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 June 30, 2018

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)

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 and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post 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 August 6, 2018 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 - June 30, 2018 and September 30, 2017	3
	Condensed Consolidated Statements of Operations - three and nine months ended June 30, 2018 and 2017	4
	Condensed Consolidated Statements of Comprehensive (Loss) Income - three and nine months ended June 30, 2018 and 2017	5
	Condensed Consolidated Statements of Equity - nine months ended June 30, 2018 and 2017	6
	Condensed Consolidated Statements of Cash Flows - nine months ended June 30, 2018 and 2017	7
	Notes to Condensed Consolidated Financial Statements	8
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	22
Item 4.	Controls and Procedures	36
PART II.	OTHER INFORMATION:
Item 6.	Exhibits	38
	Signature	39
	Index to Exhibits	40

PART I - FINANCIAL INFORMATION

ITEM 1.    FINANCIAL STATEMENTS

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	June 30, 2018			September 30, 2017
ASSETS
Current assets:
Cash and cash equivalents	$	13,539,000		$	16,281,000
Certificates of deposit	3,460,000			4,413,000
Accounts and other receivables, net of allowance for doubtful accounts of: $34,000 at June 30, 2018; $46,000 at September 30, 2017	1,414,000			1,414,000
Income taxes receivable	2,231,000			1,145,000
Investment held for sale	1,000,000			1,037,000
Other current assets	1,269,000			852,000
Total current assets	22,913,000			25,142,000
Income taxes receivable, net of current portion	460,000			—
Deferred income tax assets	—			300,000
Investments	1,695,000			2,209,000
Property and equipment	58,858,000			79,231,000
Accumulated depletion, depreciation, and amortization	(55,385,000		)	(73,862,000		)
Property and equipment, net	3,473,000			5,369,000
Total assets	$	28,541,000		$	33,020,000
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	1,158,000		$	1,185,000
Accrued capital expenditures	184,000			348,000
Accrued operating and other expenses	1,013,000			1,386,000
Accrued compensation	446,000			390,000
Current portion of asset retirement obligation	410,000			1,231,000
Other current liabilities	63,000			258,000
Total current liabilities	3,274,000			4,798,000
Deferred rent	86,000			21,000
Liability for retirement benefits	4,064,000			4,150,000
Asset retirement obligation	3,809,000			5,632,000
Deferred income tax liabilities	353,000			236,000
Total liabilities	11,586,000			14,837,000
Commitments and contingencies
Equity:
Common stock, par value $0.50 per share; authorized, 20,000,000 shares: 8,445,060 issued at June 30, 2018 and September 30, 2017	4,223,000			4,223,000
Additional paid-in capital	1,351,000			1,350,000
Retained earnings	14,311,000			15,023,000
Accumulated other comprehensive loss, net	(1,228,000		)	(1,058,000		)
Treasury stock, at cost: 167,900 shares at June 30, 2018 and September 30, 2017	(2,286,000		)	(2,286,000		)
Total stockholders' equity	16,371,000			17,252,000
Non-controlling interests	584,000			931,000
Total equity	16,955,000			18,183,000
Total liabilities and equity	$	28,541,000		$	33,020,000

See Notes to Condensed Consolidated Financial Statements

3

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

	Three months ended   June 30,						Nine months ended   June 30,
	2018			2017			2018			2017
Revenues:
Oil and natural gas	$	616,000		$	940,000		$	2,428,000		$	3,490,000
Contract drilling	1,193,000			360,000			3,051,000			3,346,000
Sale of interest in leasehold land	1,310,000			—			1,310,000			1,678,000
Gas processing and other	49,000			40,000			210,000			145,000
	3,168,000			1,340,000			6,999,000			8,659,000
Costs and expenses:
Oil and natural gas operating	544,000			620,000			1,777,000			2,266,000
Contract drilling operating	1,074,000			593,000			2,778,000			2,607,000
General and administrative	1,591,000			1,345,000			4,635,000			5,126,000
Depletion, depreciation, and amortization	187,000			234,000			694,000			942,000
Impairment of assets	165,000			—			202,000			—
Gain on sales of assets	—			(527,000		)	(2,250,000		)	(527,000		)
	3,561,000			2,265,000			7,836,000			10,414,000
Loss before equity in income (loss) of affiliates and income taxes	(393,000		)	(925,000		)	(837,000		)	(1,755,000		)
Equity in income (loss) of affiliates	136,000			(31,000		)	(97,000		)	2,125,000
(Loss) earnings before income taxes	(257,000		)	(956,000		)	(934,000		)	370,000
Income tax benefit	(163,000		)	(442,000		)	(469,000		)	(676,000		)
Net (loss) earnings	(94,000		)	(514,000		)	(465,000		)	1,046,000
Less: Net earnings (loss) attributable to non-controlling interests	280,000			(2,000		)	247,000			532,000
Net (loss) earnings attributable to Barnwell Industries, Inc.	$	(374,000	)	$	(512,000	)	$	(712,000	)	$	514,000
Basic and diluted net (loss) earnings per common share attributable to Barnwell Industries, Inc. stockholders	$	(0.05	)	$	(0.06	)	$	(0.09	)	$	0.06
Weighted-average number of common shares outstanding:
Basic and diluted	8,277,160			8,277,160			8,277,160			8,277,160

See Notes to Condensed Consolidated Financial Statements

4

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS) INCOME

(Unaudited)

	Three months ended   June 30,						Nine months ended   June 30,
	2018			2017			2018			2017
Net (loss) earnings	$	(94,000	)	$	(514,000	)	$	(465,000	)	$	1,046,000
Other comprehensive (loss) income:
Foreign currency translation adjustments, net of taxes of $0	(76,000		)	81,000			(263,000		)	33,000
Retirement plans - amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	30,000			51,000			93,000			244,000
Total other comprehensive (loss) income	(46,000		)	132,000			(170,000		)	277,000
Total comprehensive (loss) income	(140,000		)	(382,000		)	(635,000		)	1,323,000
Less: Comprehensive income (loss) attributable to non-controlling interests	280,000			(2,000		)	247,000			532,000
Comprehensive (loss) income attributable to Barnwell Industries, Inc.	$	(420,000	)	$	(380,000	)	$	(882,000	)	$	791,000

See Notes to Condensed Consolidated Financial Statements

5

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

Nine months endedJune 30, 2018 and 2017

(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, 2016	8,277,160	$	4,223,000	$	1,345,000	$	13,852,000		$	(3,920,000	)	$	(2,286,000	)	$	530,000		$	13,744,000
Contributions from non-controlling interests	—	—		—		—			—			—			6,000			6,000
Distributions to non-controlling interests	—	—		—		—			—			—			(617,000		)	(617,000		)
Net earnings	—	—		—		514,000			—			—			532,000			1,046,000
Share-based compensation	—	—		4,000		—			—			—			—			4,000
Foreign currency translation adjustments, net of taxes of $0	—	—		—		—			33,000			—			—			33,000
Retirement plans - amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	—	—		—		—			244,000			—			—			244,000
Balance at June 30, 2017	8,277,160	$	4,223,000	$	1,349,000	$	14,366,000		$	(3,643,000	)	$	(2,286,000	)	$	451,000		$	14,460,000
Balance at September 30, 2017	8,277,160	$	4,223,000	$	1,350,000	$	15,023,000		$	(1,058,000	)	$	(2,286,000	)	$	931,000		$	18,183,000
Distributions to non-controlling interests	—	—		—		—			—			—			(594,000		)	(594,000		)
Net loss (earnings)	—	—		—		(712,000		)	—			—			247,000			(465,000		)
Share-based compensation	—	—		1,000		—			—			—			—			1,000
Foreign currency translation adjustments, net of taxes of $0	—	—		—		—			(263,000		)	—			—			(263,000		)
Retirement plans - amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	—	—		—		—			93,000			—			—			93,000
Balance at June 30, 2018	8,277,160	$	4,223,000	$	1,351,000	$	14,311,000		$	(1,228,000	)	$	(2,286,000	)	$	584,000		$	16,955,000

See Notes to Condensed Consolidated Financial Statements

6

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Nine months ended   June 30,
	2018			2017
Cash flows from operating activities:
Net (loss) earnings	$	(465,000	)	$	1,046,000
Adjustments to reconcile net (loss) earnings to net cash
used in operating activities:
Equity in loss (income) of affiliates	97,000			(2,125,000		)
Depletion, depreciation, and amortization	694,000			942,000
Gain on sale of asset	—			(527,000		)
Gain on sale of oil and natural gas properties	(2,250,000		)	—
Impairment of assets	202,000			—
Distribution of income from equity investees	—			2,164,000
Retirement benefits expense	222,000			404,000
Income tax receivable	(460,000		)	—
Deferred rent liability	65,000			—
Accretion of asset retirement obligation	211,000			296,000
Deferred income tax expense	420,000			64,000
Asset retirement obligation payments	(589,000		)	(713,000		)
Share-based compensation (benefit) expense	(6,000		)	23,000
Retirement plan contributions and payments	(215,000		)	(359,000		)
Sale of interest in leasehold land, net of fees paid	(1,272,000		)	(1,418,000		)
Decrease from changes in current assets and liabilities	(975,000		)	(1,627,000		)
Net cash used in operating activities	(4,321,000		)	(1,830,000		)
Cash flows from investing activities:
Purchase of certificates of deposit	(3,958,000		)	(2,480,000		)
Proceeds from the maturity of certificates of deposit	4,911,000			—
Distribution from equity investees in excess of earnings	417,000			652,000
Net proceeds from sale of interest in leasehold land	929,000			1,418,000
Proceeds from the sale of assets, net of closing costs	—			2,360,000
Proceeds from sale of oil and natural gas assets	770,000			1,238,000
Capital expenditures - oil and natural gas	(473,000		)	(498,000		)
Capital expenditures - all other	(114,000		)	(120,000		)
Net cash provided by investing activities	2,482,000			2,570,000
Cash flows from financing activities:
Distributions to non-controlling interests	(594,000		)	(617,000		)
Contributions from non-controlling interests	—			6,000
Decrease in restricted cash	—			372,000
Net cash used in financing activities	(594,000		)	(239,000		)
Effect of exchange rate changes on cash and cash equivalents	(309,000		)	73,000
Net (decrease) increase in cash and cash equivalents	(2,742,000		)	574,000
Cash and cash equivalents at beginning of period	16,281,000			15,550,000
Cash and cash equivalents at end of period	$	13,539,000		$	16,124,000

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), a 75%-owned land investment partnership (KD Kona 2013 LLLP) and an 80%-owned joint venture (Kaupulehu 2007, LLLP). All significant intercompany accounts and transactions have been eliminated.

Barnwell’s investments in both unconsolidated entities in which a significant, but less than controlling, interest is held and in variable interest entities (“VIE”) in which the Company is not deemed to be the primary beneficiary are accounted for by the equity method.

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

Unaudited Interim Financial Information

The accompanying unaudited condensed consolidated financial statements and notes have been prepared by Barnwell in accordance with the rules and regulations of the United States (“U.S.”) Securities and Exchange Commission (“SEC”). 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, 2017 Annual Report on Form 10-K. The Condensed Consolidated Balance Sheet as of September 30, 2017 has been derived from audited consolidated financial statements.

In the opinion of management, all adjustments (which include only normal recurring adjustments) necessary to present fairly the financial position at June 30, 2018, results of operations and comprehensive (loss) income for the three and nine months ended June 30, 2018 and 2017, and equity and cash flows for the nine months ended June 30, 2018 and 2017, have been made. The results of operations for the period ended June 30, 2018 are not necessarily indicative of the operating results for the full year.

Use of Estimates

The preparation of the 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.

8

Significant Accounting Policies

There have been no changes to Barnwell’s significant accounting policies as described in the Notes to Consolidated Financial Statements included in Item 8 of the Company’s most recently filed Annual Report on Form 10-K.

Recently Adopted Accounting Pronouncements

In March 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-07, “Simplifying the Transition to the Equity Method of Accounting,” which eliminates the requirement that when an investment subsequently qualifies for use of the equity method as a result of an increase in level of ownership interest or degree of influence, an investor must adjust the investment, results of operations, and retained earnings retroactively on a step-by-step basis as if the equity method had been in effect during all previous periods that the investment had been held. This ASU requires that the equity method investor add the cost of acquiring the additional interest in the investee to the current basis of the investor’s previously held interest and to adopt the equity method of accounting as of the date the investment becomes qualified for equity method accounting. In addition, the ASU requires that an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized gain or loss in accumulated other comprehensive income at the date the investment becomes qualified for use of the equity method. The Company adopted the provisions of this ASU effective October 1, 2017. The adoption of this update did not have an impact on Barnwell’s consolidated financial statements.

In March 2016, the FASB issued ASU No. 2016-09, “Improvements to Employee Share-Based Payment Accounting,” which includes provisions intended to simplify various aspects related to how share-based payments are accounted for and presented in the financial statements. The Company adopted the provisions of this ASU effective October 1, 2017. The adoption of this update did not have an impact on Barnwell’s consolidated financial statements.

In October 2016, the FASB issued ASU No. 2016-17, “Interests Held through Related Parties That Are under Common Control,” which modifies existing guidance with respect to how a decision maker that holds an indirect interest in a VIE through a common control party determines whether it is the primary beneficiary of the VIE as part of the analysis of whether the VIE would need to be consolidated. Under this ASU, a decision maker would need to consider only its proportionate indirect interest in the VIE held through a common control party. The Company adopted the provisions of this ASU effective October 1, 2017. The adoption of this update did not have an impact on Barnwell’s consolidated financial statements.

2.    (LOSS) EARNINGS PER COMMON SHARE

Basic (loss) earnings per share is computed using the weighted-average number of common shares outstanding for the period. Diluted (loss) earnings 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) earnings per share if their effect is anti-dilutive.

Options to purchase 318,750 and 621,250 shares of common stock were excluded from the computation of diluted shares for the three and nine months ended June 30, 2018 and 2017, respectively, as their inclusion would have been antidilutive.

9

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

	Three months ended June 30, 2018
	Net Loss (Numerator)			Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(374,000	)	8,277,160	$	(0.05	)
Effect of dilutive securities -
common stock options	—			—
Diluted net loss per share	$	(374,000	)	8,277,160	$	(0.05	)

	Nine months ended June 30, 2018
	Net Loss (Numerator)			Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(712,000	)	8,277,160	$	(0.09	)
Effect of dilutive securities -
common stock options	—			—
Diluted net loss per share	$	(712,000	)	8,277,160	$	(0.09	)

	Three months ended June 30, 2017
	Net Loss (Numerator)			Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(512,000	)	8,277,160	$	(0.06	)
Effect of dilutive securities -
common stock options	—			—
Diluted net loss per share	$	(512,000	)	8,277,160	$	(0.06	)

	Nine months ended June 30, 2017
	Net Earnings (Numerator)		Shares (Denominator)	Per-Share Amount
Basic net earnings per share	$	514,000	8,277,160	$	0.06
Effect of dilutive securities -
common stock options	—		—
Diluted net earnings per share	$	514,000	8,277,160	$	0.06

3.    INVESTMENT HELD FOR SALE

At June 30, 2018, Kaupulehu 2007, LLLP owned one residential lot available for sale in the Lot 4A Increment I area located in the North Kona District of the island of Hawaii, north of Hualalai Resort at Historic Ka`upulehu, between the Queen Kaahumanu Highway and the Pacific Ocean.

10

In March 2018, Kaupulehu 2007, LLLP entered into a contract for the sale of the residential lot for net proceeds of $1,000,000. Accordingly, the lot's carrying value at March 31, 2018 was adjusted to the amount of the contract in escrow, and a $37,000 impairment of the value of the investment held for sale was recognized in the quarter ended March 31, 2018. The sale of the lot closed in August 2018 (see Note 13).

4.    INVESTMENTS

A summary of Barnwell’s investments is as follows:

	June 30, 2018		September 30, 2017
Investment in Kukio Resort Land Development Partnerships	$	1,645,000	$	2,159,000
Investment in leasehold land interest – Lot 4C	50,000		50,000
Total investments	$	1,695,000	$	2,209,000

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, 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, and KD II is the developer of Kaupulehu Lot 4A 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 as well as from commissions on real estate sales by the real estate sales office. As of June 30, 2018, 22 lots remained to be sold at Kaupulehu Increment I.

During the nine months ended June 30, 2018 and 2017, Barnwell received net cash distributions in the amount of $373,000 and $2,509,000, respectively, from the Kukio Resort Land Development Partnerships after distributing $44,000 and $307,000, respectively, to minority interests.

Barnwell's share of the operating results of its equity affiliates was income of $136,000 and a loss of $97,000 for the three and nine months ended June 30, 2018, respectively, and a loss of $31,000 and income of $2,125,000 for the three and nine months ended June 30, 2017, 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 $316,000 as of June 30, 2018, which is attributable to differences in the value of capitalized development costs and a note receivable. The basis difference is being recognized as the partnerships sell lots and recognize the associated costs and sell memberships for the Kuki`o Golf and Beach Club for which the receivable relates. The basis difference adjustments of $3,000and$6,000 for the three and nine months ended June 30, 2018, respectively, and $20,000 for the nine months ended June 30, 2017, increased equity in income of affiliates. There was no basis difference adjustment for the three months ended June 30, 2017.

