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, ~~2017~~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 ~~7, 2017~~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, ~~2017~~2018 and September 30, ~~2016~~2017	3
	Condensed Consolidated Statements of Operations - three and nine months ended June 30, ~~2017~~2018 and ~~2016~~2017	4
	Condensed Consolidated Statements of Comprehensive (Loss) Income ~~(Loss)~~ - three and nine months ended June 30, ~~2017~~2018 and ~~2016~~2017	5
	Condensed Consolidated Statements of Equity - nine months ended June 30, ~~2017~~2018 and ~~2016~~2017	6
	Condensed Consolidated Statements of Cash Flows - nine months ended June 30, ~~2017~~2018 and ~~2016~~2017	7
	Notes to Condensed Consolidated Financial Statements	8
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	1922
Item 4.	Controls and Procedures	3436
PART II.	OTHER INFORMATION:
Item 6.	Exhibits	3538
	Signature	3639
	Index to Exhibits	3740

PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


	June 30, 2017				September 30, 2016			June 30, 2018				September 30, 2017
ASSETS
Current assets:
Cash and cash equivalents	$	16,124,000			$	15,550,000		$	13,539,000			$	16,281,000
Certificates of deposit	2,480,000				—			3,460,000				4,413,000
Restricted cash	—				381,000
Accounts and other receivables, net of allowance for doubtful accounts of: $52,000 at June 30, 2017; $40,000 at September 30, 2016	1,766,000				1,228,000
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	989,000				378,000			2,231,000				1,145,000
Asset held for sale	—				1,829,000
Investment held for sale	1,192,000				1,192,000			1,000,000				1,037,000
Other current assets	916,000				556,000			1,269,000				852,000
Total current assets	23,467,000				21,114,000			22,913,000				25,142,000
Income taxes receivable, net of current portion								460,000				—
Deferred income tax assets								—				300,000
Investments	2,861,000				3,552,000			1,695,000				2,209,000
Property and equipment	75,938,000				76,868,000			58,858,000				79,231,000
Accumulated depletion, depreciation, and amortization	(71,288,000		)		(69,966,000		)	(55,385,000		)		(73,862,000		)
Property and equipment, net	4,650,000				6,902,000			3,473,000				5,369,000
Total assets	$	30,978,000			$	31,568,000		$	28,541,000			$	33,020,000

LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	1,160,000			$	1,423,000		$	1,158,000			$	1,185,000
Accrued capital expenditures	241,000				439,000			184,000				348,000
Accrued operating and other expenses	1,042,000				1,031,000			1,013,000				1,386,000
Accrued compensation	495,000				449,000			446,000				390,000
Current portion of asset retirement obligation	1,040,000				1,017,000			410,000				1,231,000
Other current liabilities	446,000				377,000			63,000				258,000
Total current liabilities	4,424,000				4,736,000			3,274,000				4,798,000
Deferred rent								86,000				21,000
Liability for retirement benefits	6,508,000				6,707,000			4,064,000				4,150,000
Asset retirement obligation	5,319,000				6,177,000			3,809,000				5,632,000
Deferred income taxes	267,000				204,000
Deferred income tax liabilities								353,000				236,000
Total liabilities	16,518,000				17,824,000			11,586,000				14,837,000
Commitments and contingencies (Note 13)
Commitments and contingencies
Equity:
Common stock, par value $0.50 per share; authorized, 20,000,000 shares: 8,445,060 issued at June 30, 2017 and September 30, 2016	4,223,000				4,223,000
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	1,349,000				1,345,000			1,351,000				1,350,000
Retained earnings	14,366,000				13,852,000			14,311,000				15,023,000
Accumulated other comprehensive loss, net	(3,643,000		)		(3,920,000		)	(1,228,000		)		(1,058,000		)
Treasury stock, at cost: 167,900 shares at June 30, 2017 and September 30, 2016	(2,286,000		)		(2,286,000		)
Treasury stock, at cost: 167,900 shares at June 30, 2018 and September 30, 2017								(2,286,000		)		(2,286,000		)
Total stockholders' equity	14,009,000				13,214,000			16,371,000				17,252,000
Non-controlling interests	451,000				530,000			584,000				931,000
Total equity	14,460,000				13,744,000			16,955,000				18,183,000
Total liabilities and equity	$	30,978,000			$	31,568,000		$	28,541,000			$	33,020,000

See Notes to Condensed Consolidated Financial Statements

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)


