
Diluted (in shares)	8,277,160	8,277,160
Per-Share Amount
Basic net loss per share (in dollars per share)	$ (0.05)	$ (0.56)
Diluted net loss per share (in dollars per share)	$ (0.05)	$ (0.56)
Options
Antidilutive shares of common stock excluded from the computation of diluted shares
Antidilutive shares excluded from computation of earnings (loss) per share (in shares)	60,000	318,750

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INVESTMENTS - SALE OF INTEREST IN LEASEHOLD LAND (Details)		1 Months Ended	3 Months Ended	5 Months Ended	12 Months Ended
	Nov. 27, 2013 partnership	Jun. 30, 2018 USD ($)	Dec. 31, 2019 USD ($) lot	Mar. 06, 2019 USD ($)	Sep. 30, 2017 a	Sep. 30, 2016	Mar. 07, 2019 USD ($) day
Investment in land development partnerships
Investment Holdings [Line Items]
Number of limited liability limited partnerships formed | partnership	2
KD Acquisition II, LP | Investment in land development partnerships
Investment Holdings [Line Items]
Collaborative agreement, percentage of distributions							15.00%
Collaborative agreement, percentage of cumulative net profits, priority payment							10.00%
Collaborative agreement, percentage of cumulative net profits, priority payment, maximum amount							$ 3,000,000
KD Acquisition II, LP | KD Kaupulehu, LLLP | Investment in land development partnerships
Investment Holdings [Line Items]
Ownership interest acquired							55.00%
KD Kaupulehu LLLP Increment I | Kaupulehu Developments
Investment Holdings [Line Items]
Aggregate gross proceeds from sale of increment I single family lots for calculating payments entitled to be received			$ 216,400,000
Number of lots remaining to be sold | lot			19
Number of lots developed | lot			80
KD Kaupulehu LLLP Increment II | Kaupulehu Developments
Investment Holdings [Line Items]
Number of single family lots sold					1	1
Number of lots developed					2
Percent of Increment II distributions				50.00%
Gain contingency, unrecorded amount				$ 8,000,000
50% of Increment II distributions received		$ 1,000,000		$ 3,500,000
KD Kaupulehu LLLP Increment II Phase 2A | Investment in land development partnerships
Investment Holdings [Line Items]
Number of single family lots, rights to				3			3
KD Kaupulehu LLLP Increment II Phase 2A, lots completed subsequent to Phase 2A | Investment in land development partnerships
Investment Holdings [Line Items]
Number of single family lots, rights to							4
Collaborative agreement, commitment to construct improvements, term | day							90
KD Development, LLC | Investment in land development partnerships
Investment Holdings [Line Items]
Collaborative agreement, fees, percentage of cumulative net profits							0.20%
Pool of Various Individuals | Investment in land development partnerships
Investment Holdings [Line Items]
Collaborative agreement, fees, percentage of cumulative net profits							0.72%
Aggregate gross proceeds greater than $100,000,000 up to $300,000,000 | KD Kaupulehu LLLP Increment I | Kaupulehu Developments
Investment Holdings [Line Items]
Payments entitled to be received as percentage of gross proceeds from sale of single family lots			10.00%
Aggregate gross proceeds in excess of $300,000 | KD Kaupulehu LLLP Increment I | Kaupulehu Developments
Investment Holdings [Line Items]
Payments entitled to be received as percentage of gross proceeds from sale of single family lots			14.00%
Minimum | KD Kaupulehu LLLP Increment II | Kaupulehu Developments
Investment Holdings [Line Items]
Payments entitled to be received as percentage of gross proceeds from sale of single family lots				8.00%
Payments entitled to be received as percentage of gross proceeds from sale of units on a lot				2.60%
Increment II lot size | a					2
Minimum | Aggregate gross proceeds greater than $100,000,000 up to $300,000,000 | KD Kaupulehu LLLP Increment I | Kaupulehu Developments
Investment Holdings [Line Items]
Aggregate gross proceeds from sale of increment I single family lots for calculating payments entitled to be received			$ 100,000,000
Minimum | Aggregate gross proceeds in excess of $300,000 | KD Kaupulehu LLLP Increment I | Kaupulehu Developments
Investment Holdings [Line Items]
Aggregate gross proceeds from sale of increment I single family lots for calculating payments entitled to be received			300,000,000
Maximum | KD Kaupulehu LLLP Increment II | Kaupulehu Developments
Investment Holdings [Line Items]
Payments entitled to be received as percentage of gross proceeds from sale of single family lots				10.00%
Payments entitled to be received as percentage of gross proceeds from sale of units on a lot				3.25%
Increment II lot size | a					3
Maximum | Aggregate gross proceeds greater than $100,000,000 up to $300,000,000 | KD Kaupulehu LLLP Increment I | Kaupulehu Developments
Investment Holdings [Line Items]
Aggregate gross proceeds from sale of increment I single family lots for calculating payments entitled to be received			$ 300,000,000