11

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

	Three months ended June 30,
	2018		2017
Revenue	$	3,559,000	$	956,000
Gross profit	$	1,777,000	$	396,000
Net earnings	$	841,000	$	57,000

	Nine months ended June 30,
	2018		2017
Revenue	$	7,348,000	$	27,152,000
Gross profit	$	3,511,000	$	12,346,000
Net earnings	$	153,000	$	10,119,000

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 approximately 870 acres of the Kaupulehu Lot 4A area by KD I and KD II in two increments (“Increment I” and “Increment II”) (see Note 12).

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. During the three and nine months ended June 30, 2018, KD I sold one lot in Increment I for $3,100,000 and Kaupulehu Developments received a percentage of sales payment of $310,000. There were no Increment I percentage of sales payments received in the three and nine months ended June 30, 2017.

With respect to Increment II, Kaupulehu Developments is entitled to receive payments from KD II resulting from the sale of lots and/or residential units by KD II within Increment II. The payments are 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 the first was sold in fiscal 2016 and second was sold in fiscal 2017. Kaupulehu Developments received a percentage of sales payment of $1,678,000 from the sale of the second lot in the nine months ended June 30, 2017. The remaining acreage within Increment II is not yet under development. It is uncertain when or if KD II will develop the other areas of Increment II.

Kaupulehu Developments is 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. In fiscal 2017, the members of KD II received cumulative distributions equal to the original basis of capital invested in the project after which Barnwell received $2,500,000 from KD II representing an amount equal to 50% of the distributions KD II made to its members in September 2017, and an additional $1,000,000 was received from KD II in June 2018 under this arrangement, for a cumulative total of $3,500,000 received out of the $8,000,000 maximum. The $1,000,000 received in June 2018 is included in the table below. Kaupulehu Development incurred fees of $137,000 related to this payment which was included in "Accrued operating and other expenses" on the Company's Consolidated Balance Sheet at June 30, 2018 and was paid in July 2018.

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

	Three months ended   June 30,					Nine months ended   June 30,
	2018			2017		2018			2017
Sale of interest in leasehold land:
Revenues - sale of interest in leasehold land	$	1,310,000		$	—	$	1,310,000		$	1,678,000
Fees - included in general and administrative expenses	(175,000		)	—		(175,000		)	(260,000		)
Proceeds from sale of interest in leasehold land, net of fees paid	$	1,135,000		$	—	$	1,135,000		$	1,418,000

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. The lease terminates in December 2025. 

5.    OIL AND NATURAL GAS PROPERTIES AND ASSET RETIREMENT OBLIGATION

Full cost properties

In October 2017, Barnwell entered into a Purchase and Sale Agreement with an independent third party and sold its oil and natural gas properties located in the Pouce Coupe area of Alberta, Canada. The sales price per the agreement was adjusted to $79,000 for customary purchase price adjustments to reflect the economic activity from the effective date of May 1, 2017 to the closing date. From Barnwell's net proceeds, $37,000 was withheld and remitted by the buyer to the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes. No gain or loss was recognized on this sale as it did not result in a significant alteration of the relationship between capitalized costs and proved reserves. Proceeds from the disposition were credited to the full cost pool.

In February 2018, Barnwell sold its oil properties located in the Red Earth area of Alberta, Canada to two separate independent third parties. The sales prices per the agreements were adjusted for customary purchase price adjustments to reflect the economic activity from the effective date of October 1, 2017 to the closing date, for a combined adjusted sales price of $1,360,000. 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. From Barnwell's net proceeds, $752,000 was withheld and remitted by the buyer to the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes.

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The difference in the relationship between capitalized costs and proved reserves of the Red Earth properties sold as compared to the properties retained by Barnwell was significant as there was a 322% difference in capitalized costs divided by proved reserves if the gain was recorded versus the gain being credited against the full-cost pool. Accordingly, Barnwell recorded a gain on the sale of Red Earth of $2,135,000 in the three months ended March 31, 2018 in accordance with the guidance in Rule 4-10(c)(6)(i) of Regulation S-X of the rules and regulations of the SEC, which requires an allocation of capitalized costs to the reserves sold and reserves retained on the basis of the relative fair values of the properties as there was a substantial economic difference between the properties sold and those retained. Also included in the gain calculation were asset retirement obligations of $1,666,000 assumed by the purchaser.

Other properties

In February 2018, Barnwell sold its interest in natural gas transmission lines and related surface facilities in the Stolberg area of Alberta, Canada for $120,000, and we recognized a $115,000 gain on the sale for the quarter ended March 31, 2018.

Asset retirement obligation

Barnwell recognizes the fair value of a liability for an asset retirement obligation in the period in which it is incurred if a reasonable estimate of fair value can be made. The following is a reconciliation of the asset retirement obligation:

	Nine months
	ended
	June 30, 2018
Asset retirement obligation as of beginning of period	$	6,863,000
Obligation incurred on new well drilled	9,000
Liabilities associated with properties sold	(1,752,000		)
Revision of estimated obligation	(323,000		)
Accretion expense	211,000
Payments	(589,000		)
Foreign currency translation adjustment	(200,000		)
Asset retirement obligation as of end of period	4,219,000
Less current portion	(410,000		)
Asset retirement obligation, long-term	$	3,809,000

Asset retirement obligations were reduced by $1,752,000 during the nine months ended June 30, 2018 for those obligations that were assumed by purchasers of certain of Barnwell's oil and natural gas properties.

6.    RETIREMENT PLANS

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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 tables detail the components of net periodic benefit cost for Barnwell’s retirement plans:

	Pension Plan						SERP						Postretirement Medical
	Three months ended June 30,
	2018			2017			2018			2017			2018		2017
Service cost (credit)	$	54,000		$	34,000		$	10,000		$	(5,000	)	$	—	$	—
Interest cost	88,000			78,000			19,000			1,000			19,000		22,000
Expected return on plan assets	(147,000		)	(122,000		)	—			—			—		—
Amortization of prior service cost (credit)	2,000			2,000			(1,000		)	(2,000		)	—		—
Amortization of net actuarial loss	25,000			21,000			3,000			(17,000		)	2,000		47,000
Net periodic benefit cost	$	22,000		$	13,000		$	31,000		$	(23,000	)	$	21,000	$	69,000

	Pension Plan						SERP						Postretirement Medical
	Nine months ended June 30,
	2018			2017			2018			2017			2018		2017
Service cost	$	162,000		$	178,000		$	30,000		$	26,000		$	—	$	—
Interest cost	266,000			252,000			57,000			42,000			57,000		66,000
Expected return on plan assets	(443,000		)	(404,000		)	—			—			—		—
Amortization of prior service cost (credit)	5,000			4,000			(4,000		)	(4,000		)	—		—
Amortization of net actuarial loss	74,000			103,000			10,000			—			8,000		141,000
Net periodic benefit cost	$	64,000		$	133,000		$	93,000		$	64,000		$	65,000	$	207,000

Barnwell contributed $200,000 to the Pension Plan during the nine months ended June 30, 2018 and estimates that it will make further contributions of approximately $300,000 during the remainder of fiscal 2018. 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 2018 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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7.    INCOME TAXES

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

	Three months ended   June 30,						Nine months ended   June 30,
	2018			2017			2018			2017
United States	$	(12,000	)	$	(619,000	)	$	(2,137,000	)	$	792,000
Canada	(525,000		)	(335,000		)	956,000			(954,000		)
	$	(537,000	)	$	(954,000	)	$	(1,181,000	)	$	(162,000	)

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

	Three months ended   June 30,						Nine months ended   June 30,
	2018			2017			2018			2017
Current	$	(60,000	)	$	(392,000	)	$	(889,000	)	$	(740,000	)
Deferred	(103,000		)	(50,000		)	420,000			64,000
	$	(163,000	)	$	(442,000	)	$	(469,000	)	$	(676,000	)

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.

The Tax Cuts and Jobs Act of 2017 (“TCJA”), enacted on December 22, 2017, contains significant changes, including a reduction in the U.S. corporate income tax rate, repeal of the corporate Alternative Minimum Tax (“AMT”), restriction of the deduction for post-TCJA net operating losses to 80% of taxable income and elimination of net operating loss carrybacks, mandatory deemed repatriation and resulting taxation of all undistributed foreign earnings, as well as various other changes that either do not currently have a significant impact to the Company, or that may impact us in the future should those provisions become applicable to the Company. We believe our assessment of the estimated impacts of the TCJA is complete based on information available to date. However, the TCJA makes broad and complex changes to the U.S. tax code and is subject to interpretation until additional guidance is issued by taxation and financial reporting authorities. The ultimate impact of the TCJA may differ from our estimates due to changes in the interpretations and assumptions we used and changes in any future regulatory guidance.

The TCJA reduces the U.S. statutory tax rate from 35% to 21% effective January 1, 2018. The Company’s U.S. federal statutory rate for the fiscal year ending September 30, 2018 will be a blended rate of 24.5%, based on a fiscal year blended rate calculation of pre- and post-TJCA rates, and will be 21% for future fiscal years. There was no financial statement impact of the TCJA’s reduction in the U.S. statutory tax rate in the quarter ended December 31, 2017, as the Company has a full valuation allowance on its net deferred tax assets under U.S. federal tax law.

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The repeal of the corporate AMT provides a mechanism for the refund over time of any unused AMT credit carryovers. Prior to the enactment of the TCJA, it was not more likely than not that the Company’s AMT credit carryovers would provide a future benefit, as such the AMT deferred tax asset had a full valuation allowance. As a result of the new TCJA provision for refundability of the AMT, the Company recorded a current income tax benefit of $460,000 in the quarter ended December 31, 2017 to reflect the undiscounted unused AMT credit carryover balance as a non-current income tax receivable. Respective portions of this balance will be reclassified to current income taxes receivable when amounts are eligible for refund within one year of the balance sheet date.

The TCJA restricts the deduction for post-TCJA net operating losses to 80% of taxable income and eliminates the current net operating loss carryback provisions. The Company has determined that all existing pre-TCJA net operating loss carryovers are of sufficient magnitude and life such that they will fully shelter future reversals of U.S. federal deferred tax liabilities. As such, there was no financial statement impact of the TCJA’s changes to net operating losses in the quarter ended December 31, 2017.

The TCJA establishes mandatory deemed repatriation and resulting taxation of all post-1986 undistributed foreign earnings. As the Company’s Canadian operations consist of a U.S. corporate subsidiary operating as a branch in Canada and other minor, inactive Canadian corporate subsidiaries there was no impact from this provision.

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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   June 30,						Nine months ended   June 30,
	2018			2017			2018			2017
Revenues:
Oil and natural gas	$	616,000		$	940,000		$	2,428,000		$	3,490,000
Land investment	1,310,000			—			1,310,000			1,678,000
Contract drilling	1,193,000			360,000			3,051,000			3,346,000
Other	3,000			19,000			73,000			88,000
Total before interest income	3,122,000			1,319,000			6,862,000			8,602,000
Interest income	46,000			21,000			137,000			57,000
Total revenues	$	3,168,000		$	1,340,000		$	6,999,000		$	8,659,000
Depletion, depreciation, and amortization:
Oil and natural gas	$	121,000		$	145,000		$	477,000		$	672,000
Contract drilling	55,000			69,000			169,000			205,000
Other	11,000			20,000			48,000			65,000
Total depletion, depreciation, and amortization	$	187,000		$	234,000		$	694,000		$	942,000
Impairment:
Land investment	$	—		$	—		$	37,000		$	—
Other	165,000			—			165,000			—
Total impairment	$	165,000		$	—		$	202,000		$	—
Operating (loss) profit (before general and administrative expenses):
Oil and natural gas	$	(49,000	)	$	175,000		$	174,000		$	552,000
Land investment	1,310,000			—			1,273,000			1,678,000
Contract drilling	64,000			(302,000		)	104,000			534,000
Other	(173,000		)	(1,000		)	(140,000		)	23,000
Gain on sales of assets	—			527,000			2,250,000			527,000
Total operating profit	1,152,000			399,000			3,661,000			3,314,000
Equity in income (loss) of affiliates:
Land investment	136,000			(31,000		)	(97,000		)	2,125,000
General and administrative expenses	(1,591,000		)	(1,345,000		)	(4,635,000		)	(5,126,000		)
Interest income	46,000			21,000			137,000			57,000
(Loss) earnings before income taxes	$	(257,000	)	$	(956,000	)	$	(934,000	)	$	370,000

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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   June 30,						Nine months ended   June 30,
	2018			2017			2018			2017
Foreign currency translation:
Beginning accumulated foreign currency translation	$	866,000		$	858,000		$	1,053,000		$	906,000
Change in cumulative translation adjustment before reclassifications	(76,000		)	81,000			(263,000		)	33,000
Income taxes	—			—			—			—
Net current period other comprehensive (loss) income	(76,000		)	81,000			(263,000		)	33,000
Ending accumulated foreign currency translation	790,000			939,000			790,000			939,000
Retirement plans:
Beginning accumulated retirement plans benefit cost	(2,048,000		)	(4,633,000		)	(2,111,000		)	(4,826,000		)
Amortization of net actuarial loss and prior service cost	30,000			51,000			93,000			244,000
Income taxes	—			—			—			—
Net current period other comprehensive income	30,000			51,000			93,000			244,000
Ending accumulated retirement plans benefit cost	(2,018,000		)	(4,582,000		)	(2,018,000		)	(4,582,000		)
Accumulated other comprehensive loss, net of taxes	$	(1,228,000	)	$	(3,643,000	)	$	(1,228,000	)	$	(3,643,000	)

The amortization of accumulated other comprehensive loss components for the retirement plans are included in the computation of net periodic benefit cost which is a component of "General and administrative" expenses on the accompanying Condensed Consolidated Statements of Operations (see Note 6 for additional details).

10.    FAIR VALUE MEASUREMENTS

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

In March 2018, Kaupulehu 2007, LLLP entered into a contract for the sale of the residential lot for net proceeds of $1,000,000. Accordingly, the lot's carrying value at March 31, 2018 was adjusted to the amount of the contract currently in escrow, and a $37,000 impairment of the value of the investment held for sale was recognized in the quarter ended March 31, 2018. The sale of the lot closed in August 2018 (see Note 13).

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

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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. As further described in Note 5, the Company recognizes the fair value of a liability for an asset retirement obligation in the period in which it is incurred if a reasonable estimate of fair value can be made. Asset retirement obligations are not measured at fair value subsequent to initial recognition.

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

	Nine months ended   June 30,
	2018			2017
Supplemental disclosure of cash flow information:
Cash paid during the year for:
Interest	$	3,000		$	6,000
Income taxes refunded, net	$	(20,000	)	$	(137,000	)
Supplemental disclosure of non-cash investing activities:
Canadian income tax withholding on proceeds from the sale of oil and natural gas properties	$	789,000		$	—

Capital expenditure accruals related to oil and natural gas exploration and development decreased $152,000 and $199,000 during the nine months ended June 30, 2018 and 2017, respectively. Additionally, capital expenditure accruals related to oil and natural gas asset retirement obligations decreased $399,000 and $62,000 during the nine months ended June 30, 2018 and 2017, respectively.

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12.    RELATED PARTY TRANSACTIONS

Kaupulehu Developments is entitled to receive a percentage of the gross receipts from the sales of lots in Increment I from KD I and the sales of lots and/or residential units in Increment II from KD II. Kaupulehu Developments is 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 has been received to date (see Note 4). KD I and KD II are part of the Kukio Resort Land Development Partnerships in which Barnwell holds an indirect 19.6% non-controlling ownership interest accounted for under the equity method of investment. The percentage of sales payments and percent 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.

During the nine months ended June 30, 2018, Barnwell received $1,310,000 in payments, of which $1,000,000 was related to the 50% of distributions otherwise payable from KD II to its members after the members of KD II received distributions equal to the original basis of capital invested in the project, up to $8,000,000. The remaining $310,000 in payments was due to percentage of sales payments from KD I from the sale of one lot within Increment I. During the nine months ended June 30, 2017, Barnwell received $1,678,000 in percentage of sales payments from KD II from the sale of one lot within Increment II.

13.    SUBSEQUENT EVENTS

In July 2018, the Company entered into a Purchase and Sale Agreement with an independent third party for the purchase of interests in oil and natural gas properties located in the Twining area of Alberta, Canada. The purchase price for Barnwell's interests is approximately $10,500,000, at current Canadian dollar exchange rates, and is subject to customary adjustments to the purchase price at closing, including adjustments to reflect an effective date of sale of July 1, 2018. In accordance with the Purchase and Sale Agreement, Barnwell paid a non-refundable 5% deposit of approximately $525,000.

Certain of the assets which would be conveyed to the Company pursuant to the Purchase and Sale Agreement are subject to third parties' rights of first refusal. If one or more of such third parties exercises their rights of first refusal, the assets being transferred to the Company would be reduced as well as the purchase price to be paid by the Company.

The closing of the transaction is expected to occur in late August 2018. There is no assurance that the transaction will be successfully consummated.