	Three months ended June 30,								Nine months ended June 30,							Three months ended June 30,								Nine months ended June 30,
	2017				2016				2017				2016			2018				2017				2018				2017
Revenues:
Oil and natural gas	$	940,000			$	768,000			$	3,490,000			$	2,237,000		$	616,000			$	940,000			$	2,428,000			$	3,490,000
Contract drilling	360,000				120,000				3,346,000				1,502,000			1,193,000				360,000				3,051,000				3,346,000
Sale of interest in leasehold land	—				1,775,000				1,678,000				2,255,000			1,310,000				—				1,310,000				1,678,000
Residential real estate	—				5,700,000				—				5,700,000
Gas processing and other	40,000				126,000				145,000				237,000			49,000				40,000				210,000				145,000
	1,340,000				8,489,000				8,659,000				11,931,000			3,168,000				1,340,000				6,999,000				8,659,000
Costs and expenses:
Oil and natural gas operating	620,000				757,000				2,266,000				2,510,000			544,000				620,000				1,777,000				2,266,000
Contract drilling operating	593,000				263,000				2,607,000				1,431,000			1,074,000				593,000				2,778,000				2,607,000
Residential real estate	—				5,510,000				—				5,510,000
General and administrative	1,344,000				1,709,000				5,119,000				5,145,000			1,591,000				1,345,000				4,635,000				5,126,000
Depletion, depreciation, and amortization	234,000				448,000				942,000				1,201,000			187,000				234,000				694,000				942,000
Impairment of oil and natural gas properties	—				1,154,000				—				1,154,000
Impairment of assets																165,000				—				202,000				—
Gain on sales of assets	(527,000		)		(472,000		)		(527,000		)		(472,000		)	—				(527,000		)		(2,250,000		)		(527,000		)
Interest expense	1,000				19,000				7,000				85,000
	2,265,000				9,388,000				10,414,000				16,564,000			3,561,000				2,265,000				7,836,000				10,414,000
Loss before equity in (loss) income of affiliates and income taxes	(925,000		)		(899,000		)		(1,755,000		)		(4,633,000		)
Equity in (loss) income of affiliates	(31,000		)		2,200,000				2,125,000				2,616,000
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	(956,000		)		1,301,000				370,000				(2,017,000		)	(257,000		)		(956,000		)		(934,000		)		370,000
Income tax benefit	(442,000		)		(72,000		)		(676,000		)		(529,000		)	(163,000		)		(442,000		)		(469,000		)		(676,000		)
Net (loss) earnings	(514,000		)		1,373,000				1,046,000				(1,488,000		)	(94,000		)		(514,000		)		(465,000		)		1,046,000
Less: Net (loss) earnings attributable to non-controlling interests	(2,000		)		598,000				532,000				754,000
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.	$	(512,000	)		$	775,000			$	514,000			$	(2,242,000	)	$	(374,000	)		$	(512,000	)		$	(712,000	)		$	514,000
Basic and diluted net (loss) earnings per common share attributable to Barnwell Industries, Inc. stockholders	$	(0.06	)		$	0.09			$	0.06			$	(0.27	)	$	(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			8,277,160				8,277,160				8,277,160				8,277,160

See Notes to Condensed Consolidated Financial Statements

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS) INCOME ~~(LOSS)~~

(Unaudited)


	Three months ended June 30,								Nine months ended June 30,							Three months ended June 30,								Nine months ended June 30,
	2017				2016				2017				2016			2018				2017				2018				2017
Net (loss) earnings	$	(514,000	)		$	1,373,000			$	1,046,000			$	(1,488,000	)	$	(94,000	)		$	(514,000	)		$	(465,000	)		$	1,046,000
Other comprehensive income (loss):
Other comprehensive (loss) income:
Foreign currency translation adjustments, net of taxes of $0	81,000				(3,000		)		33,000				113,000			(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	51,000				50,000				244,000				127,000			30,000				51,000				93,000				244,000
Total other comprehensive income	132,000				47,000				277,000				240,000
Total other comprehensive (loss) income																(46,000		)		132,000				(170,000		)		277,000
Total comprehensive (loss) income	(382,000		)		1,420,000				1,323,000				(1,248,000		)	(140,000		)		(382,000		)		(635,000		)		1,323,000
Less: Comprehensive (loss) income attributable to non-controlling interests	(2,000		)		598,000				532,000				754,000
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.	$	(380,000	)		$	822,000			$	791,000			$	(2,002,000	)	$	(420,000	)		$	(380,000	)		$	(882,000	)		$	791,000