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LEASES - OPERATING LEASE MATURITY SCHEDULE (Details) $ in Thousands	Dec. 31, 2019 USD ($)
Leases [Abstract]
Remainder of 2020	$ 194
2021	258
2022	202
2023	193
2024	193
Thereafter through 2047	5,574
Total lease payments	6,614
Less: amounts representing interest	(3,835)
Present value of lease liabilities	$ 2,779

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CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2019	Sep. 30, 2019
Statement of Financial Position [Abstract]
Accounts receivable, allowance for doubtful accounts	$ 45	$ 44
Common stock, par value (in dollars per share)	$ 0.50	$ 0.50
Common stock, authorized shares	20,000,000	20,000,000
Common stock, issued shares	8,445,060	8,445,060
Treasury stock, shares	167,900	167,900

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CONDENSED CONSOLIDATED STATEMENTS OF EQUITY - USD ($)	Total	Common Stock	Additional Paid-In Capital	Retained Earnings	Accumulated Other Comprehensive Loss	Treasury Stock	Non-controlling Interests
Balance, beginning of period (in shares) at Sep. 30, 2018		8,277,160
Balance, beginning of period at Sep. 30, 2018	$ 16,239,000	$ 4,223,000	$ 1,350,000	$ 13,253,000	$ (514,000)	$ (2,286,000)	$ 213,000
Increase (Decrease) in Stockholders' Equity
Cumulative impact from the adoption of ASU No. 2014-09	20,000			20,000
Distributions to non-controlling interests	(107,000)						(107,000)
Net (loss) earnings	(4,573,000)			(4,600,000)			27,000
Foreign currency translation adjustments, net of taxes of $0	(413,000)				(413,000)
Retirement plans:
Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	17,000				17,000
Net actuarial gains arising during the period, net of taxes of $0	0
Curtailment gain, net of taxes of $0	0
Balance, end of period (in shares) at Dec. 31, 2018		8,277,160
Balance, end of period at Dec. 31, 2018	11,183,000	$ 4,223,000	1,350,000	8,673,000	(910,000)	(2,286,000)	133,000
Balance, beginning of period (in shares) at Sep. 30, 2019		8,277,160
Balance, beginning of period at Sep. 30, 2019	1,329,000	$ 4,223,000	1,350,000	859,000	(2,917,000)	(2,286,000)	100,000
Increase (Decrease) in Stockholders' Equity
Net (loss) earnings	(419,000)			(414,000)			(5,000)
Foreign currency translation adjustments, net of taxes of $0	5,000				5,000
Retirement plans:
Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	60,000				60,000
Net actuarial gains arising during the period, net of taxes of $0	880,000				880,000
Curtailment gain, net of taxes of $0	1,699,000				1,699,000
Balance, end of period (in shares) at Dec. 31, 2019		8,277,160
Balance, end of period at Dec. 31, 2019	$ 3,554,000	$ 4,223,000	$ 1,350,000	$ 445,000	$ (273,000)	$ (2,286,000)	$ 95,000

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LEASES - NARRATIVE (Details) $ in Thousands	Dec. 31, 2019 USD ($) a	Oct. 01, 2019 USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating lease right-of-use assets	$ 331
Operating lease liability	$ 2,779
Operating lease, area of land | a	0.75
Accounting Standards Update 2016-02
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating lease right-of-use assets		$ 2,589
Operating lease liability		$ 2,589

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SEGMENT INFORMATION

3 Months Ended

Dec. 31, 2019

Segment Reporting [Abstract]