In July 2018, Kaupulehu Developments received a percentage of sales payment of $165,000 from the sale of a lot within Phase II of Increment I. Financial results from the receipt of this payment will be reflected in Barnwell’s year ending September 30, 2018.

In August 2018, Kaupulehu 2007, LLLP, received net proceeds of $1,000,000 from the sale of the remaining residential lot available for sale in Lot 4A of Increment I. Financial results from the receipt of this payment will be reflected in Barnwell’s year ending September 30, 2018.

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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, 2017. 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.

Current Outlook

Due to the negative impacts of 1) declines in oil and natural gas production due primarily to oil and natural gas property divestitures as well as the natural decline oil and natural gas wells experience as they age; 2) declines in oil and natural gas prices (notwithstanding recent increases in oil prices); 3) increasing costs due to both inflation, the age of Barnwell's properties, increases in governmental regulation and other factors, Barnwell's existing oil and natural gas assets are projected to have negative cash flow from operations after consideration of related general and administrative expenses. As a result, the Company's current cash on hand will likely not be sufficient to fund both the reinvestments that are necessary to sustain our business in the future and our asset retirement obligations, retirement plan funding, and ongoing operating and general and administrative expenses. Therefore, it is likely that Barnwell will be increasingly reliant upon future land investment segment proceeds, if any, and future cash distributions, if any, from the Kukio Resort Land Development Partnerships, the timing of which are both highly uncertain and not within Barnwell’s control, to fund operations and provide capital for reinvestment. Additionally, the Company may need to consider alternative strategies to enable it to sustain or grow its business. If the Company is unable to make sufficient and successful investments in the near future, or if unforeseen circumstances arise that impair our ability to sustain or grow the Company, we will likely be forced to wind down our operations, either through liquidation, bankruptcy or further sales of our assets, and/or we may not be able to continue as a going concern beyond one year.

In July 2018, the Company entered into a Purchase and Sale Agreement with an independent third party for the purchase of interests in oil and natural gas properties located in the Twining area of Alberta,

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Canada. The purchase price for Barnwell's interests is approximately $10,500,000, at current Canadian dollar exchange rates, and is subject to customary adjustments to the purchase price at closing, including adjustments to reflect an effective date of sale of July 1, 2018. In accordance with the Purchase and Sale Agreement, Barnwell paid a non-refundable 5% deposit of approximately $525,000 to the independent third party seller. Certain of the assets which would be conveyed to the Company pursuant to the Purchase and Sale Agreement are subject to third parties’ rights of first refusal. If one or more of such third parties exercises their rights of first refusal, the assets being transferred to the Company would be reduced as well as the purchase price to be paid by the Company. The closing of the transaction is expected to occur in late August 2018. There is no assurance that the transaction will be successfully consummated.

If the Company successfully closes the Twining area transaction without significant exercises of rights of first refusal by third parties, oil and natural gas reserves, production and cash flows are expected to increase as a result of the acquisition of these new working interests in oil and natural gas properties. However, the use of a significant portion of the Company’s existing cash balance for this investment will generate the need for a significant amount of financing in the form of debt or equity in order to have the working capital necessary to make the capital expenditures needed for the oil and natural gas reserve levels and resulting oil and natural gas production and cash flows that would be sufficient to meet the Company’s ongoing cash needs in the absence of sufficient land investment segment cash inflows. In the absence of sufficient financing or other sources of funds, the Company may be forced to sell assets to meet its ongoing cash needs and may not be able to make the capital expenditures needed to maintain its oil and natural gas reserves, and the aforementioned concerns and unfavorable actions may become relevant and we may not be able to continue as a going concern beyond one year. There can be no assurance that our future financing actions will be successful. Management is not currently able to assess the likelihood or timing of raising capital for future expenditures or acquisitions.

Critical Accounting Policies and Estimates

Management has determined that our most critical accounting policies and estimates are those related to the evaluation of recoverability of assets, depletion of our oil and natural gas properties, income taxes and asset retirement obligation which are discussed in our Annual Report on Form 10-K for the fiscal year ended September 30, 2017. There have been no significant changes to these critical accounting policies and estimates during the three and nine months ended June 30, 2018. We continue to monitor our accounting policies to ensure proper application of current rules and regulations.

Impact of Recently Issued Accounting Standards on Future Filings

In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-09, “Revenue from Contracts with Customers (Topic 606),” which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. This ASU will replace most existing revenue recognition guidance in U.S. GAAP when it becomes effective. Subsequent to the issuance of ASU No. 2014-09, the FASB issued additional ASUs related to this revenue guidance. In March 2016, the FASB issued ASU No. 2016-08, “Principal versus Agent Considerations,” which is intended to improve the operability and understandability of the implementation guidance on principal versus agent considerations. In April 2016, the FASB issued ASU No. 2016-10, “Identifying Performance Obligations and Licensing,” which clarifies the implementation guidance on identifying performance obligations and licenses in customer contracts. In May 2016, the FASB issued ASU No. 2016-12, "Narrow-Scope Improvements and Practical Expedients," which addresses completed contracts and contract modifications at transition, noncash consideration, the presentation of sales taxes and other taxes collected from customers, and assessment of collectibility when determining whether a transaction

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represents a valid contract. In December 2016, the FASB issued ASU No. 2016-20, "Technical Corrections and Improvements to Topic 606," which includes thirteen technical corrections or improvements that affect only narrow aspects of the guidance in ASU No. 2014-09. ASU No. 2014-09 and all of the related ASUs (collectively, "Topic 606") have the same effective date. On July 9, 2015, the FASB deferred the effective date of Topic 606 for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. Topic 606 permits two methods of adoption: retrospectively to each prior reporting period presented, or the modified retrospective method with the cumulative effect of initially applying the guidance recognized at the date of initial application. Barnwell will adopt Topic 606 on October 1, 2018 and intends to apply the modified retrospective method of transition. Management is well underway in its process to assess the impact of Topic 606 on its financial accounting systems and financial statements of its revenue-earning business segments and continues to develop the changes necessary to implement Topic 606, but has not yet finalized the quantified impact adoption of Topic 606 will have on the consolidated financial statements.

In January 2016, the FASB issued ASU No. 2016-01, "Recognition and Measurement of Financial Assets and Financial Liabilities," which provides guidance for the recognition, measurement, presentation, and disclosure of financial assets and liabilities. The amendment is effective for annual reporting periods beginning after December 15, 2018 and interim periods within those annual periods. The adoption of this update is not expected to have a material impact on Barnwell’s consolidated financial statements.

In February 2016, the FASB issued ASU No. 2016-02, “Leases,” which seeks to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and by disclosing key information about leasing arrangements. In general, a right-of-use asset and lease obligation will be recorded for leases exceeding a twelve-month term whether operating or financing, while the income statement will reflect lease expense for operating leases and amortization/interest expense for financing leases. The balance sheet amount recorded for existing leases at the date of adoption must be calculated using the applicable incremental borrowing rate at the date of adoption. Subsequent to the issuance of ASU No. 2016-02, the FASB issued ASU No. 2018-01, "Land Easement Practical Expedient for Transition to Topic 842," which provides an optional transition practical expedient to not evaluate existing or expired land easements under the new lease standard and ASU No. 2018-10, "Clarifying Pre-Effective Amendments to the Forthcoming Lease Accounting Rules," which provides further clarification on certain guidance within ASU No. 2016-02, "Leases". These ASUs are effective for annual reporting periods beginning after December 15, 2018, and interim periods within those annual periods, and require the use of the modified retrospective method, which will require adjustment to all comparative periods presented in the consolidated financial statements. Barnwell is currently evaluating the effect that the adoption of this update will have on the consolidated financial statements.

In August 2016, the FASB issued ASU No. 2016-15, “Classification of Certain Cash Receipts and Cash Payments,” which addresses the classification of certain specific cash flow issues including debt prepayment or extinguishment costs, settlement of certain debt instruments, contingent consideration payments made after a business combination, proceeds from the settlement of certain insurance claims and distributions received from equity method investees. The guidance is effective for annual reporting periods beginning after December 15, 2017 and interim periods within those annual periods. Early adoption is permitted, provided that all of the amendments are adopted in the same period. The adoption of this update is not expected to have a material impact on Barnwell’s consolidated financial statements.

In October 2016, the FASB issued ASU No. 2016-16, “Intra-Entity Transfers of Assets Other Than Inventory,” which provides guidance on recognition of current income tax consequences for intra-entity asset transfers (other than inventory) at the time of transfer. This represents a change from current GAAP, where

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the consolidated tax consequences of intra-entity asset transfers are deferred until the transferred asset is sold to a third party or otherwise recovered through use. The guidance is effective for annual reporting periods beginning after December 15, 2017 and interim periods within those annual periods. Early adoption at the beginning of an annual period is permitted. The adoption of this update is not expected to have a material impact on Barnwell’s consolidated financial statements.

In November 2016, the FASB issued ASU No. 2016-18, "Statement of Cash Flows - Restricted Cash," which requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents and amounts generally described as restricted cash or restricted cash equivalents. Thus, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and the end-of-period total amounts set forth on the statement of cash flows. This ASU is effective for annual reporting periods beginning after December 15, 2017 and interim periods within those annual periods. The amendments should be applied using a retrospective transition method to each period presented. The adoption of this update will impact the presentation of the cash flow statements if Barnwell has restricted cash at the time of adoption.

In February 2017, the FASB issued ASU No. 2017-05, “Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets,” which clarifies the scope of Subtopic 610-20 and adds guidance for partial sales of nonfinancial assets. ASU No. 2017-05 is effective at the same time as the revenue standard in ASU No. 2014-09, “Revenue from Contracts with Customers” goes into effect, which is annual reporting periods beginning after December 15, 2017 and interim periods within those annual periods. The adoption of this update is not expected to have a material impact on Barnwell’s consolidated financial statements.

In March 2017, the FASB issued ASU No. 2017-07, “Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” which requires employers to report the service cost component separate from the other components of net pension benefit costs. The changes to the standard require employers to report the service cost component in the same line item as other compensation costs arising from services rendered by employees during the reporting period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside the subtotal of income from operations, if one is presented. If a separate line item is not used, the line item used in the income statement must be disclosed. This ASU is effective for interim and annual reporting periods beginning after December 15, 2017. The adoption of this update will impact the presentation and disclosure of net pension benefit costs.

In May 2017, the FASB issued ASU No. 2017-09, “Stock Compensation - Scope of Modification Accounting,” which provides clarification on when modification accounting should be used for changes to the terms or conditions of a share-based payment award. This ASU is effective for interim and annual reporting periods beginning after December 15, 2017, with early adoption permitted. The adoption of this update is not expected to have a material impact on Barnwell’s consolidated financial statements.

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 TCJA. This ASU is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted. The adoption of this update is not expected to have a material impact on Barnwell's consolidated financial statements.

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In July 2018, the FASB issued ASU No. 2018-09, "Codification Improvements," which provides further clarification to the codification literature. The transition and effective date guidance is based on the facts and circumstances of each amendment within the ASU. Some of the amendments in the ASU do not require transition guidance and will be effective upon issuance of the ASU. Other amendments have transition guidance with effective dates for annual reporting periods beginning after December 15, 2018. The adoption of this update is not expected to have a material impact on Barnwell's consolidated financial statements.

Overview

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

Oil and Natural Gas Segment

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

Land Investment Segment

The land investment segment is comprised of the following components:

1)   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 Acquisition, LLLP ("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. Increment I is an area zoned for approximately 80 single-family lots, of which 22 remained to be sold at June 30, 2018, and a beach club on the portion of the property bordering the Pacific Ocean, and is partially developed.

• The right to receive percentage of sales payments from KD Acquisition II, LLLP ("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 is 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,of which $3,500,000 has been received to date. 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 the remaining acreage within Increment II is not yet under development.

• An indirect 19.6% non-controlling ownership interest in the Kukio Resort Land Development Partnerships which is comprised of KD Kukio Resorts, LLLP, KD Maniniowali, LLLP and KD

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Kaupulehu, LLLP. 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. KD Kaupulehu, LLLP, which wholly owns KD I and KD II discussed above, is the developer of Kaupulehu Lot 4A Increments I and II, the area in which Barnwell has interests in percentage of sales payments and percentage of future distributions to KD II's members. 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. As of June 30, 2018, 22 lots remained to be sold at Kaupulehu Increment 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.

2)   Barnwell owns an 80% interest in Kaupulehu 2007, LLLP (“Kaupulehu 2007”), a Hawaii limited liability limited partnership. Kaupulehu 2007 owned one residential parcel in the Kaupulehu area that was available for sale as of June 30, 2018. The residential parcel was sold in August 2018 (see Note 13 of the Notes to our Condensed Consolidated Financial Statements).

Contract Drilling Segment

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

Results of Operations

Summary

Net loss attributable to Barnwell for the three months ended June 30, 2018 totaled $374,000, a $138,000increase in operating results from net loss of $512,000 for the three months ended June 30, 2017.The following factors affected the results of operations for the three months ended June 30, 2018 as compared to the prior year period:

• A $224,000decrease in oil and natural gas segment operating results, before income taxes, due primarily to a decrease in oil and natural gas production due to sales of oil and natural gas properties in past periods;

• A $366,000increase in contract drilling operating results, before income taxes, primarily due to losses in the prior year period on certain water well drilling contracts due to unforeseen difficulties such as significant geological formation issues and well wall subsidences;

• $1,310,000 in land investment segment revenues, before income taxes, in the current period as compared to none in the prior year period;

• A $172,000decrease in other operating results, due primarily to a $165,000 write-off of land inundated by the Kilauea volcano eruption that began in May 2018;

• A $246,000increase in general and administrative expenses primarily related to fees associated with the increase in land investment segment revenues; and

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• A $527,000 gain on sale in the prior year period due to the sale of the New York office in May 2017. There was no such gain during the three months ended June 30, 2018.

Barnwell had a net loss of $712,000 for the nine months ended June 30, 2018, a $1,226,000decrease in operating results from net earnings of $514,000 for the nine months ended June 30, 2017. The following factors affected the results of operations for the nine months ended June 30, 2018 as compared to the prior year period:

• A $378,000decrease in oil and natural gas segment operating results, before income taxes, due primarily to the decreased oil and natural gas production due to sales of oil and natural gas properties in the current year period;

• A $430,000decrease in contract drilling operating results, before income taxes, primarily due to a high value contract in the prior year period for the plugging and abandonment of two geothermal wells;

• A $405,000decrease in land investment segment operating profit, before income taxes and non-controlling interests’ share of such profits;

• A $491,000decrease in general and administrative expenses primarily as a result of decreased compensation costs and professional fees;

• A $2,250,000gain recognized in the current year primarily from the sale of oil properties in the Red Earth area of Alberta, Canada compared to a $527,000 gain recognized in the prior year period due to the sale of the New York office in May 2017; and

• A $2,222,000decrease in equity in income from affiliates as a result of decreased Kukio Resort Land Development Partnerships’ operating results.

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 increased4% and 5% in the three and nine months ended June 30, 2018, respectively, as compared to the same periods in the prior year. The exchange rate of the Canadian dollar to the U.S. dollar decreased5% at June 30, 2018, as compared to September 30, 2017. Accordingly, the assets, liabilities, stockholders’ equity and revenues and expenses of Barnwell’s subsidiaries operating in Canada have been adjusted to reflect the change in the exchange rates. Barnwell’s Canadian dollar assets are greater than its Canadian dollar liabilities; therefore, increases or decreases in the value of the Canadian dollar to the U.S. dollar generate other comprehensive income or loss, respectively. Other comprehensive income and losses are not included in net (loss) earnings. Other comprehensive loss due to foreign currency translation adjustments, net of taxes, for the three months ended June 30, 2018 was $76,000, a $157,000 change from other comprehensive income due to foreign currency translation adjustments, net of taxes, of $81,000 for the same period in the prior year. Other comprehensive

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loss due to foreign currency translation adjustments, net of taxes, for the nine months ended June 30, 2018 was $263,000, a $296,000 change from other comprehensive income due to foreign currency translation adjustments, net of taxes, of $33,000 for the same period in the prior year. There were no taxes on other comprehensive loss or income due to foreign currency translation adjustments in the three and nine months ended June 30, 2018 and 2017 due to a full valuation allowance on the related deferred tax asset.