See Notes to Condensed Consolidated Financial Statements

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

Nine months ended June 30, ~~2017~~2018 and ~~2016~~2017

(Unaudited)


	Shares Outstanding			Common Stock				Additional Paid-In Capital				Retained Earnings				Accumulated Other Comprehensive Income (Loss)				Treasury Stock				Non-controlling Interests				Total Equity
Balance at September 30, 2015	8,277,160			$	4,223,000			$	1,335,000			$	17,467,000			$	(2,122,000	)		$	(2,286,000	)		$	645,000			$	19,262,000
Distributions to non-controlling interests	—			—				—				—				—				—				(866,000		)		(866,000		)
Net earnings (loss)	—			—				—				(2,242,000		)		—				—				754,000				(1,488,000		)
Share-based compensation	—			—				8,000				—				—				—				—				8,000
Foreign currency translation adjustments, net of taxes of $0	—			—				—				—				113,000				—				—				113,000
Retirement plans - amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	—			—				—				—				127,000				—				—				127,000
Balance at June 30, 2016	8,277,160			$	4,223,000			$	1,343,000			$	15,225,000			$	(1,882,000	)		$	(2,286,000	)		$	533,000			$	17,156,000
																															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		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			—			—				—				—				—				—				6,000				6,000
Distributions to non-controlling interests	—			—				—				—				—				—				(617,000		)		(617,000		)	—			—				—				—				—				—				(617,000		)		(617,000		)
Net earnings	—			—				—				514,000				—				—				532,000				1,046,000			—			—				—				514,000				—				—				532,000				1,046,000
Share-based compensation	—			—				4,000				—				—				—				—				4,000			—			—				4,000				—				—				—				—				4,000
Foreign currency translation adjustments, net of taxes of $0	—			—				—				—				33,000				—				—				33,000			—			—				—				—				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			—			—				—				—				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		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

BARNWELL INDUSTRIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	Nine months ended June 30,							Nine months ended June 30,
	2017				2016			2018				2017
Cash flows from operating activities:
Net earnings (loss)	$	1,046,000			$	(1,488,000	)
Adjustments to reconcile net earnings (loss) to net cash
(used in) provided by operating activities:
Equity in income of affiliates	(2,125,000		)		(2,616,000		)
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	942,000				1,201,000			694,000				942,000
Impairment of oil and natural gas properties	—				1,154,000
Gain on sale of asset	(527,000		)		—			—				(527,000		)
Gain on sale of oil and natural gas properties	—				(472,000		)	(2,250,000		)		—
Impairment of assets								202,000				—
Distribution of income from equity investees	2,164,000				3,714,000			—				2,164,000
Retirement benefits expense	404,000				389,000			222,000				404,000
Income tax receivable								(460,000		)		—
Deferred rent liability								65,000				—
Accretion of asset retirement obligation	296,000				345,000			211,000				296,000
Deferred income tax expense (benefit)	64,000				(2,000		)
Deferred income tax expense								420,000				64,000
Asset retirement obligation payments	(713,000		)		(217,000		)	(589,000		)		(713,000		)
Share-based compensation expense (benefit)	23,000				(33,000		)
Share-based compensation (benefit) expense								(6,000		)		23,000
Retirement plan contributions and payments	(359,000		)		(1,104,000		)	(215,000		)		(359,000		)
Sale of interest in leasehold land, net of fees paid	(1,418,000		)		(1,915,000		)	(1,272,000		)		(1,418,000		)
Real estate held for sale	—				5,132,000
Decrease from changes in current assets and liabilities	(1,627,000		)		(1,044,000		)	(975,000		)		(1,627,000		)
Net cash (used in) provided by operating activities	(1,830,000		)		3,044,000
Net cash used in operating activities								(4,321,000		)		(1,830,000		)
Cash flows from investing activities:
Purchase of certificates of deposit	(2,480,000		)		—			(3,958,000		)		(2,480,000		)
Decrease in restricted cash	—				7,089,000
Proceeds from the maturity of certificates of deposit								4,911,000				—
Distribution from equity investees in excess of earnings	652,000				1,646,000			417,000				652,000
Proceeds from sale of interest in leasehold land, net of fees paid	1,418,000				1,915,000
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				—			—				2,360,000
Proceeds from the sale of oil and natural gas properties	1,238,000				—
Proceeds from sale of oil and natural gas assets								770,000				1,238,000
Capital expenditures - oil and natural gas	(498,000		)		(673,000		)	(473,000		)		(498,000		)
Capital expenditures - all other	(120,000		)		(45,000		)	(114,000		)		(120,000		)
Net cash provided by investing activities	2,570,000				9,932,000			2,482,000				2,570,000
Cash flows from financing activities:
Repayments of long-term debt	—				(3,440,000		)
Distributions to non-controlling interests	(617,000		)		(866,000		)	(594,000		)		(617,000		)
Contributions from non-controlling interests	6,000				—			—				6,000
Decrease in restricted cash	372,000				54,000			—				372,000
Net cash used in financing activities	(239,000		)		(4,252,000		)	(594,000		)		(239,000		)
Effect of exchange rate changes on cash and cash equivalents	73,000				238,000			(309,000		)		73,000
Net increase in cash and cash equivalents	574,000				8,962,000
Net (decrease) increase in cash and cash equivalents								(2,742,000		)		574,000
Cash and cash equivalents at beginning of period	15,550,000				8,471,000			16,281,000				15,550,000
Cash and cash equivalents at end of period	$	16,124,000			$	17,433,000		$	13,539,000			$	16,124,000