SEGMENT INFORMATION

SEGMENT INFORMATION

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

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

	Three months ended   December 31,
	2019			2018
Revenues:
Oil and natural gas	$	2,141,000		$	1,232,000
Contract drilling	2,646,000			1,163,000
Land investment	—			165,000
Other	56,000			14,000
Total before interest income	4,843,000			2,574,000
Interest income	7,000			21,000
Total revenues	$	4,850,000		$	2,595,000
Depletion, depreciation, and amortization:
Oil and natural gas	$	606,000		$	749,000
Contract drilling	85,000			57,000
Other	14,000			13,000
Total depletion, depreciation, and amortization	$	705,000		$	819,000
Impairment:
Oil and natural gas	$	—		$	2,170,000
Total impairment	$	—		$	2,170,000
Operating profit (loss) (before general and administrative expenses):
Oil and natural gas	$	322,000		$	(3,024,000	)
Land investment	—			165,000
Contract drilling	747,000			(210,000		)
Other	42,000			1,000
Total operating profit (loss)	1,111,000			(3,068,000		)
Equity in loss of affiliates:
Land investment	(43,000		)	(79,000		)
General and administrative expenses	(1,496,000		)	(1,548,000		)
Interest expense	—			(4,000		)
Interest income	7,000			21,000
Loss before income taxes	$	(421,000	)	$	(4,678,000	)

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OIL AND NATURAL GAS PROPERTIES

3 Months Ended

Dec. 31, 2019

Oil and Natural Gas Properties [Abstract]

OIL AND NATURAL GAS PROPERTIES

OIL AND NATURAL GAS PROPERTIES

Dispositions

In October 2019, Barnwell entered into a purchase and sale agreement with an independent third party and sold its interests in properties located in the Progress area of Alberta, Canada. The sales price per the agreement was adjusted for customary purchase price adjustments to $594,000 in order to, among other things, reflect an economic effective date of October 1, 2019. The final determination of the customary adjustments to the purchase price has not yet been made however it is not expected to result in a material adjustment. The proceeds were credited to the full cost pool, with no gain or loss recognized, as the sale did not result in a significant alteration of the relationship between capitalized costs and proved reserves.

There were no oil and natural gas property dispositions during the three months ended December 31, 2018. The $633,000 of proceeds from sale of oil and gas properties included in the Condensed Consolidated Statement of Cash Flows for the three months ended December 31, 2018 represents the refund of income taxes previously withheld from what otherwise would have been proceeds on the previous years' oil and natural gas property sales.

Acquisitions

There were no significant amounts paid for oil and natural gas property acquisitions during the three months ended December 31, 2019.

In the quarter ended December 31, 2018, Barnwell acquired additional working interests in oil and natural gas properties located in the Wood River and Twining areas of Alberta, Canada for cash consideration of $355,000. The purchase prices per the agreements were adjusted for customary purchase price adjustments to reflect the economic activity from the effective date to the closing date. The customary purchase price adjustments were finalized in the quarter ended June 30, 2019 and resulted in an immaterial adjustment.

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 no ceiling test impairment during the three months ended December 31, 2019. There was a ceiling test impairment of $2,170,000 during the three months ended December 31, 2018.

Changes in the 12-month rolling average first-day-of-the-month prices for oil, natural gas and natural gas liquids prices, the value of reserve additions as compared to the amount of capital expenditures to obtain them, and changes in production rates and estimated levels of reserves, future development costs and the market value of unproved properties, impact the determination of the maximum carrying value of oil and natural gas properties. In addition, the ceiling test is also impacted by any changes in management's quarterly evaluation of the Company's ability to fund the approximately $12,000,000 of future capital expenditures necessary over the next five years to develop the proved undeveloped reserves that are largely in the Twining areas of Alberta, Canada, the value of which is included in the calculation of the ceiling limitation. If facts, circumstances, estimates and assumptions underlying management's assessment of the Company's ability to fund such capital expenditures change such that it is no longer reasonably certain that all of the approximately $12,000,000 of capital expenditures necessary to develop the proved undeveloped reserves can be made, it is likely that we will incur a further ceiling test impairment at that time.