Oil and natural gas

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

	Average Price Per Unit
	Three months ended				Increase
	June 30,				(Decrease)
	2018		2017		$			%
Natural Gas (Mcf)*	$	0.72	$	1.84	$	(1.12	)	(61	%)
Oil (Bbls)**	$	55.20	$	39.05	$	16.15		41	%
Liquids (Bbls)**	$	44.00	$	28.00	$	16.00		57	%

	Average Price Per Unit
	Nine months ended				Increase
	June 30,				(Decrease)
	2018		2017		$			%
Natural Gas (Mcf)*	$	1.24	$	2.14	$	(0.90	)	(42	%)
Oil (Bbls)**	$	49.74	$	40.86	$	8.88		22	%
Liquids (Bbls)**	$	42.32	$	29.13	$	13.19		45	%

	Net Production
	Three months ended		Increase
	June 30,		(Decrease)
	2018	2017	Units		%
Natural Gas (Mcf)*	67,000	90,000	(23,000	)	(26	%)
Oil (Bbls)**	10,000	19,000	(9,000	)	(47	%)
Liquids (Bbls)**	1,000	1,000	—		—	%

	Net Production
	Nine months ended		Increase
	June 30,		(Decrease)
	2018	2017	Units		%
Natural Gas (Mcf)*	220,000	293,000	(73,000	)	(25	%)
Oil (Bbls)**	41,000	64,000	(23,000	)	(36	%)
Liquids (Bbls)**	3,000	3,000	—		—	%

_______________________________________

*            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

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The oil and natural gas segment generated $49,000 of operating loss before general and administrative expenses in the three months ended June 30, 2018, a decrease in operating results of $224,000 as compared to the $175,000 operating profit before general and administrative expenses generated during the same period of the prior year. The oil and natural gas segment generated $174,000 of operating profit before general and administrative expenses in the nine months ended June 30, 2018, a decrease in operating results of $378,000 as compared to the $552,000 operating profit before general and administrative expenses generated during the same period of the prior year.

Oil and natural gas revenues decreased $324,000 (34%) and $1,062,000 (30%) for the three and ninemonths ended June 30, 2018, respectively, as compared to the same periods in the prior year, primarily due to decreased oil and natural gas production due to sales of oil and natural gas properties as well as production downtime and shut-ins at various properties that we do not operate, and a decrease in natural gas prices. The impact of the decreases in production and lower natural gas prices were partially offset by higher oil prices for the three and nine months ended June 30, 2018 as compared to the same periods in the prior year.

Oil and natural gas operating expenses decreased $76,000 (12%) and $489,000 (22%) for the three and nine months ended June 30, 2018, respectively, as compared to the same periods in the prior year, primarily as a result of decreased production as described above. Partially offsetting the decrease was the fact that oil and natural gas operating expenses in the prior year periods included equalization credits for previously allocated operating expenses received from non-operated properties and a reduction in the estimated probable remediation costs for a gas migration at one of our non-operated wells for which approximately $200,000 was originally accrued in the prior year quarter and was adjusted down to approximately $23,000 based on updated information from the operator.

Sale of interest in leasehold land

Kaupulehu Developments is entitled to receive percentage of sales payments from the sales of lots in Increment I from KD I and the sales of lots and/or residential units in Increment II from KD II. Kaupulehu Developments also is 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 has been received to date. KD I and KD II are land development partnerships in which Barnwell holds an indirect 19.6% non-controlling ownership interest 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.

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

	Three months ended   June 30,					Nine months ended   June 30,
	2018			2017		2018			2017
Sale of interest in leasehold land:
Revenues - sale of interest in leasehold land	$	1,310,000		$	—	$	1,310,000		$	1,678,000
Fees - included in general and administrative expenses	(175,000		)	—		(175,000		)	(260,000		)
Proceeds from the sale of interest in leasehold land, net of fees paid	$	1,135,000		$	—	$	1,135,000		$	1,418,000

The Kukio Resort Land Development Partnerships had one lot sale during the three and nine months ended June 30, 2018 and Kaupulehu Developments received a percentage of sales payment in the amount of $310,000 from KD I. In the three and nine months ended June 20, 3018, Kaupulehu Developments received $1,000,000 from KD II which represented an amount equal to 50% of the distributions otherwise payable from KD II to its members after the members of KD II received distributions equal to the original basis of capital invested in the project, up to $8,000,000. During the nine months ended June 30, 2017, KD II sold the second of two large ocean front lots within Increment II for $20,975,000 and Kaupulehu Developments received a percentage of sales payment in the amount of $1,678,000 from KD II representing 8% of the gross sales price of the parcel.

As of June 30, 2018, 22 single-family lots of the 80 lots developed within Increment I remained to be sold. The current remaining acreage within Increment II is not yet under development. It is uncertain when or if KD II will develop the other areas of Increment II, and there is no assurance with regards to the amounts of future sales from Increments I and II.

Contract drilling

Contract drilling revenues increased$833,000 (231%) and contract drilling costs increased$481,000 (81%) for the three months ended June 30, 2018, as compared to the same period in the prior year. The contract drilling segment generated a $64,000 operating profit before general and administrative expenses in the three months ended June 30, 2018, an increase in operating results of $366,000 as compared to the $302,000 operating loss generated during the same period of the prior year.

Contract drilling revenues decreased$295,000 (9%) and contract drilling costs increased$171,000 (7%), respectively, for the nine months ended June 30, 2018, as compared to the same period in the prior year. The contract drilling segment generated a $104,000 operating profit before general and administrative expenses in the nine months ended June 30, 2018, a decrease in operating results of $430,000 as compared to the $534,000 operating profit generated during the same period of the prior year.

The increase in operating results for the three months ended June 30, 2018 as compared to the same period in the prior year was primarily due to losses during the three months ended June 30, 2017 on certain water well drilling contracts due to unforeseen difficulties such as geological formation issues and well wall subsidences. The decrease in operating results for the nine months ended June 30, 2018 as compared to the prior year period was primarily due to work on a higher value contract in the prior year period for the plugging and abandonment of two geothermal wells which was completed as of June 30, 2017. The operating profit

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in the prior year period from this higher value contract was partially offset by losses on certain water well drilling contracts due to unforeseen difficulties as mentioned above.

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.

General and administrative expenses

General and administrative expenses increased$246,000 (18%) for the three months ended June 30, 2018, as compared to the same period in the prior year. The increase was due primarily to a $41,000 increase in compensation costs resulting from an increase in stock appreciation rights, and an increase of $175,000 in professional fees related to the land investment segment proceeds received in the current year period.

General and administrative expenses decreased$491,000 (10%) for the nine months ended June 30, 2018, as compared to the same period in the prior year. The decrease was primarily due to a $379,000 decrease in compensation costs resulting from a decrease in retirement plan expenses, executive bonuses, and stock appreciation rights, a decrease of $85,000 in professional fees related to lower land investment segment proceeds received in the current year period, and a decrease in costs associated with Barnwell's New York office, which was sold in May 2017.

Depletion, depreciation, and amortization

Depletion, depreciation, and amortization decreased$47,000 (20%) and $248,000 (26%) for the three and nine months ended June 30, 2018, respectively, as compared to the same periods in the prior year, due to decreases in production and the impact of oil and natural gas property sales on the depletion rate in the current year periods. This decrease was partially offset by an increase in the depletion rate for the three and nine months ended June 30, 2018. The depletion rate increased due to a significant decrease in estimated natural gas reserve volumes resulting from the impact of a decline in natural gas prices and a continuing poor outlook for natural gas prices, which in turn has made the future production of natural gas reserves uneconomic at certain of the Company's properties.

Impairment of assets

Impairment of assets was $165,000 and $202,000 for the three and nine months ended June 30, 2018, respectively. There was no impairment of assets for the three and nine months ended June 30, 2017.

In May 2018, the Kilauea volcano on the island of Hawaii erupted in the district of Puna on the eastern part of the island. Lava flows subsequently covered all of the approximately sixteen acres of land in the district of Puna that Barnwell owns. As a result, Barnwell wrote off the entire $165,000 carrying value of the sixteen acres during the three months ended June 30, 2018.

In March 2018, Kaupulehu 2007, LLLP entered into a contract for the sale of the residential lot for net proceeds of $1,000,000. Accordingly, the lot's carrying value at March 31, 2018 was adjusted to the amount of the contract that was in escrow at that time, and a $37,000 impairment of the value of the investment held for sale was recognized in the nine months ended June 30, 2018.

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Gain on sales of assets

As a result of the significant impact the sale of Red Earth had on the relationship between capitalized costs and proved reserves of the sold property and retained properties, Barnwell did not credit the sales proceeds to the full cost pool, but instead calculated a gain on the sale of Red Earth of $2,135,000 which was recognized in the quarter ended March 31, 2018, in accordance with the guidance in Rule 4-10(c)(6)(i) of Regulation S-X of the rules and regulations of the SEC. Refer to the "Oil and Natural Gas Properties" section below for further information.

Also included in gain on sales of assets for the quarter ended March 31, 2018 is a $115,000 gain on the sale of Barnwell's interest in natural gas transmission lines and related surface facilities in the Stolberg area of Alberta, Canada in February 2018.

During the nine months ended June 30, 2017, the Company's New York office was sold for approximately $2,360,000, net of related costs, resulting in a gain of $527,000, which was recognized in the quarter ended June 30, 2017.

Equity in income (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 income of $136,000 during the three months ended June 30, 2018, as compared to allocated losses of $31,000 during the three months ended June 30, 2017. The allocated income for the three months ended June 30, 2018 was due to one lot sale in Increment I, whereas there were no lots sold during the three months ended June 30, 2017.

Barnwell was allocated partnership losses of $97,000 during the nine months ended June 30, 2018, as compared to allocated income of $2,125,000 during the nine months ended June 30, 2017. The decrease in the allocated partnership income is due to the investee partnerships' sale of the second of two large ocean front parcels in Kaupulehu Increment II for $20,975,000 in December 2016.

Income taxes

Barnwell’s effective consolidated income tax rate for the three and nine months ended June 30, 2018, after adjusting (loss) earnings before income taxes for non-controlling interests, was 30% and 40%, respectively, as compared to 46% and 417% for the three and nine months ended June 30, 2017, respectively. 

Consolidated taxes do not bear a customary relationship to pretax results due primarily to the fact that the Company is taxed separately in Canada based on Canadian source operations and in the U.S. based on consolidated operations, and essentially all deferred tax assets, net of relevant offsetting deferred tax liabilities 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.

The Tax Cuts and Jobs Act ("TCJA") was enacted on December 22, 2017. The TCJA includes various changes to the tax law, including a permanent reduction in the U.S. corporate income tax rate from 35% to 21% effective January 1, 2018 and a repeal of the corporate alternative minimum tax ("AMT"). The Company’s U.S. federal statutory rate for the fiscal year ending September 30, 2018 will be a blended rate

33

of 24.5%, based on a fiscal year blended rate calculation of pre- and post-TJCA rates, and will be 21% for future fiscal years. There was no financial statement impact of the TCJA’s reduction in the U.S. statutory tax rate in the nine months ended June 30, 2018 as the Company has a full valuation allowance on its net deferred tax assets under U.S. federal tax law. The repeal of the corporate AMT provides a mechanism for the refund over time of any unused AMT credit carryovers. Prior to the enactment of the TCJA, it was not more likely than not that the Company’s AMT credit carryovers would provide a future benefit, as such the AMT deferred tax asset had a full valuation allowance. As a result of the new TCJA provision for refundability of the AMT, the Company recorded a current income tax benefit of $460,000 in the nine months ended June 30, 2018.

We believe our assessment of the estimated impacts of the TCJA is complete based on information available to date. However, the TCJA makes broad and complex changes to the U.S. tax code and is subject to interpretation until additional guidance is issued by taxation and financial reporting authorities. The ultimate impact of the TCJA may differ from our estimates due to changes in the interpretations and assumptions we used and changes in any future regulatory guidance.

Net earnings (loss) attributable to non-controlling interests

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

Net earnings attributable to non-controlling interests for the three months ended June 30, 2018 totaled $280,000, as compared to net loss attributable to non-controlling interests of $2,000 for the same period in the prior year. The $282,000 increase is due primarily to an increase in land investment segment proceeds received and Kukio Land Development Partnership income allocated to non-controlling interests in the current year period as compared to the same period in the prior year.

Net earnings attributable to non-controlling interests for the nine months ended June 30, 2018 totaled $247,000, as compared to net earnings attributable to non-controlling interests of $532,000 for the same period in the prior year. The decrease of $285,000 is due to a decrease in land investment segment proceeds received and Kukio Land Development Partnership operating results in the current year period as compared to the same period in the prior year.

Liquidity and Capital Resources

Barnwell’s primary sources of liquidity are cash on hand and land investment segment proceeds. At June 30, 2018, Barnwell had $19,639,000 in working capital.

Cash Flows

Cash flows used in operations totaled $4,321,000 for the nine months ended June 30, 2018, as compared to cash flows used in operations of $1,830,000 for the same period in the prior year. The following factors affected the $2,491,000decrease in operating cash flows for the nine months ended June 30, 2018, as compared to the prior year:

• A $2,164,000 distribution of income received from the Kukio Resort Land Development Partnerships in the prior year period whereas there was no such distribution in the current year period;

34

• Decreases in oil and natural gas and contract drilling margins before depreciation and income taxes, respectively. The oil and natural gas margin decreased primarily due to the decreased oil and natural gas production due to sales of oil and natural gas properties. The contract drilling margin decreased primarily due to a high value contract in the prior year period for the plugging and abandonment of two geothermal wells, whereas there was no such high value contract in the current year period; and

• The impacts above were partially offset by a lower decrease from changes in working capital in the current year period compared to the prior year period.

Cash flows provided by investing activities totaled $2,482,000 during the nine months ended June 30, 2018, as compared to cash flows provided by investing activities of $2,570,000 during the same period of the prior year. The $88,000decrease in investing cash flows was primarily due to a $235,000 decrease in the distribution of capital received from the Kukio Resort Land Development Partnerships received in the current year period as compared to the prior year period, a $489,000 decrease in percentage of sales proceeds received, net of commission fees paid, in the current year period as compared to the prior year period, a $2,360,000 decrease in net proceeds from the sale of assets due to the New York office being sold in the prior year period, and a $468,000 decrease in net proceeds from the sale of certain oil and natural gas properties in the current year period compared to the prior year period. These items were partially offset an increase of $3,433,000 in net proceeds from certificates of deposit in the current year period compared to the prior year period.

Net cash used in financing activities totaled $594,000 for the nine months ended June 30, 2018, as compared to $239,000 during the same period of the prior year. The $355,000 change in financing cash flowswas due to a $23,000 decrease in distributions to non-controlling interests in the current year period as compared to the prior year period, and a $372,000 release of restricted cash during 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 $121,000 and $321,000 for the three and nine months ended June 30, 2018, respectively, as compared to $35,000 and $299,000 for the same periods in the prior year. Barnwell expects to make approximately $10,500,000 in investments in oil and natural gas properties for the remainder of fiscal 2018 (see Note 13 of the Notes to our Condensed Consolidated Financial Statements). This estimate may change depending on whether or not third parties exercise their rights of first refusal related to Barnwell's purchase of interest in oil and natural gas properties located in the Twining area of Alberta, Canada, and as dictated by management’s assessment of the oil and natural gas environment and prospects.

Oil and Natural Gas Properties

In October 2017, Barnwell entered into a Purchase and Sale Agreement with an independent third party and sold its oil and natural gas properties located in the Pouce Coupe area of Alberta, Canada. The sales price per the agreement was adjusted to $79,000 for customary purchase price adjustments to reflect the economic activity from the effective date of May 1, 2017 to the closing date. From Barnwell's net proceeds, $37,000 was withheld and remitted by the buyer to the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes.

35

In February 2018, Barnwell sold its oil properties located in the Red Earth area of Alberta, Canada to two separate independent third parties. The sales prices per the agreements were adjusted for customary purchase price adjustments to reflect the economic activity from the effective date of October 1, 2017 to the closing date, for a combined adjusted sales price of $1,360,000. The final determination of the customary adjustments to the purchase price has not yet been made, however it is not expected to result in a material adjustment. Barnwell recorded a gain on the sale of Red Earth of $2,135,000 in the quarter ended March 31, 2018, which included asset retirement obligations of $1,666,000 assumed by the purchaser. From Barnwell's net proceeds, $752,000 was withheld and remitted by the buyer to the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes. Net oil production from these properties was approximately 23,000 Bbls, or approximately 16% of total net production, for the year ended September 30, 2017. As of September 30, 2017, estimated net proved oil reserve volumes associated with these properties was 104,000 Bbls, or approximately 11% of the total reserve volumes at that date.

In July 2018, the Company entered into a Purchase and Sale Agreement with an independent third party for the purchase of interests in oil and natural gas properties located in the Twining area of Alberta, Canada. The purchase price for Barnwell's interests is approximately $10,500,000 and is subject to customary adjustment to the purchase price at closing. Certain of the assets which would be conveyed to the Company pursuant to the Purchase and Sales Agreement are subject to third parties' rights of first refusal. If one or more of such third parties exercises their rights of first refusal, the assets being transferred to the Company would be reduced as well as the purchase price to be paid by the Company (see Note 13 of the Notes to our Condensed Consolidated Financial Statements). 

Asset Retirement Obligation

In July 2014, the Alberta Energy Regulator introduced an Inactive Well Compliance Program which resulted in the acceleration of expenditures to reactivate, suspend and/or abandon long-term inactive wells. Under the program all inactive wells that were non-compliant as of April 1, 2015 need to be brought into compliance by the operator within five years, in increments of not less than 20 percent per year. Barnwell has only two remaining wells to bring into compliance over the final two years of the program. The impact of this program was incorporated into Barnwell's estimate of its asset retirement obligations beginning in fiscal 2014. At June 30, 2018, the current portion of the asset retirement obligation was $410,000.