See Notes to Condensed Consolidated Financial Statements

BARNWELL INDUSTRIES, INC.

AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Principles of Consolidation

The condensed consolidated financial statements include the accounts of Barnwell Industries, Inc. and all majority-owned subsidiaries (collectively referred to herein as “Barnwell,” “we,” “our,” “us,” or the “Company”), including a 77.6%-owned land investment general partnership (Kaupulehu Developments), a 75%-owned land investment partnership (KD Kona 2013 LLLP) and ~~two~~an 80%-owned joint ~~ventures~~venture (Kaupulehu 2007, ~~LLLP and Kaupulehu Investors, LLC)~~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.~~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, ~~2016~~2017 Annual Report on Form 10-K. The Condensed Consolidated Balance Sheet as of September 30, ~~2016~~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, ~~2017,~~2018, results of operations and comprehensive (loss) income ~~(loss)~~ for the three and nine months ended June 30, ~~2017~~2018 and ~~2016,~~2017, and equity and cash flows for the nine months ended June 30, ~~2017~~2018 and ~~2016,~~2017, have been made. The results of operations for the period ended June 30, ~~2017~~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.

~~Reclassifications~~

Fees related to percentage of sales payments have been reclassified to general and administrative expenses rather than being presented net with sale of interest in leasehold land revenues for the prior year periods to conform to the current year periods presentation.

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 ~~January 2015,~~March 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. ~~2015-01,~~2016-07, “Simplifying ~~Income Statement Presentation by Eliminating~~ the ~~Concept~~Transition to the Equity Method of ~~Extraordinary Items,~~Accounting,” which eliminates the ~~concept~~requirement that when an investment subsequently qualifies for use of the equity method as a result of an ~~extraordinary item from GAAP. As~~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 ~~result,~~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 ~~will no longer be required to separately classify, present and disclose extraordinary events and transactions.~~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, ~~2016.~~2017. The adoption of this update did not have ~~a material~~an impact on Barnwell’s consolidated financial statements.

In ~~February 2015,~~March 2016, the FASB issued ASU No. ~~2015-02, "Amendments~~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 ~~Consolidation Analysis," which simplifies the current consolidation guidance and will require companies to reevaluate limited partnerships and similar entities for consolidation.~~financial statements. The Company adopted the provisions of this ASU effective October 1, ~~2016.~~2017. The adoption of this update did not have ~~a material~~an impact on Barnwell’s consolidated financial statements.

In ~~April 2015,~~October 2016, the FASB issued ASU No. ~~2015-03, "Simplifying~~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 ~~Presentation~~primary beneficiary of ~~Debt Issuance Costs." This amendment was issued to simplify~~ the ~~presentation~~VIE as part of ~~debt issuance costs by requiring debt issuance costs~~the analysis of whether the VIE would need to be ~~presented as~~consolidated. Under this ASU, a ~~deduction from~~decision maker would need to consider only its proportionate indirect interest in the ~~corresponding debt liability. This will make the presentation of debt issuance costs consistent with the presentation of debt discounts or premiums.~~VIE held through a common control party. The Company adopted the provisions of this ASU effective October 1, ~~2016.~~2017. The adoption of this update did not have ~~a material impact on Barnwell’s consolidated financial statements.~~