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INVESTMENTS - SUMMARIZED FINANCIAL INFORMATION (Details) - Investment in land development partnerships - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Investment Holdings [Line Items]
Revenue	$ 1,766	$ 1,948
Gross profit	796	646
Net loss	$ (168)	$ (158)

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SEGMENT INFORMATION (Tables)

3 Months Ended

Dec. 31, 2019

Segment Reporting [Abstract]

Schedule of financial information related to reporting segments

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,
	2019			2018
Revenues:
Oil and natural gas	$	2,141,000		$	1,232,000
Contract drilling	2,646,000			1,163,000
Land investment	—			165,000
Other	56,000			14,000
Total before interest income	4,843,000			2,574,000
Interest income	7,000			21,000
Total revenues	$	4,850,000		$	2,595,000
Depletion, depreciation, and amortization:
Oil and natural gas	$	606,000		$	749,000
Contract drilling	85,000			57,000
Other	14,000			13,000
Total depletion, depreciation, and amortization	$	705,000		$	819,000
Impairment:
Oil and natural gas	$	—		$	2,170,000
Total impairment	$	—		$	2,170,000
Operating profit (loss) (before general and administrative expenses):
Oil and natural gas	$	322,000		$	(3,024,000	)
Land investment	—			165,000
Contract drilling	747,000			(210,000		)
Other	42,000			1,000
Total operating profit (loss)	1,111,000			(3,068,000		)
Equity in loss of affiliates:
Land investment	(43,000		)	(79,000		)
General and administrative expenses	(1,496,000		)	(1,548,000		)
Interest expense	—			(4,000		)
Interest income	7,000			21,000
Loss before income taxes	$	(421,000	)	$	(4,678,000	)

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details)	3 Months Ended
	Dec. 31, 2019
Kaupulehu Developments
Principles of Consolidation
Ownership interest in subsidiaries (as a percent)	77.60%
KD Kona 2013 LLLP
Principles of Consolidation
Ownership interest in subsidiaries (as a percent)	75.00%

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CONTINGENCIES (Details) $ in Thousands	12 Months Ended
	Sep. 30, 2019 well customer	Dec. 31, 2019 USD ($)
Failure of Hole Opener | Minimum
Loss Contingencies
Estimate of possible loss		$ 1,400
Failure of Hole Opener | Maximum
Loss Contingencies
Estimate of possible loss		1,600
Unfavorable Regulatory Action | Minimum
Loss Contingencies
Estimate of possible loss		2,000
Unfavorable Regulatory Action | Maximum
Loss Contingencies
Estimate of possible loss		$ 3,000
Contract drilling
Loss Contingencies
Number of wells not meeting specifications for plumbness | well	2
Number of customers with wells not meeting specifications for plumbness | customer	1

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CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2019	Sep. 30, 2019
Current assets:
Cash and cash equivalents	$ 2,399	$ 4,613
Accounts and other receivables, net of allowance for doubtful accounts of: $45,000 at December 31, 2019; $44,000 at September 30, 2019	3,220	1,884
Income taxes receivable	379	386
Operating lease right-of-use asset held for sale	2,226
Other current assets	1,681	1,821
Total current assets	9,905	8,704
Income taxes receivable, net of current portion	230	230
Asset for retirement benefits	1,393	0
Investments	937	980
Operating lease right-of-use assets	331
Property and equipment	76,560	72,522
Accumulated depletion, depreciation, and amortization	(66,034)	(64,134)
Property and equipment, net	10,526	8,388
Total assets	23,322	18,302
Current liabilities:
Accounts payable	1,109	1,223
Accrued capital expenditures	1,984	287
Accrued compensation	159	205
Accrued operating and other expenses	1,097	1,079
Operating lease liability held for sale	2,441
Current portion of operating lease liabilities	108
Current portion of asset retirement obligation	720	330
Other current liabilities	1,055	1,644
Total current liabilities	8,673	4,768
Deferred rent	0	193
Operating lease liabilities	230
Liability for retirement benefits	4,609	5,785
Asset retirement obligation	6,097	6,059
Deferred income tax liabilities	159	168
Total liabilities	19,768	16,973
Commitments and contingencies
Equity:
Common stock, par value $0.50 per share; authorized, 20,000,000 shares: 8,445,060 issued at December 31, 2019 and September 30, 2019	4,223	4,223
Additional paid-in capital	1,350	1,350
Retained earnings	445	859
Accumulated other comprehensive loss, net	(273)	(2,917)
Treasury stock, at cost: 167,900 shares at December 31, 2019 and September 30, 2019	(2,286)	(2,286)
Total stockholders' equity	3,459	1,229
Non-controlling interests	95	100
Total equity	3,554	1,329
Total liabilities and equity	$ 23,322	$ 18,302