ITEM 4.    CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

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

As of June 30, 2018, an evaluation was carried out by Barnwell’s Chief Executive Officer and Chief Financial Officer of the effectiveness of Barnwell’s disclosure controls and procedures. Based on that evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that Barnwell’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) were effective as of June 30, 2018 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.

36

Changes in Internal Control Over Financial Reporting

There was no change in Barnwell’s internal control over financial reporting during the quarter ended June 30, 2018 that materially affected, or is reasonably likely to materially affect, Barnwell’s internal control over financial reporting.

37

PART II - OTHER INFORMATION

ITEM 6.    EXHIBITS

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

38

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:	August 13, 2018	/s/ Russell M. Gifford
		Russell M. Gifford
		Chief Financial Officer,
		Executive Vice President,
		Treasurer and Secretary

39

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

40

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:	August 13, 2018	/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:	August 13, 2018	/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 June 30, 2018 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:	August 13, 2018	/s/ Alexander C. Kinzler
		Alexander C. Kinzler
		Title: President, Chief Executive Officer, Chief Operating Officer, General Counsel
Dated:	August 13, 2018	/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.

XML

Document and Entity Information - shares	9 Months Ended
	Jun. 30, 2018	Aug. 06, 2018
Document and Entity Information
Entity Registrant Name	BARNWELL INDUSTRIES INC
Entity Central Index Key	0000010048
Current Fiscal Year End Date	--09-30
Entity Filer Category	Smaller Reporting Company
Entity Current Reporting Status	Yes
Document Type	10-Q
Document Period End Date	Jun. 30, 2018
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding (in shares)		8,277,160

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2018	Sep. 30, 2017
Current assets:
Cash and cash equivalents	$ 13,539	$ 16,281
Certificates of deposit	3,460	4,413
Accounts and other receivables, net of allowance for doubtful accounts of: $34,000 at June 30, 2018; $46,000 at September 30, 2017	1,414	1,414
Income taxes receivable	2,231	1,145
Investment held for sale	1,000	1,037
Other current assets	1,269	852
Total current assets	22,913	25,142
Income taxes receivable, net of current portion	460	0
Deferred income tax assets	0	300
Investments	1,695	2,209
Property and equipment	58,858	79,231
Accumulated depletion, depreciation, and amortization	(55,385)	(73,862)
Property and equipment, net	3,473	5,369
Total assets	28,541	33,020
Current liabilities:
Accounts payable	1,158	1,185
Accrued capital expenditures	184	348
Accrued operating and other expenses	1,013	1,386
Accrued compensation	446	390
Current portion of asset retirement obligation	410	1,231
Other current liabilities	63	258
Total current liabilities	3,274	4,798
Deferred rent	86	21
Liability for retirement benefits	4,064	4,150
Asset retirement obligation	3,809	5,632
Deferred income tax liabilities	353	236
Total liabilities	11,586	14,837
Commitments and contingencies
Equity:
Common stock, par value $0.50 per share; authorized, 20,000,000 shares: 8,445,060 issued at June 30, 2018 and September 30, 2017	4,223	4,223
Additional paid-in capital	1,351	1,350
Retained earnings	14,311	15,023
Accumulated other comprehensive loss, net	(1,228)	(1,058)
Treasury stock, at cost: 167,900 shares at June 30, 2018 and September 30, 2017	(2,286)	(2,286)
Total stockholders' equity	16,371	17,252
Non-controlling interests	584	931
Total equity	16,955	18,183
Total liabilities and equity	$ 28,541	$ 33,020

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2018	Sep. 30, 2017
Statement of Financial Position [Abstract]
Accounts and other receivables, net of allowance for doubtful accounts of: $34,000 at June 30, 2018; $46,000 at September 30, 2017	$ 34	$ 46
Common stock, par value (in dollars per share)	$ 0.50	$ 0.50
Common stock, authorized shares (in shares)	20,000,000	20,000,000
Common stock, issued shares (in shares)	8,445,060	8,445,060
Treasury stock, shares (in shares)	167,900	167,900

XML

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Revenues:
Oil and natural gas	$ 616,000	$ 940,000	$ 2,428,000	$ 3,490,000
Contract drilling	1,193,000	360,000	3,051,000	3,346,000
Sale of interest in leasehold land	1,310,000	0	1,310,000	1,678,000
Gas processing and other	49,000	40,000	210,000	145,000
Total revenues	3,168,000	1,340,000	6,999,000	8,659,000
Costs and expenses:
Oil and natural gas operating	544,000	620,000	1,777,000	2,266,000
Contract drilling operating	1,074,000	593,000	2,778,000	2,607,000
General and administrative	1,591,000	1,345,000	4,635,000	5,126,000
Depletion, depreciation, and amortization	187,000	234,000	694,000	942,000
Impairment of assets	165,000	0	202,000	0
Gain on sales of assets	0	(527,000)	(2,250,000)	(527,000)
Total costs and expenses	3,561,000	2,265,000	7,836,000	10,414,000
Loss before equity in income (loss) of affiliates and income taxes	(393,000)	(925,000)	(837,000)	(1,755,000)
Equity in income (loss) of affiliates	136,000	(31,000)	(97,000)	2,125,000
(Loss) earnings before income taxes	(257,000)	(956,000)	(934,000)	370,000
Income tax benefit	(163,000)	(442,000)	(469,000)	(676,000)
Net (loss) earnings	(94,000)	(514,000)	(465,000)	1,046,000
Less: Net earnings (loss) attributable to non-controlling interests	280,000	(2,000)	247,000	532,000
Net (loss) earnings attributable to Barnwell Industries, Inc.	$ (374,000)	$ (512,000)	$ (712,000)	$ 514,000
Basic and diluted net earnings (loss) per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share)	$ (0.05)	$ (0.06)	$ (0.09)	$ 0.06
Weighted-average number of common shares outstanding:
Basic and diluted (in shares)	8,277	8,277	8,277	8,277

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS) INCOME (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Statement of Comprehensive Income [Abstract]
Net (loss) earnings	$ (94)	$ (514)	$ (465)	$ 1,046
Other comprehensive (loss) income:
Foreign currency translation adjustments, net of taxes of $0	(76)	81	(263)	33
Retirement plans - amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	30	51	93	244
Total other comprehensive (loss) income	(46)	132	(170)	277
Total comprehensive (loss) income	(140)	(382)	(635)	1,323
Less: Comprehensive income (loss) attributable to non-controlling interests	280	(2)	247	532
Comprehensive (loss) income attributable to Barnwell Industries, Inc.	$ (420)	$ (380)	$ (882)	$ 791

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS) INCOME (Parenthetical) (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Statement of Comprehensive Income [Abstract]
Foreign currency translation adjustments, taxes	$ 0	$ 0	$ 0	$ 0
Amortization of accumulated other comprehensive loss into net periodic benefit cost, taxes	$ 0	$ 0	$ 0	$ 0

XML

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) - USD ($) $ in Thousands	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, 2016		8,277,160
Balance, beginning of period at Sep. 30, 2016	$ 13,744	$ 4,223	$ 1,345	$ 13,852	$ (3,920)	$ (2,286)	$ 530
Increase (Decrease) in Stockholders' Equity
Contributions from non-controlling interests	6						6
Distributions to non-controlling interests	(617)						(617)
Net (loss) earnings	1,046			514			532
Share-based compensation	4		4
Foreign currency translation adjustments, net of taxes of $0	33				33
Retirement plans - amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	244				244
Balance, end of period (in shares) at Jun. 30, 2017		8,277,160
Balance, end of period at Jun. 30, 2017	14,460	$ 4,223	1,349	14,366	(3,643)	(2,286)	451
Balance, beginning of period (in shares) at Sep. 30, 2017		8,277,160
Balance, beginning of period at Sep. 30, 2017	18,183	$ 4,223	1,350	15,023	(1,058)	(2,286)	931
Increase (Decrease) in Stockholders' Equity
Distributions to non-controlling interests	(594)						(594)
Net (loss) earnings	(465)			(712)			247
Share-based compensation	1		1
Foreign currency translation adjustments, net of taxes of $0	(263)				(263)
Retirement plans - amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	93				93
Balance, end of period (in shares) at Jun. 30, 2018		8,277,160
Balance, end of period at Jun. 30, 2018	$ 16,955	$ 4,223	$ 1,351	$ 14,311	$ (1,228)	$ (2,286)	$ 584

XML

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Parenthetical) (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Statement of Stockholders' Equity [Abstract]
Foreign currency translation adjustments, taxes	$ 0	$ 0	$ 0	$ 0
Amortization of accumulated other comprehensive loss into net periodic benefit cost, taxes	$ 0	$ 0	$ 0	$ 0

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Cash flows from operating activities:
Net (loss) earnings	$ (465)	$ 1,046
Adjustments to reconcile net earnings (loss) to net cash (used in) provided by operating activities:
Equity in loss (income) of affiliates	97	(2,125)
Depletion, depreciation, and amortization	694	942
Gain on sale of asset	0	(527)
Gain on sale of oil and natural gas properties	(2,250)	0
Impairment of assets	202	0
Distribution of income from equity investees	0	2,164
Retirement benefits expense	222	404
Income tax receivable	(460)	0
Deferred rent liability	65	0
Accretion of asset retirement obligation	211	296
Deferred income tax expense	420	64
Asset retirement obligation payments	(589)	(713)
Share-based compensation (benefit) expense	(6)	23
Retirement plan contributions and payments	(215)	(359)
Sale of interest in leasehold land, net of fees paid	(1,272)	(1,418)
Decrease from changes in current assets and liabilities	(975)	(1,627)
Net cash used in operating activities	(4,321)	(1,830)
Cash flows from investing activities:
Purchase of certificates of deposit	(3,958)	(2,480)
Proceeds from the maturity of certificates of deposit	4,911	0
Distribution from equity investees in excess of earnings	417	652
Net proceeds from sale of interest in leasehold land	929	1,418
Proceeds from the sale of assets, net of closing costs	0	2,360
Proceeds from sale of oil and natural gas assets	770	1,238
Capital expenditures - oil and natural gas	(473)	(498)
Capital expenditures - all other	(114)	(120)
Net cash provided by investing activities	2,482	2,570
Cash flows from financing activities:
Distributions to non-controlling interests	(594)	(617)
Contributions from non-controlling interests	0	6
Decrease in restricted cash	0	372
Net cash used in financing activities	(594)	(239)
Effect of exchange rate changes on cash and cash equivalents	(309)	73
Net (decrease) increase in cash and cash equivalents	(2,742)	574
Cash and cash equivalents at beginning of period	16,281	15,550
Cash and cash equivalents at end of period	$ 13,539	$ 16,124

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

9 Months Ended

Jun. 30, 2018

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), a 75%-owned land investment partnership (KD Kona 2013 LLLP) and an 80%-owned joint venture (Kaupulehu 2007, LLLP). All significant intercompany accounts and transactions have been eliminated.

Barnwell’s investments in both unconsolidated entities in which a significant, but less than controlling, interest is held and in variable interest entities (“VIE”) in which the Company is not deemed to be the primary beneficiary are accounted for by the equity method.

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

Unaudited Interim Financial Information

The accompanying unaudited condensed consolidated financial statements and notes have been prepared by Barnwell in accordance with the rules and regulations of the United States (“U.S.”) Securities and Exchange Commission (“SEC”). 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, 2017 Annual Report on Form 10-K. The Condensed Consolidated Balance Sheet as of September 30, 2017 has been derived from audited consolidated financial statements.

In the opinion of management, all adjustments (which include only normal recurring adjustments) necessary to present fairly the financial position at June 30, 2018, results of operations and comprehensive (loss) income for the three and nine months ended June 30, 2018 and 2017, and equity and cash flows for the nine months ended June 30, 2018 and 2017, have been made. The results of operations for the period ended June 30, 2018 are not necessarily indicative of the operating results for the full year.

Use of Estimates

The preparation of the 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 Accounting Policies

There have been no changes to Barnwell’s significant accounting policies as described in the Notes to Consolidated Financial Statements included in Item 8 of the Company’s most recently filed Annual Report on Form 10-K.

Recently Adopted Accounting Pronouncements

In March 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-07, “Simplifying the Transition to the Equity Method of Accounting,” which eliminates the requirement that when an investment subsequently qualifies for use of the equity method as a result of an increase in level of ownership interest or degree of influence, an investor must adjust the investment, results of operations, and retained earnings retroactively on a step-by-step basis as if the equity method had been in effect during all previous periods that the investment had been held. This ASU requires that the equity method investor add the cost of acquiring the additional interest in the investee to the current basis of the investor’s previously held interest and to adopt the equity method of accounting as of the date the investment becomes qualified for equity method accounting. In addition, the ASU requires that an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized gain or loss in accumulated other comprehensive income at the date the investment becomes qualified for use of the equity method. The Company adopted the provisions of this ASU effective October 1, 2017. The adoption of this update did not have an impact on Barnwell’s consolidated financial statements.

In March 2016, the FASB issued ASU No. 2016-09, “Improvements to Employee Share-Based Payment Accounting,” which includes provisions intended to simplify various aspects related to how share-based payments are accounted for and presented in the financial statements. The Company adopted the provisions of this ASU effective October 1, 2017. The adoption of this update did not have an impact on Barnwell’s consolidated financial statements.

In October 2016, the FASB issued ASU No. 2016-17, “Interests Held through Related Parties That Are under Common Control,” which modifies existing guidance with respect to how a decision maker that holds an indirect interest in a VIE through a common control party determines whether it is the primary beneficiary of the VIE as part of the analysis of whether the VIE would need to be consolidated. Under this ASU, a decision maker would need to consider only its proportionate indirect interest in the VIE held through a common control party. The Company adopted the provisions of this ASU effective October 1, 2017. The adoption of this update did not have an impact on Barnwell’s consolidated financial statements.

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(LOSS) EARNINGS PER COMMON SHARE

9 Months Ended

Jun. 30, 2018

Earnings Per Share [Abstract]

(LOSS) EARNINGS PER COMMON SHARE

(LOSS) EARNINGS PER COMMON SHARE

Basic (loss) earnings per share is computed using the weighted-average number of common shares outstanding for the period. Diluted (loss) earnings 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) earnings per share if their effect is anti-dilutive.

Options to purchase 318,750 and 621,250 shares of common stock were excluded from the computation of diluted shares for the three and nine months ended June 30, 2018 and 2017, respectively, as their inclusion would have been antidilutive.

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

	Three months ended June 30, 2018
	Net Loss (Numerator)			Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(374,000	)	8,277,160	$	(0.05	)
Effect of dilutive securities -
common stock options	—			—
Diluted net loss per share	$	(374,000	)	8,277,160	$	(0.05	)

	Nine months ended June 30, 2018
	Net Loss (Numerator)			Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(712,000	)	8,277,160	$	(0.09	)
Effect of dilutive securities -
common stock options	—			—
Diluted net loss per share	$	(712,000	)	8,277,160	$	(0.09	)

	Three months ended June 30, 2017
	Net Loss (Numerator)			Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(512,000	)	8,277,160	$	(0.06	)
Effect of dilutive securities -
common stock options	—			—
Diluted net loss per share	$	(512,000	)	8,277,160	$	(0.06	)

	Nine months ended June 30, 2017
	Net Earnings (Numerator)		Shares (Denominator)	Per-Share Amount
Basic net earnings per share	$	514,000	8,277,160	$	0.06
Effect of dilutive securities -
common stock options	—		—
Diluted net earnings per share	$	514,000	8,277,160	$	0.06

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INVESTMENT HELD FOR SALE

9 Months Ended

Jun. 30, 2018

INVESTMENT HELD FOR SALE [Abstract]

INVESTMENT HELD FOR SALE

INVESTMENT HELD FOR SALE

At June 30, 2018, Kaupulehu 2007, LLLP owned one residential lot available for sale in the Lot 4A Increment I area located in the North Kona District of the island of Hawaii, north of Hualalai Resort at Historic Ka`upulehu, between the Queen Kaahumanu Highway and the Pacific Ocean.

In March 2018, Kaupulehu 2007, LLLP entered into a contract for the sale of the residential lot for net proceeds of $1,000,000. Accordingly, the lot's carrying value at March 31, 2018 was adjusted to the amount of the contract in escrow, and a $37,000 impairment of the value of the investment held for sale was recognized in the quarter ended March 31, 2018. The sale of the lot closed in August 2018 (see Note 13).

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INVESTMENTS

9 Months Ended

Jun. 30, 2018

Investments, All Other Investments [Abstract]

INVESTMENTS

INVESTMENTS

A summary of Barnwell’s investments is as follows:

	June 30, 2018		September 30, 2017
Investment in Kukio Resort Land Development Partnerships	$	1,645,000	$	2,159,000
Investment in leasehold land interest – Lot 4C	50,000		50,000
Total investments	$	1,695,000	$	2,209,000

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, 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, and KD II is the developer of Kaupulehu Lot 4A 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 as well as from commissions on real estate sales by the real estate sales office. As of June 30, 2018, 22 lots remained to be sold at Kaupulehu Increment I.