In July 2015, the FASB issued ASU No. 2015-12, "Plan Accounting: (Part I) Fully Benefit-Responsive Investment Contracts, (Part II) Plan Investment Disclosures, (Part III) Measurement Date Practical Expedient." This ASU aims to simplify the accounting and presentation of plan accounting. Part I of this ASU requires fully benefit-responsive investment contracts to be measured at contract value instead of the current fair value measurement. Part II simplifies the investment disclosure requirements for employee benefit plans. Part III provides an alternative measurement date for fiscal periods that do not coincide with a month-end date. The Company adopted the provisions of this ASU effective October 1, 2016. The adoption of this update did not have a material impact on Barnwell’s consolidated financial statements.

In September 2015, the FASB issued ASU No. 2015-16, "Simplifying the Accounting for Measurement-Period Adjustments." This ASU eliminates the requirement to account for business combination measurement period adjustments retrospectively. Measurement period adjustments will now be recognized prospectively in the reporting period in which the adjustment amount is determined. The nature and amount of any measurement period adjustments recognized during the reporting period must be disclosed, including the value of the adjustment to each current period income statement line item relating to the income

effects that would have been recognized in previous periods if the adjustment to provisional amounts were recognized as of the acquisition date. The Company adopted the provisions of this ASU effective October 1, 2016. The adoption of this update did not have a material impact on Barnwell’s consolidated financial statements.

2. (LOSS) EARNINGS ~~(LOSS)~~ PER COMMON SHARE

Basic (loss) earnings ~~(loss)~~ per share is computed using the weighted-average number of common shares outstanding for the period. Diluted (loss) earnings ~~(loss)~~ per share is calculated using the treasury stock method to reflect the assumed issuance of common shares for all potentially dilutive securities, which consist of outstanding stock options. Potentially dilutive shares are excluded from the computation of diluted (loss) earnings ~~(loss)~~ 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, ~~and 2016,~~respectively, as their inclusion would have been antidilutive.

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


	Three months ended June 30, 2017										Three months ended June 30, 2018
	Net Loss (Numerator)				Shares (Denominator)			Per-Share Amount			Net Loss (Numerator)				Shares (Denominator)			Per-Share Amount
Basic net loss per share	$	(512,000	)		8,277,160			$	(0.06	)	$	(374,000	)		8,277,160			$	(0.05	)
Effect of dilutive securities -
common stock options	—				—						—				—
Diluted net loss per share	$	(512,000	)		8,277,160			$	(0.06	)	$	(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

Three months ended June 30, 2016

Net Earnings
(Numerator)

Shares
(Denominator)

Per-Share
Amount
Basic net earnings per share $ 775,000
8,277,160
$ 0.09
Effect of dilutive securities -

common stock options —
—

Diluted net earnings per share $ 775,000
8,277,160
$ 0.09

Nine months ended June 30, 2016

Net Loss
(Numerator)

Shares
(Denominator)

Per-Share
Amount
Basic net loss per share $ (2,242,000 ) 8,277,160
$ (0.27 )
Effect of dilutive securities -

common stock options —
—

Diluted net loss per share $ (2,242,000 ) 8,277,160
$ (0.27 )

3.~~ASSET HELD FOR SALE~~

The Company's New York office was designated as an asset held for sale and the carrying value in the aggregate amount of $1,829,000 was included in "Asset held for sale" on the Company's Condensed Consolidated Balance Sheet at September 30, 2016. On May 2, 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.

4. INVESTMENT HELD FOR SALE

At June 30, ~~2017,~~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).

5.4. INVESTMENTS

A summary of Barnwell’s investments is as follows:


	June 30, 2017				September 30, 2016			June 30, 2018				September 30, 2017
Investment in Kukio Resort land development partnerships	$	2,811,000			$	3,502,000
Investment in Kukio Resort Land Development Partnerships								$	1,645,000			$	2,159,000
Investment in leasehold land interest – Lot 4C	50,000				50,000			50,000				50,000
Total investments	$	2,861,000			$	3,552,000		$	1,695,000			$	2,209,000

Investment in Kukio Resort ~~land development partnerships~~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. ~~KD Kaupulehu, LLLP, which is comprised of~~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 ~~Increments~~Increment I, and KD II is the ~~area in which Barnwell has~~developer of Kaupulehu Lot 4A Increment II. Barnwell's ownership interests in ~~percentage of sales payments. Barnwell’s investment in these entities~~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 ~~commission~~commissions on real estate sales by the real estate sales office. As of June 30, ~~2017, 25~~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~~Land Development Partnerships after distributing $44,000 and $307,000, to minority interests. During the nine months ended June 30, 2016, Barnwell received net cash distributions in the amount of $5,320,000 from the Kukio Resort land development partnerships after distributing $40,000respectively, to minority interests.