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Parenthetical) - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Statement of Comprehensive Income [Abstract]
Foreign currency translation adjustments, taxes	$ 0	$ 0
Amortization of accumulated other comprehensive loss into net periodic benefit cost, taxes	0	0
Net actuarial gains arising during the period, taxes	0	0
Curtailment gain, taxes	$ 0	$ 0

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LEASES - ASSETS AND LIABILITIES (Details) $ in Thousands	Dec. 31, 2019 USD ($)
Leases [Abstract]
Operating lease right-of-use asset held for sale	$ 2,226
Operating lease right-of-use assets	331
Total right-of-use assets	2,557
Operating lease liability held for sale	2,441
Current portion of operating lease liabilities	108
Operating lease liabilities	230
Total lease liabilities	$ 2,779

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SEGMENT INFORMATION (Details) - USD ($)	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Revenues:
Revenue from contract with customer	$ 4,843,000	$ 2,574,000
Interest income	7,000	21,000
Total revenues	4,850,000	2,595,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	705,000	819,000
Asset Impairment Charges [Abstract]
Impairment of assets	0	2,170,000
Operating profit (loss) (before general and administrative expenses):
Operating profit (loss) (before general and administrative expenses):	1,111,000	(3,068,000)
Equity in income (loss) of affiliates:
Equity in loss of affiliates	(43,000)	(79,000)
General and administrative expenses	(1,496,000)	(1,548,000)
Interest expense	0	(4,000)
Interest income	7,000	21,000
Loss before income taxes	(421,000)	(4,678,000)
Oil and natural gas
Revenues:
Revenue from contract with customer	2,141,000	1,232,000
Total revenues	2,141,000	1,232,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	606,000	749,000
Asset Impairment Charges [Abstract]
Impairment of assets	0	2,170,000
Operating profit (loss) (before general and administrative expenses):
Operating profit (loss) (before general and administrative expenses):	322,000	(3,024,000)
Contract drilling
Revenues:
Revenue from contract with customer	2,646,000	1,163,000
Total revenues	2,646,000	1,163,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	85,000	57,000
Operating profit (loss) (before general and administrative expenses):
Operating profit (loss) (before general and administrative expenses):	747,000	(210,000)
Land investment
Revenues:
Revenue from contract with customer	0	165,000
Total revenues	0	165,000
Operating profit (loss) (before general and administrative expenses):
Operating profit (loss) (before general and administrative expenses):	0	165,000
Other
Revenues:
Revenue from contract with customer	56,000	14,000
Total revenues	63,000	35,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	14,000	13,000
Operating profit (loss) (before general and administrative expenses):
Operating profit (loss) (before general and administrative expenses):	42,000	$ 1,000
Intersegment eliminations
Revenues:
Total revenues	$ 0

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INVESTMENTS - SUMMARY OF REVENUES (Details) - Kaupulehu Developments - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Investment Holdings [Line Items]
Revenues - sale of interest in leasehold land	$ 0	$ 165
Fees - included in general and administrative expenses	0	(20)
Sale of interest in leasehold land, net of fees paid	$ 0	$ 145

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INCOME TAXES (Details) - USD ($) $ in Thousands	3 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Components of loss before income taxes, after adjusting the earnings (loss) for non-controlling interests
United States	$ (147)	$ (1,124)
Canada	(269)	(3,581)
Total	(416)	(4,705)
Components of the income tax provision (benefit)
Current	7	(33)
Deferred	(9)	(72)
Total	$ (2)	$ (105)

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LOSS PER COMMON SHARE (Tables)

3 Months Ended

Dec. 31, 2019

Earnings Per Share [Abstract]

Reconciliations between net earnings (loss) attributable to the entity's stockholders and common shares outstanding of the basic and diluted net earnings (loss) per share computations

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

	Three months ended December 31, 2019
	Net Loss (Numerator)			Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(414,000	)	8,277,160	$	(0.05	)
Effect of dilutive securities -
common stock options	—			—
Diluted net loss per share	$	(414,000	)	8,277,160	$	(0.05	)

	Three months ended December 31, 2018
	Net Loss (Numerator)			Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(4,600,000	)	8,277,160	$	(0.56	)
Effect of dilutive securities -
common stock options	—			—
Diluted net loss per share	$	(4,600,000	)	8,277,160	$	(0.56	)

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CONTINGENCIES

3 Months Ended

Dec. 31, 2019

Loss Contingency [Abstract]

CONTINGENCIES

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.