During the nine months ended June 30, 2018 and 2017, Barnwell received net cash distributions in the amount of $373,000 and $2,509,000, respectively, from the Kukio Resort Land Development Partnerships after distributing $44,000 and $307,000, respectively, to minority interests.

Barnwell's share of the operating results of its equity affiliates was income of $136,000 and a loss of $97,000 for the three and nine months ended June 30, 2018, respectively, and a loss of $31,000 and income of $2,125,000 for the three and nine months ended June 30, 2017, 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 $316,000 as of June 30, 2018, which is attributable to differences in the value of capitalized development costs and a note receivable. The basis difference is being recognized as the partnerships sell lots and recognize the associated costs and sell memberships for the Kuki`o Golf and Beach Club for which the receivable relates. The basis difference adjustments of $3,000and$6,000 for the three and nine months ended June 30, 2018, respectively, and $20,000 for the nine months ended June 30, 2017, increased equity in income of affiliates. There was no basis difference adjustment for the three months ended June 30, 2017.

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

	Three months ended June 30,
	2018		2017
Revenue	$	3,559,000	$	956,000
Gross profit	$	1,777,000	$	396,000
Net earnings	$	841,000	$	57,000

	Nine months ended June 30,
	2018		2017
Revenue	$	7,348,000	$	27,152,000
Gross profit	$	3,511,000	$	12,346,000
Net earnings	$	153,000	$	10,119,000

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 approximately 870 acres of the Kaupulehu Lot 4A area by KD I and KD II in two increments (“Increment I” and “Increment II”) (see Note 12).

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. During the three and nine months ended June 30, 2018, KD I sold one lot in Increment I for $3,100,000 and Kaupulehu Developments received a percentage of sales payment of $310,000. There were no Increment I percentage of sales payments received in the three and nine months ended June 30, 2017.

With respect to Increment II, Kaupulehu Developments is entitled to receive payments from KD II resulting from the sale of lots and/or residential units by KD II within Increment II. The payments are 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 the first was sold in fiscal 2016 and second was sold in fiscal 2017. Kaupulehu Developments received a percentage of sales payment of $1,678,000 from the sale of the second lot in the nine months ended June 30, 2017. The remaining acreage within Increment II is not yet under development. It is uncertain when or if KD II will develop the other areas of Increment II.

Kaupulehu Developments is 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. In fiscal 2017, the members of KD II received cumulative distributions equal to the original basis of capital invested in the project after which Barnwell received $2,500,000 from KD II representing an amount equal to 50% of the distributions KD II made to its members in September 2017, and an additional $1,000,000 was received from KD II in June 2018 under this arrangement, for a cumulative total of $3,500,000 received out of the $8,000,000 maximum. The $1,000,000 received in June 2018 is included in the table below. Kaupulehu Development incurred fees of $137,000 related to this payment which was included in "Accrued operating and other expenses" on the Company's Consolidated Balance Sheet at June 30, 2018 and was paid in July 2018.

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

	Three months ended   June 30,					Nine months ended   June 30,
	2018			2017		2018			2017
Sale of interest in leasehold land:
Revenues - sale of interest in leasehold land	$	1,310,000		$	—	$	1,310,000		$	1,678,000
Fees - included in general and administrative expenses	(175,000		)	—		(175,000		)	(260,000		)
Proceeds from sale of interest in leasehold land, net of fees paid	$	1,135,000		$	—	$	1,135,000		$	1,418,000

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. The lease terminates in December 2025.

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OIL AND NATURAL GAS PROPERTIES AND ASSET RETIREMENT OBLIGATION

9 Months Ended

Jun. 30, 2018

Oil and Natural Gas Properties [Abstract]

OIL AND NATURAL GAS PROPERTIES AND ASSET RETIREMENT OBLIGATION

OIL AND NATURAL GAS PROPERTIES AND ASSET RETIREMENT OBLIGATION

Full cost properties

In October 2017, Barnwell entered into a Purchase and Sale Agreement with an independent third party and sold its oil and natural gas properties located in the Pouce Coupe area of Alberta, Canada. The sales price per the agreement was adjusted to $79,000 for customary purchase price adjustments to reflect the economic activity from the effective date of May 1, 2017 to the closing date. From Barnwell's net proceeds, $37,000 was withheld and remitted by the buyer to the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes. No gain or loss was recognized on this sale as it did not result in a significant alteration of the relationship between capitalized costs and proved reserves. Proceeds from the disposition were credited to the full cost pool.

In February 2018, Barnwell sold its oil properties located in the Red Earth area of Alberta, Canada to two separate independent third parties. The sales prices per the agreements were adjusted for customary purchase price adjustments to reflect the economic activity from the effective date of October 1, 2017 to the closing date, for a combined adjusted sales price of $1,360,000. 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. From Barnwell's net proceeds, $752,000 was withheld and remitted by the buyer to the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes.

The difference in the relationship between capitalized costs and proved reserves of the Red Earth properties sold as compared to the properties retained by Barnwell was significant as there was a 322% difference in capitalized costs divided by proved reserves if the gain was recorded versus the gain being credited against the full-cost pool. Accordingly, Barnwell recorded a gain on the sale of Red Earth of $2,135,000 in the three months ended March 31, 2018 in accordance with the guidance in Rule 4-10(c)(6)(i) of Regulation S-X of the rules and regulations of the SEC, which requires an allocation of capitalized costs to the reserves sold and reserves retained on the basis of the relative fair values of the properties as there was a substantial economic difference between the properties sold and those retained. Also included in the gain calculation were asset retirement obligations of $1,666,000 assumed by the purchaser.

Other properties

In February 2018, Barnwell sold its interest in natural gas transmission lines and related surface facilities in the Stolberg area of Alberta, Canada for $120,000, and we recognized a $115,000 gain on the sale for the quarter ended March 31, 2018.

Asset retirement obligation

Barnwell recognizes the fair value of a liability for an asset retirement obligation in the period in which it is incurred if a reasonable estimate of fair value can be made. The following is a reconciliation of the asset retirement obligation:

	Nine months
	ended
	June 30, 2018
Asset retirement obligation as of beginning of period	$	6,863,000
Obligation incurred on new well drilled	9,000
Liabilities associated with properties sold	(1,752,000		)
Revision of estimated obligation	(323,000		)
Accretion expense	211,000
Payments	(589,000		)
Foreign currency translation adjustment	(200,000		)
Asset retirement obligation as of end of period	4,219,000
Less current portion	(410,000		)
Asset retirement obligation, long-term	$	3,809,000

Asset retirement obligations were reduced by $1,752,000 during the nine months ended June 30, 2018 for those obligations that were assumed by purchasers of certain of Barnwell's oil and natural gas properties.

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RETIREMENT PLANS

9 Months Ended

Jun. 30, 2018

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 tables detail the components of net periodic benefit cost for Barnwell’s retirement plans:

	Pension Plan						SERP						Postretirement Medical
	Three months ended June 30,
	2018			2017			2018			2017			2018		2017
Service cost (credit)	$	54,000		$	34,000		$	10,000		$	(5,000	)	$	—	$	—
Interest cost	88,000			78,000			19,000			1,000			19,000		22,000
Expected return on plan assets	(147,000		)	(122,000		)	—			—			—		—
Amortization of prior service cost (credit)	2,000			2,000			(1,000		)	(2,000		)	—		—
Amortization of net actuarial loss	25,000			21,000			3,000			(17,000		)	2,000		47,000
Net periodic benefit cost	$	22,000		$	13,000		$	31,000		$	(23,000	)	$	21,000	$	69,000

	Pension Plan						SERP						Postretirement Medical
	Nine months ended June 30,
	2018			2017			2018			2017			2018		2017
Service cost	$	162,000		$	178,000		$	30,000		$	26,000		$	—	$	—
Interest cost	266,000			252,000			57,000			42,000			57,000		66,000
Expected return on plan assets	(443,000		)	(404,000		)	—			—			—		—
Amortization of prior service cost (credit)	5,000			4,000			(4,000		)	(4,000		)	—		—
Amortization of net actuarial loss	74,000			103,000			10,000			—			8,000		141,000
Net periodic benefit cost	$	64,000		$	133,000		$	93,000		$	64,000		$	65,000	$	207,000

Barnwell contributed $200,000 to the Pension Plan during the nine months ended June 30, 2018 and estimates that it will make further contributions of approximately $300,000 during the remainder of fiscal 2018. 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 2018 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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INCOME TAXES

9 Months Ended

Jun. 30, 2018

Income Tax Disclosure [Abstract]

INCOME TAXES

INCOME TAXES

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

	Three months ended   June 30,						Nine months ended   June 30,
	2018			2017			2018			2017
United States	$	(12,000	)	$	(619,000	)	$	(2,137,000	)	$	792,000
Canada	(525,000		)	(335,000		)	956,000			(954,000		)
	$	(537,000	)	$	(954,000	)	$	(1,181,000	)	$	(162,000	)

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

	Three months ended   June 30,						Nine months ended   June 30,
	2018			2017			2018			2017
Current	$	(60,000	)	$	(392,000	)	$	(889,000	)	$	(740,000	)
Deferred	(103,000		)	(50,000		)	420,000			64,000
	$	(163,000	)	$	(442,000	)	$	(469,000	)	$	(676,000	)

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.

The Tax Cuts and Jobs Act of 2017 (“TCJA”), enacted on December 22, 2017, contains significant changes, including a reduction in the U.S. corporate income tax rate, repeal of the corporate Alternative Minimum Tax (“AMT”), restriction of the deduction for post-TCJA net operating losses to 80% of taxable income and elimination of net operating loss carrybacks, mandatory deemed repatriation and resulting taxation of all undistributed foreign earnings, as well as various other changes that either do not currently have a significant impact to the Company, or that may impact us in the future should those provisions become applicable to the Company. We believe our assessment of the estimated impacts of the TCJA is complete based on information available to date. However, the TCJA makes broad and complex changes to the U.S. tax code and is subject to interpretation until additional guidance is issued by taxation and financial reporting authorities. The ultimate impact of the TCJA may differ from our estimates due to changes in the interpretations and assumptions we used and changes in any future regulatory guidance.

The TCJA reduces the U.S. statutory tax rate from 35% to 21% effective January 1, 2018. The Company’s U.S. federal statutory rate for the fiscal year ending September 30, 2018 will be a blended rate of 24.5%, based on a fiscal year blended rate calculation of pre- and post-TJCA rates, and will be 21% for future fiscal years. There was no financial statement impact of the TCJA’s reduction in the U.S. statutory tax rate in the quarter ended December 31, 2017, as the Company has a full valuation allowance on its net deferred tax assets under U.S. federal tax law.

The repeal of the corporate AMT provides a mechanism for the refund over time of any unused AMT credit carryovers. Prior to the enactment of the TCJA, it was not more likely than not that the Company’s AMT credit carryovers would provide a future benefit, as such the AMT deferred tax asset had a full valuation allowance. As a result of the new TCJA provision for refundability of the AMT, the Company recorded a current income tax benefit of $460,000 in the quarter ended December 31, 2017 to reflect the undiscounted unused AMT credit carryover balance as a non-current income tax receivable. Respective portions of this balance will be reclassified to current income taxes receivable when amounts are eligible for refund within one year of the balance sheet date.

The TCJA restricts the deduction for post-TCJA net operating losses to 80% of taxable income and eliminates the current net operating loss carryback provisions. The Company has determined that all existing pre-TCJA net operating loss carryovers are of sufficient magnitude and life such that they will fully shelter future reversals of U.S. federal deferred tax liabilities. As such, there was no financial statement impact of the TCJA’s changes to net operating losses in the quarter ended December 31, 2017.

The TCJA establishes mandatory deemed repatriation and resulting taxation of all post-1986 undistributed foreign earnings. As the Company’s Canadian operations consist of a U.S. corporate subsidiary operating as a branch in Canada and other minor, inactive Canadian corporate subsidiaries there was no impact from this provision.

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SEGMENT INFORMATION

9 Months Ended

Jun. 30, 2018

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   June 30,						Nine months ended   June 30,
	2018			2017			2018			2017
Revenues:
Oil and natural gas	$	616,000		$	940,000		$	2,428,000		$	3,490,000
Land investment	1,310,000			—			1,310,000			1,678,000
Contract drilling	1,193,000			360,000			3,051,000			3,346,000
Other	3,000			19,000			73,000			88,000
Total before interest income	3,122,000			1,319,000			6,862,000			8,602,000
Interest income	46,000			21,000			137,000			57,000
Total revenues	$	3,168,000		$	1,340,000		$	6,999,000		$	8,659,000
Depletion, depreciation, and amortization:
Oil and natural gas	$	121,000		$	145,000		$	477,000		$	672,000
Contract drilling	55,000			69,000			169,000			205,000
Other	11,000			20,000			48,000			65,000
Total depletion, depreciation, and amortization	$	187,000		$	234,000		$	694,000		$	942,000
Impairment:
Land investment	$	—		$	—		$	37,000		$	—
Other	165,000			—			165,000			—
Total impairment	$	165,000		$	—		$	202,000		$	—
Operating (loss) profit (before general and administrative expenses):
Oil and natural gas	$	(49,000	)	$	175,000		$	174,000		$	552,000
Land investment	1,310,000			—			1,273,000			1,678,000
Contract drilling	64,000			(302,000		)	104,000			534,000
Other	(173,000		)	(1,000		)	(140,000		)	23,000
Gain on sales of assets	—			527,000			2,250,000			527,000
Total operating profit	1,152,000			399,000			3,661,000			3,314,000
Equity in income (loss) of affiliates:
Land investment	136,000			(31,000		)	(97,000		)	2,125,000
General and administrative expenses	(1,591,000		)	(1,345,000		)	(4,635,000		)	(5,126,000		)
Interest income	46,000			21,000			137,000			57,000
(Loss) earnings before income taxes	$	(257,000	)	$	(956,000	)	$	(934,000	)	$	370,000

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ACCUMULATED OTHER COMPREHENSIVE LOSS

9 Months Ended

Jun. 30, 2018

Equity [Abstract]

ACCUMULATED OTHER COMPREHENSIVE LOSS

ACCUMULATED OTHER COMPREHENSIVE LOSS

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

	Three months ended   June 30,						Nine months ended   June 30,
	2018			2017			2018			2017
Foreign currency translation:
Beginning accumulated foreign currency translation	$	866,000		$	858,000		$	1,053,000		$	906,000
Change in cumulative translation adjustment before reclassifications	(76,000		)	81,000			(263,000		)	33,000
Income taxes	—			—			—			—
Net current period other comprehensive (loss) income	(76,000		)	81,000			(263,000		)	33,000
Ending accumulated foreign currency translation	790,000			939,000			790,000			939,000
Retirement plans:
Beginning accumulated retirement plans benefit cost	(2,048,000		)	(4,633,000		)	(2,111,000		)	(4,826,000		)
Amortization of net actuarial loss and prior service cost	30,000			51,000			93,000			244,000
Income taxes	—			—			—			—
Net current period other comprehensive income	30,000			51,000			93,000			244,000
Ending accumulated retirement plans benefit cost	(2,018,000		)	(4,582,000		)	(2,018,000		)	(4,582,000		)
Accumulated other comprehensive loss, net of taxes	$	(1,228,000	)	$	(3,643,000	)	$	(1,228,000	)	$	(3,643,000	)

The amortization of accumulated other comprehensive loss components for the retirement plans are included in the computation of net periodic benefit cost which is a component of "General and administrative" expenses on the accompanying Condensed Consolidated Statements of Operations (see Note 6 for additional details).

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FAIR VALUE MEASUREMENTS

9 Months Ended

Jun. 30, 2018

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS

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

In March 2018, Kaupulehu 2007, LLLP entered into a contract for the sale of the residential lot for net proceeds of $1,000,000. Accordingly, the lot's carrying value at March 31, 2018 was adjusted to the amount of the contract currently in escrow, and a $37,000 impairment of the value of the investment held for sale was recognized in the quarter ended March 31, 2018. The sale of the lot closed in August 2018 (see Note 13).

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. As further described in Note 5, the Company recognizes the fair value of a liability for an asset retirement obligation in the period in which it is incurred if a reasonable estimate of fair value can be made. Asset retirement obligations are not measured at fair value subsequent to initial recognition.

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INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

9 Months Ended

Jun. 30, 2018

Supplemental Cash Flow Elements [Abstract]

INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

	Nine months ended   June 30,
	2018			2017
Supplemental disclosure of cash flow information:
Cash paid during the year for:
Interest	$	3,000		$	6,000
Income taxes refunded, net	$	(20,000	)	$	(137,000	)
Supplemental disclosure of non-cash investing activities:
Canadian income tax withholding on proceeds from the sale of oil and natural gas properties	$	789,000		$	—

Capital expenditure accruals related to oil and natural gas exploration and development decreased $152,000 and $199,000 during the nine months ended June 30, 2018 and 2017, respectively. Additionally, capital expenditure accruals related to oil and natural gas asset retirement obligations decreased $399,000 and $62,000 during the nine months ended June 30, 2018 and 2017, respectively.