Barnwell's share of the ~~loss~~operating results of its equity affiliates was ~~$31,000 for the three months ended June 30, 2017. Equity in~~ income of ~~affiliates was $2,125,000 for the nine months ended June 30, 2017~~$136,000 and ~~$2,200,000 and $2,616,000~~a loss of $97,000 for the three and nine months ended June 30, ~~2016,~~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~~Land Development Partnerships exceeds the carrying value of the investment in affiliates by approximately ~~$331,000~~$316,000 as of June 30, ~~2017,~~2018, which is attributable to differences in the value of capitalized development costs and a note receivable. The basis difference ~~will be~~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 ~~$20,000 for the nine months ended June 30, 2017~~ $3,000and ~~$17,000 and $34,000~~$6,000 for the three and nine months ended June 30, ~~2016,~~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.

Barnwell, as well as KD I, KD II and certain other owners of the partnerships, have jointly and severally executed a surety indemnification agreement. Bonds issued by the surety at June 30, 2017 totaled approximately $325,000 and relate to certain construction contracts of KD I. If any such performance bonds are called, we may be obligated to reimburse the issuer of the performance bond as Barnwell, KD I and certain other partners are jointly and severally liable, however we believe that it is remote that a material amount of any currently outstanding performance bonds will be called. Performance bonds do not have stated expiration dates. Rather, the performance bonds are released as the underlying performance is completed.

As of June 30, 2017, Barnwell’s maximum loss exposure as a result of its investment in the Kukio Resort land development partnerships was approximately $3,136,000, consisting of the carrying value of the investment of $2,811,000 and $325,000 from the surety indemnification agreement of which we are jointly and severally liable.

Summarized financial information for the Kukio Resort ~~land development partnerships~~Land Development Partnerships is as follows:


	Three months ended June 30,							Three months ended June 30,
	2017				2016			2018				2017
Revenue	$	956,000			$	23,584,000		$	3,559,000			$	956,000
Gross profit	$	396,000			$	10,732,000		$	1,777,000			$	396,000
Net earnings	$	57,000			$	10,029,000		$	841,000			$	57,000


	Nine months ended June 30,							Nine months ended June 30,
	2017				2016			2018				2017
Revenue	$	27,152,000			$	31,703,000		$	7,348,000			$	27,152,000
Gross profit	$	12,346,000			$	14,186,000		$	3,511,000			$	12,346,000
Net earnings	$	10,119,000			$	12,020,000		$	153,000			$	10,119,000

~~Percentage~~Sale of ~~sales payments~~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 ~~15)~~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 ~~proceeds~~revenues received from KD I and KD ~~II.~~II and the amount of fees directly related to such revenues:


	Three months ended June 30,								Nine months ended June 30,							Three months ended June 30,								Nine months ended June 30,
	2017				2016				2017				2016			2018				2017				2018				2017
Sale of interest in leasehold land:
Revenues - sale of interest in leasehold land	$	—			$	1,775,000			$	1,678,000			$	2,255,000		$	1,310,000			$	—			$	1,310,000			$	1,678,000
Fees - included in general and administrative expenses	—				(273,000		)		(260,000		)		(340,000		)	(175,000		)		—				(175,000		)		(260,000		)
Proceeds from sale of interest in leasehold land, net of fees paid	$	—			$	1,502,000			$	1,418,000			$	1,915,000		$	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.

6.5. OIL AND NATURAL GAS PROPERTIES AND ASSET RETIREMENT OBLIGATION

Full cost properties

In ~~June~~October 2017, Barnwell entered into a Purchase and Sale Agreement with an independent third party and sold ~~a portion of~~ its oil and natural gas ~~property~~properties located in the ~~Progress and Valhalla areas~~Pouce Coupe area of Alberta, Canada. The sales price per the agreement was adjusted to $79,000 for customary purchase price adjustments to ~~$1,076,000 in order to, among other things,~~ reflect anthe economic activity from the effective date of ~~April~~May 1, ~~2017.~~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, ~~$552,000~~$752,000 was withheld and remitted by the buyer to the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income ~~taxes related to the sale, which is included in “Income taxes receivable” on the Condensed Consolidated Balance Sheet at June 30, 2017.~~taxes.