During the quarter ended December 31, 2019, the Company experienced the failure of a hole opener which broke apart leaving pieces in the bottom of the well.  If the Company is unable to overcome this impediment to completing the well it may have to abandon the well and drill a new well for which the potential exposure estimated to be incurred would range from $1,400,000 to $1,600,000.  Efforts to remove the items from the well are currently ongoing. No contingent liability has been recorded at December 31, 2019 as the likelihood of the Company needing to abandon the well and drill a new well is not probable.

In the year ended September 30, 2019, two of the water wells drilled by the contract drilling segment for one customer were determined to not meet the contract specifications for plumbness. Management believes the degrees of deviation for both wells are not impactful to the performance of the submersible pumps that will be installed in those wells. Accordingly, no contingent liability has been recorded at December 31, 2019 as the likelihood of any impact is not probable. However, per the contracts, both of which are with one customer, a failure to meet the contract plumbness specification allows the customer to demand the drilling of a new well at no cost to the customer as well as potential liquidated damages. If the customer makes such a demand, the potential exposure for both wells combined is estimated to range from $2,000,000 to $3,000,000. Negotiations with the customer are currently ongoing.

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REVENUE FROM CONTRACTS WITH CUSTOMERS (Tables)

3 Months Ended

Dec. 31, 2019

Revenue from Contract with Customer [Abstract]

Summary of disaggregation of revenue

The following tables provides information about disaggregated revenue by revenue streams, reportable segments, geographical region, and timing of revenue recognition for the three months ended December 31, 2019 and 2018.

		Three months ended December 31, 2019
		Oil and natural gas		Contract drilling		Land investment		Other		Total
Revenue streams:
	Oil	$	1,725,000	$	—	$	—	$	—	$	1,725,000
	Natural gas	322,000		—		—		—		322,000
	Natural gas liquids	94,000		—		—		—		94,000
	Drilling and pump	—		2,646,000		—		—		2,646,000
	Contingent residual payments	—		—		—		—		—
	Other	—		—		—		56,000		56,000
	Total revenues before interest income	$	2,141,000	$	2,646,000	$	—	$	56,000	$	4,843,000
Geographical regions:
	United States	$	—	$	2,646,000	$	—	$	7,000	$	2,653,000
	Canada	2,141,000		—		—		49,000		2,190,000
	Total revenues before interest income	$	2,141,000	$	2,646,000	$	—	$	56,000	$	4,843,000
Timing of revenue recognition:
	Goods transferred at a point in time	$	2,141,000	$	—	$	—	$	56,000	$	2,197,000
	Services transferred over time	—		2,646,000		—		—		2,646,000
	Total revenues before interest income	$	2,141,000	$	2,646,000	$	—	$	56,000	$	4,843,000

		Three months ended December 31, 2018
		Oil and natural gas		Contract drilling		Land investment		Other		Total
Revenue streams:
	Oil	$	896,000	$	—	$	—	$	—	$	896,000
	Natural gas	162,000		—		—		—		162,000
	Natural gas liquids	174,000		—		—		—		174,000
	Drilling and pump	—		1,163,000		—		—		1,163,000
	Contingent residual payments	—		—		165,000		—		165,000
	Other	—		—		—		14,000		14,000
	Total revenues before interest income	$	1,232,000	$	1,163,000	$	165,000	$	14,000	$	2,574,000
Geographical regions:
	United States	$	—	$	1,163,000	$	165,000	$	—	$	1,328,000
	Canada	1,232,000		—		—		14,000		1,246,000
	Total revenues before interest income	$	1,232,000	$	1,163,000	$	165,000	$	14,000	$	2,574,000
Timing of revenue recognition:
	Goods transferred at a point in time	$	1,232,000	$	—	$	165,000	$	14,000	$	1,411,000
	Services transferred over time	—		1,163,000		—		—		1,163,000
	Total revenues before interest income	$	1,232,000	$	1,163,000	$	165,000	$	14,000	$	2,574,000

Summary of contract with customer, asset and liability

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

	December 31, 2019		September 30, 2019
Accounts receivables from contracts with customers	$	2,862,000	$	1,322,000
Contract assets	551,000		344,000
Contract liabilities	1,043,000		1,633,000