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RELATED PARTY TRANSACTIONS

9 Months Ended

Jun. 30, 2018

Related Party Transactions [Abstract]

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS

Kaupulehu Developments is entitled to receive a percentage of the gross receipts from the sales of lots in Increment I from KD I and the sales of lots and/or residential units in Increment II from KD II. Kaupulehu Developments is 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 has been received to date (see Note 4). KD I and KD II are part of the Kukio Resort Land Development Partnerships in which Barnwell holds an indirect 19.6% non-controlling ownership interest accounted for under the equity method of investment. The percentage of sales payments and percent 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.

During the nine months ended June 30, 2018, Barnwell received $1,310,000 in payments, of which $1,000,000 was related to the 50% of distributions otherwise payable from KD II to its members after the members of KD II received distributions equal to the original basis of capital invested in the project, up to $8,000,000. The remaining $310,000 in payments was due to percentage of sales payments from KD I from the sale of one lot within Increment I. During the nine months ended June 30, 2017, Barnwell received $1,678,000 in percentage of sales payments from KD II from the sale of one lot within Increment II.

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SUBSEQUENT EVENTS

9 Months Ended

Jun. 30, 2018

Subsequent Events [Abstract]

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS

In July 2018, the Company entered into a Purchase and Sale Agreement with an independent third party for the purchase of interests in oil and natural gas properties located in the Twining area of Alberta, Canada. The purchase price for Barnwell's interests is approximately $10,500,000, at current Canadian dollar exchange rates, and is subject to customary adjustments to the purchase price at closing, including adjustments to reflect an effective date of sale of July 1, 2018. In accordance with the Purchase and Sale Agreement, Barnwell paid a non-refundable 5% deposit of approximately $525,000.

Certain of the assets which would be conveyed to the Company pursuant to the Purchase and Sale Agreement are subject to third parties' rights of first refusal. If one or more of such third parties exercises their rights of first refusal, the assets being transferred to the Company would be reduced as well as the purchase price to be paid by the Company.

The closing of the transaction is expected to occur in late August 2018. There is no assurance that the transaction will be successfully consummated.

In July 2018, Kaupulehu Developments received a percentage of sales payment of $165,000 from the sale of a lot within Phase II of Increment I. Financial results from the receipt of this payment will be reflected in Barnwell’s year ending September 30, 2018.

In August 2018, Kaupulehu 2007, LLLP, received net proceeds of $1,000,000 from the sale of the remaining residential lot available for sale in Lot 4A of Increment I. Financial results from the receipt of this payment will be reflected in Barnwell’s year ending September 30, 2018.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

9 Months Ended

Jun. 30, 2018

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), a 75%-owned land investment partnership (KD Kona 2013 LLLP) and an 80%-owned joint venture (Kaupulehu 2007, LLLP). All significant intercompany accounts and transactions have been eliminated.

Barnwell’s investments in both unconsolidated entities in which a significant, but less than controlling, interest is held and in variable interest entities (“VIE”) 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 (“SEC”). Accordingly, certain information and footnote disclosures normally included in the annual financial statements prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted pursuant to those rules and regulations, although the Company believes that the disclosures made are adequate to make the information not misleading. These condensed consolidated financial statements and notes should be read in conjunction with the consolidated financial statements and notes thereto included in Barnwell’s September 30, 2017 Annual Report on Form 10-K. The Condensed Consolidated Balance Sheet as of September 30, 2017 has been derived from audited consolidated financial statements.

In the opinion of management, all adjustments (which include only normal recurring adjustments) necessary to present fairly the financial position at June 30, 2018, results of operations and comprehensive (loss) income for the three and nine months ended June 30, 2018 and 2017, and equity and cash flows for the nine months ended June 30, 2018 and 2017, have been made. The results of operations for the period ended June 30, 2018 are not necessarily indicative of the operating results for the full year.

Use of Estimates

Use of Estimates

The preparation of the 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.

Recently Adopted Accounting Pronouncements

Recently Adopted Accounting Pronouncements

In March 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-07, “Simplifying the Transition to the Equity Method of Accounting,” which eliminates the requirement that when an investment subsequently qualifies for use of the equity method as a result of an increase in level of ownership interest or degree of influence, an investor must adjust the investment, results of operations, and retained earnings retroactively on a step-by-step basis as if the equity method had been in effect during all previous periods that the investment had been held. This ASU requires that the equity method investor add the cost of acquiring the additional interest in the investee to the current basis of the investor’s previously held interest and to adopt the equity method of accounting as of the date the investment becomes qualified for equity method accounting. In addition, the ASU requires that an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized gain or loss in accumulated other comprehensive income at the date the investment becomes qualified for use of the equity method. The Company adopted the provisions of this ASU effective October 1, 2017. The adoption of this update did not have an impact on Barnwell’s consolidated financial statements.

In March 2016, the FASB issued ASU No. 2016-09, “Improvements to Employee Share-Based Payment Accounting,” which includes provisions intended to simplify various aspects related to how share-based payments are accounted for and presented in the financial statements. The Company adopted the provisions of this ASU effective October 1, 2017. The adoption of this update did not have an impact on Barnwell’s consolidated financial statements.

In October 2016, the FASB issued ASU No. 2016-17, “Interests Held through Related Parties That Are under Common Control,” which modifies existing guidance with respect to how a decision maker that holds an indirect interest in a VIE through a common control party determines whether it is the primary beneficiary of the VIE as part of the analysis of whether the VIE would need to be consolidated. Under this ASU, a decision maker would need to consider only its proportionate indirect interest in the VIE held through a common control party. The Company adopted the provisions of this ASU effective October 1, 2017. The adoption of this update did not have an impact on Barnwell’s consolidated financial statements.

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(LOSS) EARNINGS PER COMMON SHARE (Tables)

9 Months Ended

Jun. 30, 2018

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

	Three months ended June 30, 2018
	Net Loss (Numerator)			Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(374,000	)	8,277,160	$	(0.05	)
Effect of dilutive securities -
common stock options	—			—
Diluted net loss per share	$	(374,000	)	8,277,160	$	(0.05	)

	Nine months ended June 30, 2018
	Net Loss (Numerator)			Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(712,000	)	8,277,160	$	(0.09	)
Effect of dilutive securities -
common stock options	—			—
Diluted net loss per share	$	(712,000	)	8,277,160	$	(0.09	)

	Three months ended June 30, 2017
	Net Loss (Numerator)			Shares (Denominator)	Per-Share Amount
Basic net loss per share	$	(512,000	)	8,277,160	$	(0.06	)
Effect of dilutive securities -
common stock options	—			—
Diluted net loss per share	$	(512,000	)	8,277,160	$	(0.06	)

	Nine months ended June 30, 2017
	Net Earnings (Numerator)		Shares (Denominator)	Per-Share Amount
Basic net earnings per share	$	514,000	8,277,160	$	0.06
Effect of dilutive securities -
common stock options	—		—
Diluted net earnings per share	$	514,000	8,277,160	$	0.06

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INVESTMENTS (Tables)

9 Months Ended

Jun. 30, 2018

Investments, All Other Investments [Abstract]

Summary of investments

A summary of Barnwell’s investments is as follows:

	June 30, 2018		September 30, 2017
Investment in Kukio Resort Land Development Partnerships	$	1,645,000	$	2,159,000
Investment in leasehold land interest – Lot 4C	50,000		50,000
Total investments	$	1,695,000	$	2,209,000

Summarized financial information for the land development partnerships

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

	Three months ended June 30,
	2018		2017
Revenue	$	3,559,000	$	956,000
Gross profit	$	1,777,000	$	396,000
Net earnings	$	841,000	$	57,000

	Nine months ended June 30,
	2018		2017
Revenue	$	7,348,000	$	27,152,000
Gross profit	$	3,511,000	$	12,346,000
Net earnings	$	153,000	$	10,119,000

Summary of percentage of sales payment revenues received

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

	Three months ended   June 30,					Nine months ended   June 30,
	2018			2017		2018			2017
Sale of interest in leasehold land:
Revenues - sale of interest in leasehold land	$	1,310,000		$	—	$	1,310,000		$	1,678,000
Fees - included in general and administrative expenses	(175,000		)	—		(175,000		)	(260,000		)
Proceeds from sale of interest in leasehold land, net of fees paid	$	1,135,000		$	—	$	1,135,000		$	1,418,000

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OIL AND NATURAL GAS PROPERTIES AND ASSET RETIREMENT OBLIGATION (Tables)

9 Months Ended

Jun. 30, 2018

Oil and Natural Gas Properties [Abstract]

Schedule of change in asset retirement obligation

The following is a reconciliation of the asset retirement obligation:

	Nine months
	ended
	June 30, 2018
Asset retirement obligation as of beginning of period	$	6,863,000
Obligation incurred on new well drilled	9,000
Liabilities associated with properties sold	(1,752,000		)
Revision of estimated obligation	(323,000		)
Accretion expense	211,000
Payments	(589,000		)
Foreign currency translation adjustment	(200,000		)
Asset retirement obligation as of end of period	4,219,000
Less current portion	(410,000		)
Asset retirement obligation, long-term	$	3,809,000

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RETIREMENT PLANS (Tables)

9 Months Ended

Jun. 30, 2018

Retirement Benefits [Abstract]

Schedule of components of net periodic benefit cost

The following tables detail the components of net periodic benefit cost for Barnwell’s retirement plans:

	Pension Plan						SERP						Postretirement Medical
	Three months ended June 30,
	2018			2017			2018			2017			2018		2017
Service cost (credit)	$	54,000		$	34,000		$	10,000		$	(5,000	)	$	—	$	—
Interest cost	88,000			78,000			19,000			1,000			19,000		22,000
Expected return on plan assets	(147,000		)	(122,000		)	—			—			—		—
Amortization of prior service cost (credit)	2,000			2,000			(1,000		)	(2,000		)	—		—
Amortization of net actuarial loss	25,000			21,000			3,000			(17,000		)	2,000		47,000
Net periodic benefit cost	$	22,000		$	13,000		$	31,000		$	(23,000	)	$	21,000	$	69,000

	Pension Plan						SERP						Postretirement Medical
	Nine months ended June 30,
	2018			2017			2018			2017			2018		2017
Service cost	$	162,000		$	178,000		$	30,000		$	26,000		$	—	$	—
Interest cost	266,000			252,000			57,000			42,000			57,000		66,000
Expected return on plan assets	(443,000		)	(404,000		)	—			—			—		—
Amortization of prior service cost (credit)	5,000			4,000			(4,000		)	(4,000		)	—		—
Amortization of net actuarial loss	74,000			103,000			10,000			—			8,000		141,000
Net periodic benefit cost	$	64,000		$	133,000		$	93,000		$	64,000		$	65,000	$	207,000

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INCOME TAXES (Tables)

9 Months Ended

Jun. 30, 2018

Income Tax Disclosure [Abstract]

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

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

	Three months ended   June 30,						Nine months ended   June 30,
	2018			2017			2018			2017
United States	$	(12,000	)	$	(619,000	)	$	(2,137,000	)	$	792,000
Canada	(525,000		)	(335,000		)	956,000			(954,000		)
	$	(537,000	)	$	(954,000	)	$	(1,181,000	)	$	(162,000	)

Schedule of components of the income tax provision (benefit)

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

	Three months ended   June 30,						Nine months ended   June 30,
	2018			2017			2018			2017
Current	$	(60,000	)	$	(392,000	)	$	(889,000	)	$	(740,000	)
Deferred	(103,000		)	(50,000		)	420,000			64,000
	$	(163,000	)	$	(442,000	)	$	(469,000	)	$	(676,000	)

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SEGMENT INFORMATION (Tables)

9 Months Ended

Jun. 30, 2018

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   June 30,						Nine months ended   June 30,
	2018			2017			2018			2017
Revenues:
Oil and natural gas	$	616,000		$	940,000		$	2,428,000		$	3,490,000
Land investment	1,310,000			—			1,310,000			1,678,000
Contract drilling	1,193,000			360,000			3,051,000			3,346,000
Other	3,000			19,000			73,000			88,000
Total before interest income	3,122,000			1,319,000			6,862,000			8,602,000
Interest income	46,000			21,000			137,000			57,000
Total revenues	$	3,168,000		$	1,340,000		$	6,999,000		$	8,659,000
Depletion, depreciation, and amortization:
Oil and natural gas	$	121,000		$	145,000		$	477,000		$	672,000
Contract drilling	55,000			69,000			169,000			205,000
Other	11,000			20,000			48,000			65,000
Total depletion, depreciation, and amortization	$	187,000		$	234,000		$	694,000		$	942,000
Impairment:
Land investment	$	—		$	—		$	37,000		$	—
Other	165,000			—			165,000			—
Total impairment	$	165,000		$	—		$	202,000		$	—
Operating (loss) profit (before general and administrative expenses):
Oil and natural gas	$	(49,000	)	$	175,000		$	174,000		$	552,000
Land investment	1,310,000			—			1,273,000			1,678,000
Contract drilling	64,000			(302,000		)	104,000			534,000
Other	(173,000		)	(1,000		)	(140,000		)	23,000
Gain on sales of assets	—			527,000			2,250,000			527,000
Total operating profit	1,152,000			399,000			3,661,000			3,314,000
Equity in income (loss) of affiliates:
Land investment	136,000			(31,000		)	(97,000		)	2,125,000
General and administrative expenses	(1,591,000		)	(1,345,000		)	(4,635,000		)	(5,126,000		)
Interest income	46,000			21,000			137,000			57,000
(Loss) earnings before income taxes	$	(257,000	)	$	(956,000	)	$	(934,000	)	$	370,000

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ACCUMULATED OTHER COMPREHENSIVE LOSS (Tables)

9 Months Ended

Jun. 30, 2018

Equity [Abstract]

Schedule of changes in each component of accumulated other comprehensive loss

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

	Three months ended   June 30,						Nine months ended   June 30,
	2018			2017			2018			2017
Foreign currency translation:
Beginning accumulated foreign currency translation	$	866,000		$	858,000		$	1,053,000		$	906,000
Change in cumulative translation adjustment before reclassifications	(76,000		)	81,000			(263,000		)	33,000
Income taxes	—			—			—			—
Net current period other comprehensive (loss) income	(76,000		)	81,000			(263,000		)	33,000
Ending accumulated foreign currency translation	790,000			939,000			790,000			939,000
Retirement plans:
Beginning accumulated retirement plans benefit cost	(2,048,000		)	(4,633,000		)	(2,111,000		)	(4,826,000		)
Amortization of net actuarial loss and prior service cost	30,000			51,000			93,000			244,000
Income taxes	—			—			—			—
Net current period other comprehensive income	30,000			51,000			93,000			244,000
Ending accumulated retirement plans benefit cost	(2,018,000		)	(4,582,000		)	(2,018,000		)	(4,582,000		)
Accumulated other comprehensive loss, net of taxes	$	(1,228,000	)	$	(3,643,000	)	$	(1,228,000	)	$	(3,643,000	)

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

9 Months Ended

Jun. 30, 2018

Supplemental Cash Flow Elements [Abstract]

Schedule of supplemental cash flow information

	Nine months ended   June 30,
	2018			2017
Supplemental disclosure of cash flow information:
Cash paid during the year for:
Interest	$	3,000		$	6,000
Income taxes refunded, net	$	(20,000	)	$	(137,000	)
Supplemental disclosure of non-cash investing activities:
Canadian income tax withholding on proceeds from the sale of oil and natural gas properties	$	789,000		$	—

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details)	9 Months Ended
	Jun. 30, 2018
Kaupulehu Developments
Subsidiary or Equity Method Investee [Line Items]
Ownership interest in subsidiaries	77.60%
KD Kona 2013 LLLP
Subsidiary or Equity Method Investee [Line Items]
Ownership interest in subsidiaries	75.00%
Kaupulehu 2007, LLLP
Subsidiary or Equity Method Investee [Line Items]
Ownership interest in subsidiaries	80.00%

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(LOSS) EARNINGS PER COMMON SHARE (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Net (Loss) Earnings (Numerator)
Basic net earnings (loss) per share	$ (374)	$ (512)	$ (712)	$ 514
Effect of dilutive securities - common stock options	0	0	0	0
Diluted net earnings (loss) per share	$ (374)	$ (512)	$ (712)	$ 514
Shares (Denominator)
Basic net earnings (loss) per share (in shares)	8,277,160	8,277,160	8,277,160	8,277,160
Effect of dilutive securities - common stock options (in shares)	0	0	0	0
Diluted net earnings (loss) per share (in shares)	8,277,160	8,277,160	8,277,160	8,277,160
Per-Share Amount
Basic net earnings (loss) per share (in dollars per share)	$ (0.05)	$ (0.06)	$ (0.09)	$ 0.06
Diluted net earnings (loss) per share (in dollars per share)	$ (0.05)	$ (0.06)	$ (0.09)	$ 0.06
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)			318,750	621,250