During the nine months ended June 30, 2017, Barnwell also sold miscellaneous oil and natural gas properties for proceeds of $162,000, of which $67,000 was withheld and remitted by the buyer to the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes related to the sales which is included in “Income taxes receivable” on the Condensed Consolidated Balance Sheet at June 30, 2017.

~~No gain or loss was recognized related to these dispositions as these sales to multiple counterparties~~The difference in ~~unrelated transactions did not individually, or in aggregate, result in a significant alteration of~~ the relationship between capitalized costs and proved ~~reserves.~~

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.

7. ~~LONG-TERM DEBT~~

~~Canadian revolving demand facility~~Other properties

In ~~June 2016,~~February 2018, Barnwell ~~entered into an agreement with Royal Bank~~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 ~~revolving demand facility~~$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 ~~amount~~period in which it is incurred if a reasonable estimate of ~~$500,000 Canadian dollars. Borrowings under this facility~~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 ~~$0 at September~~reduced by $1,752,000 during the nine months ended June 30, ~~2016. The~~2018 for those obligations ~~under the credit facility~~that were ~~secured~~assumed by ~~a $500,000 Canadian dollar guaranteed investment certificate pledged to Royal Bank~~purchasers of Canada, which is classified as "Restricted cash" on the accompanying Condensed Consolidated Balance Sheet at U.S. $381,000, at the September 30, 2016 exchange rate. In April 2017, the revolving demand facility was canceledcertain of Barnwell's oil and ~~the guaranteed investment certificate matured and the funds were reclassified to cash.~~natural gas properties.

8.6. 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							Pension Plan								SERP								Postretirement Medical
	Three months ended June 30,																							Three months ended June 30,
	2017				2016				2017				2016				2017				2016			2018				2017				2018				2017				2018				2017
Service cost	$	34,000			$	65,000			$	(5,000	)		$	19,000			$	—			$	—
Service cost (credit)																								$	54,000			$	34,000			$	10,000			$	(5,000	)		$	—			$	—
Interest cost	78,000				91,000				1,000				24,000				22,000				14,000			88,000				78,000				19,000				1,000				19,000				22,000
Expected return on plan assets	(122,000		)		(139,000		)		—				—				—				—			(147,000		)		(122,000		)		—				—				—				—
Amortization of prior service cost (credit)	2,000				2,000				(2,000		)		(2,000		)		—				—			2,000				2,000				(1,000		)		(2,000		)		—				—
Amortization of net actuarial loss	21,000				38,000				(17,000		)		12,000				47,000				—			25,000				21,000				3,000				(17,000		)		2,000				47,000
Net periodic benefit cost	$	13,000			$	57,000			$	(23,000	)		$	53,000			$	69,000			$	14,000		$	22,000			$	13,000			$	31,000			$	(23,000	)		$	21,000			$	69,000


	Pension Plan								SERP								Postretirement Medical							Pension Plan								SERP								Postretirement Medical
	Nine months ended June 30,																							Nine months ended June 30,
	2017				2016				2017				2016				2017				2016			2018				2017				2018				2017				2018				2017
Service cost	$	178,000			$	195,000			$	26,000			$	51,000			$	—			$	—		$	162,000			$	178,000			$	30,000			$	26,000			$	—			$	—
Interest cost	252,000				273,000				42,000				64,000				66,000				42,000			266,000				252,000				57,000				42,000				57,000				66,000
Expected return on plan assets	(404,000		)		(363,000		)		—				—				—				—			(443,000		)		(404,000		)		—				—				—				—
Amortization of prior service cost (credit)	4,000				4,000				(4,000		)		(4,000		)		—				—			5,000				4,000				(4,000		)		(4,000		)		—				—
Amortization of net actuarial loss	103,000				106,000				—				21,000				141,000				—			74,000				103,000				10,000				—				8,000				141,000
Net periodic benefit cost	$	133,000			$	215,000			$	64,000			$	132,000			$	207,000			$	42,000		$	64,000			$	133,000			$	93,000			$	64,000			$	65,000			$	207,000

Barnwell contributed ~~$350,000~~$200,000 to the Pension Plan during the nine months ended June 30, ~~2017~~2018 and estimates that it will make further contributions of approximately ~~$350,000~~$300,000 during the remainder of fiscal ~~2017. In January 2017, the Postretirement Medical plan commenced payments for retiree medical insurance benefits.~~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 ~~2017~~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.