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INVESTMENT HELD FOR SALE (Details) $ in Thousands	1 Months Ended	3 Months Ended			9 Months Ended
	Mar. 31, 2018 USD ($)	Jun. 30, 2018 USD ($) parcel	Mar. 31, 2018 USD ($)	Jun. 30, 2017 USD ($)	Jun. 30, 2018 USD ($) parcel	Jun. 30, 2017 USD ($)
Investment Holdings [Line Items]
Impairment of assets		$ 165		$ 0	$ 202	$ 0
Residential Parcel
Investment Holdings [Line Items]
Number of real estate properties | parcel		1			1
Proceeds from sale of property held-for-sale	$ 1,000
Impairment of assets			$ 37

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INVESTMENTS - SUMMARY OF INVESTMENTS (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Sep. 30, 2017
Investment Holdings [Line Items]
Investments	$ 1,695	$ 2,209
Investment in Kukio Resort Land Development Partnerships
Investment Holdings [Line Items]
Investments	1,645	2,159
Investment in leasehold land interest – Lot 4C
Investment Holdings [Line Items]
Investments	$ 50	$ 50

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INVESTMENTS - LAND DEVELOPMENT PARTNERSHIPS (Details) $ in Thousands		3 Months Ended		9 Months Ended
	Nov. 27, 2013 USD ($) partnership	Jun. 30, 2018 USD ($) lot	Jun. 30, 2017 USD ($)	Jun. 30, 2018 USD ($) lot	Jun. 30, 2017 USD ($)
Investment Holdings [Line Items]
Equity in income (loss) of affiliates		$ 136	$ (31)	$ (97)	$ 2,125
Investment in Kukio Resort Land Development Partnerships
Investment Holdings [Line Items]
Number of limited liability limited partnerships formed | partnership	2
Cash distribution from equity method investment				373	2,509
Difference between carrying amount and underlying equity		316		316
Basis difference adjustment		3		6	20
Revenue		3,559	956	7,348	27,152
Gross profit		1,777	396	3,511	12,346
Net earnings		$ 841	$ 57	153	10,119
Investment in Kukio Resort Land Development Partnerships | Noncontrolling Interest
Investment Holdings [Line Items]
Cash distribution from equity method investment				$ 44	$ 307
Investment in Kukio Resort Land Development Partnerships | KD Kaupulehu LLLP Increment I
Investment Holdings [Line Items]
Number of residential lots remaining to be sold | lot		22		22
Investment in Kukio Resort Land Development Partnerships | K D Kukio Resorts LLLP
Investment Holdings [Line Items]
Ownership interest acquired	19.60%
Investment in Kukio Resort Land Development Partnerships | K D Maniniowali LLLP
Investment Holdings [Line Items]
Ownership interest acquired	19.60%
Investment in Kukio Resort Land Development Partnerships | KD Kaupulehu, LLLP
Investment Holdings [Line Items]
Ownership interest acquired	19.60%
Investment in Kukio Resort Land Development Partnerships | Indirectly Acquired Interest
Investment Holdings [Line Items]
Aggregate cost	$ 5,140

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INVESTMENTS - SALE OF INTEREST IN LEASEHOLD LAND (Details)	1 Months Ended	3 Months Ended		9 Months Ended		12 Months Ended	21 Months Ended
	Jun. 30, 2018 USD ($) a	Jun. 30, 2018 USD ($) a lot	Jun. 30, 2017 USD ($)	Jun. 30, 2018 USD ($) a increment lot	Jun. 30, 2017 USD ($)	Sep. 30, 2017 USD ($)	Jun. 30, 2018 USD ($) a
Investment [Line Items]
Sale of interest in leasehold land		$ 1,310,000	$ 0	$ 1,310,000	$ 1,678,000
Fees related to land payments	$ 1,013,000	$ 1,013,000		$ 1,013,000		$ 1,386,000	$ 1,013,000
Kaupulehu Developments
Investment [Line Items]
Area of land (in acres) | a	870	870		870			870
Number of development increments | increment				2
Sale of interest in leasehold land		$ 1,310,000	$ 0	$ 1,310,000	1,678,000
Kaupulehu Developments | KD Kaupulehu LLLP Increment I
Investment [Line Items]
Aggregate gross proceeds from sale of Increment I single family lots for calculating payments entitled to be received				$ 3,100,000
Number of single family lots sold | lot		1		1
Sale of interest in leasehold land		$ 310,000		$ 310,000
Kaupulehu Developments | KD Kaupulehu LLLP Increment II
Investment [Line Items]
Number of lots developed | lot				2
Percent of Increment II distributions				50.00%		50.00%
Contingent payments, unrecorded	$ 8,000,000	8,000,000		$ 8,000,000		$ 8,000,000	$ 8,000,000
Increment II distributions received to date	1,000,000					$ 2,500,000	3,500,000
Fees related to land payments	$ 137,000	$ 137,000		$ 137,000			$ 137,000
Kaupulehu Developments | KD Kaupulehu LLLP Increment II | Minimum
Investment [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	2		2			2
Kaupulehu Developments | KD Kaupulehu LLLP Increment II | Maximum
Investment [Line Items]
Payments entitled to be received as percentage of gross proceeds from sale of single family lots				10.00%
Sale of interest in leasehold land					$ 1,678,000
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	3		3			3
Kaupulehu Developments | Aggregate Gross Proceeds Range Two | KD Kaupulehu LLLP Increment I
Investment [Line Items]
Payments entitled to be received as percentage of gross proceeds from sale of single family lots				10.00%
Kaupulehu Developments | Aggregate Gross Proceeds Range Two | KD Kaupulehu LLLP Increment I | Minimum
Investment [Line Items]
Aggregate gross proceeds from sale of Increment I single family lots for calculating payments entitled to be received				$ 100,000,000
Kaupulehu Developments | Aggregate Gross Proceeds Range Two | KD Kaupulehu LLLP Increment I | Maximum
Investment [Line Items]
Aggregate gross proceeds from sale of Increment I single family lots for calculating payments entitled to be received				$ 300,000,000
Kaupulehu Developments | Aggregate Gross Proceeds Range Three | KD Kaupulehu LLLP Increment I
Investment [Line Items]
Payments entitled to be received as percentage of gross proceeds from sale of single family lots				14.00%
Kaupulehu Developments | Aggregate Gross Proceeds Range Three | KD Kaupulehu LLLP Increment I | Minimum
Investment [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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INVESTMENTS - PERCENTAGE OF SALES PAYMENTS (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Investment Holdings [Line Items]
Revenues - sale of interest in leasehold land	$ 1,310	$ 0	$ 1,310	$ 1,678
Kaupulehu Developments
Investment Holdings [Line Items]
Revenues - sale of interest in leasehold land	1,310	0	1,310	1,678
Fees - included in general and administrative expenses	(175)	0	(175)	(260)
Proceeds from sale of interest in leasehold land, net of fees paid	$ 1,135	$ 0	$ 1,135	$ 1,418

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INVESTMENTS - LOT 4C (Details) a in Thousands	Jun. 30, 2018 a
Land Interest
Investment [Line Items]
Area of land (in acres)	1

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OIL AND NATURAL GAS PROPERTIES AND ASSET RETIREMENT OBLIGATION (Details) $ in Thousands	1 Months Ended		3 Months Ended	9 Months Ended
	Feb. 28, 2018 USD ($) party	Oct. 31, 2017 USD ($)	Mar. 31, 2018 USD ($)	Jun. 30, 2018 USD ($)	Jun. 30, 2017 USD ($)	Sep. 30, 2017 USD ($)
Oil and Natural Gas Properties [Line Items]
Proceeds from the sale of oil and natural gas properties				$ 770	$ 1,238
Income taxes receivable				2,231		$ 1,145
Gain on sale of oil and natural gas properties				2,250	0
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation as of beginning of period		$ 6,863		6,863
Obligation incurred on new well drilled				9
Liabilities associated with properties sold				(1,752)
Revision of estimated obligation				(323)
Accretion expense				211	$ 296
Payments				(589)
Foreign currency translation adjustment				(200)
Asset retirement obligation as of end of period				4,219
Less current portion				(410)		(1,231)
Asset retirement obligation, long-term				3,809		$ 5,632
Pouce Coupe
Oil and Natural Gas Properties [Line Items]
Proceeds from the sale of oil and natural gas properties		$ 79
Income taxes receivable				37
Red Earth
Oil and Natural Gas Properties [Line Items]
Proceeds from the sale of oil and natural gas properties	$ 1,360
Income taxes receivable				752
Number of separate independent third parties | party	2
Percent difference in capitalized costs divided by proved reserves if the gain is recorded as opposed to being credited against the full-cost pool	322.00%
Gain on sale of oil and natural gas properties				2,135
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Liabilities associated with properties sold				$ (1,666)
Stolberg
Oil and Natural Gas Properties [Line Items]
Proceeds from the sale of oil and natural gas properties	$ 120
Gain on sale of oil and natural gas properties			$ 115

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RETIREMENT PLANS (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Pension Plan
Net periodic benefit cost:
Service cost (credit)	$ 54	$ 34	$ 162	$ 178
Interest cost	88	78	266	252
Expected return on plan assets	(147)	(122)	(443)	(404)
Amortization of prior service cost (credit)	2	2	5	4
Amortization of net actuarial loss	25	21	74	103
Net periodic benefit cost	22	13	64	133
Other disclosures
Contribution by the entity to the Pension Plan			200
Estimated future employer contributions	300		300
SERP
Net periodic benefit cost:
Service cost (credit)	10	(5)	30	26
Interest cost	19	1	57	42
Expected return on plan assets	0	0	0	0
Amortization of prior service cost (credit)	(1)	(2)	(4)	(4)
Amortization of net actuarial loss	3	(17)	10	0
Net periodic benefit cost	31	(23)	93	64
Postretirement Medical
Net periodic benefit cost:
Service cost (credit)	0	0	0	0
Interest cost	19	22	57	66
Expected return on plan assets	0	0	0	0
Amortization of prior service cost (credit)	0	0	0	0
Amortization of net actuarial loss	2	47	8	141
Net periodic benefit cost	$ 21	$ 69	$ 65	$ 207

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INCOME TAXES (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Components of income (loss) before income taxes, after adjusting the income (loss) for non-controlling interests
United States	$ (12)	$ (619)	$ (2,137)	$ 792
Canada	(525)	(335)	956	(954)
Total	(537)	(954)	(1,181)	(162)
Components of the income tax provision (benefit)
Current	(60)	(392)	(889)	(740)
Deferred	(103)	(50)	420	64
Total	$ (163)	$ (442)	$ (469)	$ (676)
Blended federal statutory income tax rate			24.50%
Income tax benefit from AMT credit carryover refund provision			$ 460

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SEGMENT INFORMATION (Details) - USD ($)	3 Months Ended			9 Months Ended
	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Revenues:
Revenues	$ 3,122,000		$ 1,319,000	$ 6,862,000	$ 8,602,000
Interest income	46,000		21,000	137,000	57,000
Total revenues	3,168,000		1,340,000	6,999,000	8,659,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	187,000		234,000	694,000	942,000
Impairment:
Impairment	165,000		0	202,000	0
Operating (loss) profit (before general and administrative expenses):
Operating profit (loss)	1,152,000		399,000	3,661,000	3,314,000
Equity in income (loss) of affiliates:
Land investment	136,000		(31,000)	(97,000)	2,125,000
General and administrative expenses	(1,591,000)		(1,345,000)	(4,635,000)	(5,126,000)
Interest income	46,000		21,000	137,000	57,000
(Loss) earnings before income taxes	(257,000)		(956,000)	(934,000)	370,000
Oil and natural gas
Revenues:
Revenues	616,000		940,000	2,428,000	3,490,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	121,000		145,000	477,000	672,000
Operating (loss) profit (before general and administrative expenses):
Operating profit (loss)	(49,000)		175,000	174,000	552,000
Land investment
Revenues:
Revenues	1,310,000		0	1,310,000	1,678,000
Impairment:
Impairment	0	$ 37,000	0	37,000	0
Operating (loss) profit (before general and administrative expenses):
Operating profit (loss)	1,310,000		0	1,273,000	1,678,000
Contract drilling
Revenues:
Revenues	1,193,000		360,000	3,051,000	3,346,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	55,000		69,000	169,000	205,000
Operating (loss) profit (before general and administrative expenses):
Operating profit (loss)	64,000		(302,000)	104,000	534,000
Other
Revenues:
Revenues	3,000		19,000	73,000	88,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	11,000		20,000	48,000	65,000
Impairment:
Impairment	165,000		0	165,000	0
Operating (loss) profit (before general and administrative expenses):
Operating profit (loss)	(173,000)		(1,000)	(140,000)	23,000
Gain on sales of assets
Operating (loss) profit (before general and administrative expenses):
Operating profit (loss)	$ 0		$ 527,000	2,250,000	$ 527,000
Intersegment Eliminations
Revenues:
Revenues				$ 0

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ACCUMULATED OTHER COMPREHENSIVE LOSS (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Sep. 30, 2017
Foreign currency translation:
Beginning accumulated foreign currency translation	$ 866	$ 858	$ 1,053	$ 906
Change in cumulative translation adjustment before reclassifications	(76)	81	(263)	33
Income taxes	0	0	0	0
Net current period other comprehensive (loss) income	(76)	81	(263)	33
Ending accumulated foreign currency translation	790	939	790	939
Retirement plans:
Beginning accumulated retirement plans benefit cost	(2,048)	(4,633)	(2,111)	(4,826)
Amortization of net actuarial loss and prior service cost	30	51	93	244
Income taxes	0	0	0	0
Net current period other comprehensive income	30	51	93	244
Ending accumulated retirement plans benefit cost	(2,018)	(4,582)	(2,018)	(4,582)
Accumulated other comprehensive loss, net of taxes	$ (1,228)	$ (3,643)	$ (1,228)	$ (3,643)	$ (1,058)

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FAIR VALUE MEASUREMENTS (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended			9 Months Ended
	Mar. 31, 2018	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of assets		$ 165		$ 0	$ 202	$ 0
Residential Parcel [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proceeds from sale of property held-for-sale	$ 1,000
Impairment of assets			$ 37

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INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Details) - USD ($) $ in Thousands	9 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Supplemental disclosure of cash flow information:
Interest	$ 3	$ 6
Income taxes refunded, net	(20)	(137)
Supplemental disclosure of non-cash investing activities:
Canadian income tax withholding on proceeds from the sale of oil and natural gas properties	789	0
Oil and natural gas
Supplemental disclosures of cash flow information:
Decrease in capital expenditure accruals related to oil and natural gas exploration and development	152	199
Decrease in capital expenditure accruals related to oil and natural gas asset retirement obligations	$ 399	$ 62

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RELATED PARTY TRANSACTIONS (Details)	3 Months Ended		9 Months Ended
	Jun. 30, 2018 USD ($)	Jun. 30, 2017 USD ($)	Jun. 30, 2018 USD ($) lot	Jun. 30, 2017 USD ($) lot
Related party transactions
Revenues - sale of interest in leasehold land	$ 1,310,000	$ 0	$ 1,310,000	$ 1,678,000
Kaupulehu Developments
Related party transactions
Revenues - sale of interest in leasehold land	1,310,000	$ 0	$ 1,310,000	1,678,000
Kaupulehu Developments | Investment in Kukio Resort Land Development Partnerships | KD Kaupulehu LLLP Increment II
Related party transactions
Percent of Increment II distributions			50.00%
Contingent payments, unrecorded	8,000,000		$ 8,000,000
Revenues - sale of interest in leasehold land			$ 1,000,000	$ 1,678,000
Number of single family lots sold | lot				1
Kaupulehu Developments | Investment in Kukio Resort Land Development Partnerships | KD Kaupulehu, LLLP
Related party transactions
Percent of Increment II distributions			50.00%
Contingent payments, unrecorded	$ 8,000,000		$ 8,000,000
Increment II distributions received to date			$ 3,500,000
Ownership interest acquired	19.60%		19.60%
Revenues - sale of interest in leasehold land			$ 1,310,000
Kaupulehu Developments | Investment in Kukio Resort Land Development Partnerships | KD Kaupulehu LLLP Increment I
Related party transactions
Revenues - sale of interest in leasehold land			$ 310,000
Number of single family lots sold | lot			1

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SUBSEQUENT EVENTS (Details) - USD ($) $ in Thousands	1 Months Ended		3 Months Ended		9 Months Ended
	Aug. 31, 2018	Jul. 31, 2018	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Subsequent Event [Line Items]
Sale of interest in leasehold land			$ 1,310	$ 0	$ 1,310	$ 1,678
Kaupulehu Developments
Subsequent Event [Line Items]
Sale of interest in leasehold land			$ 1,310	$ 0	$ 1,310	$ 1,678
Kaupulehu Developments | Subsequent Event
Subsequent Event [Line Items]
Sale of interest in leasehold land		$ 165
Kaupulehu 2007, LLLP | Subsequent Event
Subsequent Event [Line Items]
Proceeds from sale of property held-for-sale	$ 1,000
Purchase and Sale Agreement | Subsequent Event
Subsequent Event [Line Items]
Collaborative agreement, non-refundable deposit, percentage		5.00%
Collaborative agreement, non-refundable deposit, amount		$ 525
Purchase and Sale Agreement | Barnwell Industries Inc | Subsequent Event
Subsequent Event [Line Items]
Collaborative agreement, purchase price		$ 10,500