9.7. INCOME TAXES

The components of ~~earnings (loss)~~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,							Three months ended June 30,								Nine months ended June 30,
	2017				2016				2017				2016			2018				2017				2018				2017
United States	$	(619,000	)		$	2,201,000			$	792,000			$	793,000		$	(12,000	)		$	(619,000	)		$	(2,137,000	)		$	792,000
Canada	(335,000		)		(1,498,000		)		(954,000		)		(3,564,000		)	(525,000		)		(335,000		)		956,000				(954,000		)
	$	(954,000	)		$	703,000			$	(162,000	)		$	(2,771,000	)	$	(537,000	)		$	(954,000	)		$	(1,181,000	)		$	(162,000	)

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


	Three months ended June 30,								Nine months ended June 30,							Three months ended June 30,								Nine months ended June 30,
	2017				2016				2017				2016			2018				2017				2018				2017
Current	$	(392,000	)		$	(159,000	)		$	(740,000	)		$	(527,000	)	$	(60,000	)		$	(392,000	)		$	(889,000	)		$	(740,000	)
Deferred	(50,000		)		87,000				64,000				(2,000		)	(103,000		)		(50,000		)		420,000				64,000
	$	(442,000	)		$	(72,000	)		$	(676,000	)		$	(529,000	)	$	(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~~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. ~~In addition,~~

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 ~~the three and nine months ended June 30, 2017 includes a $369,000 benefit from the lapsing~~refund within one year of the ~~statute~~balance sheet date.

The TCJA restricts the deduction for post-TCJA net operating losses to 80% of ~~limitations on a previously accrued uncertain tax position.~~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 ~~remaining uncertain tax positions~~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 ~~of June 30, 2017.~~a branch in Canada and other minor, inactive Canadian corporate subsidiaries there was no impact from this provision.

~~10.~~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,							Three months ended June 30,								Nine months ended June 30,
	2017				2016				2017				2016			2018				2017				2018				2017
Revenues:
Oil and natural gas	$	940,000			$	768,000			$	3,490,000			$	2,237,000		$	616,000			$	940,000			$	2,428,000			$	3,490,000
Land investment	—				1,775,000				1,678,000				2,255,000			1,310,000				—				1,310,000				1,678,000
Contract drilling	360,000				120,000				3,346,000				1,502,000			1,193,000				360,000				3,051,000				3,346,000
Residential real estate	—				5,700,000				—				5,700,000
Other	19,000				109,000				88,000				198,000			3,000				19,000				73,000				88,000
Total before interest income	1,319,000				8,472,000				8,602,000				11,892,000			3,122,000				1,319,000				6,862,000				8,602,000
Interest income	21,000				17,000				57,000				39,000			46,000				21,000				137,000				57,000
Total revenues	$	1,340,000			$	8,489,000			$	8,659,000			$	11,931,000		$	3,168,000			$	1,340,000			$	6,999,000			$	8,659,000
Depletion, depreciation, and amortization:
Oil and natural gas	$	145,000			$	351,000			$	672,000			$	930,000		$	121,000			$	145,000			$	477,000			$	672,000
Contract drilling	69,000				64,000				205,000				187,000			55,000				69,000				169,000				205,000
Other	20,000				33,000				65,000				84,000			11,000				20,000				48,000				65,000
Total depletion, depreciation, and amortization	$	234,000			$	448,000			$	942,000			$	1,201,000		$	187,000			$	234,000			$	694,000			$	942,000
Impairment:
Oil and natural gas	$	—			$	1,154,000			$	—			$	1,154,000
Operating profit (loss) (before general and administrative expenses):
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	$	175,000			$	(1,494,000	)		$	552,000			$	(2,357,000	)	$	(49,000	)		$	175,000			$	174,000			$	552,000
Land investment	—				1,775,000				1,678,000				2,255,000			1,310,000				—				1,273,000				1,678,000
Contract drilling	(302,000		)		(207,000		)		534,000				(116,000		)	64,000				(302,000		)		104,000				534,000
Residential real estate	—				190,000				—				190,000
Other	(1,000		)		76,000				23,000				114,000			(173,000		)		(1,000		)		(140,000		)		23,000
Gain on sales of assets	527,000				472,000				527,000				472,000			—				527,000				2,250,000				527,000
Total operating profit (loss)	399,000				812,000				3,314,000				558,000
Equity in (loss) income of affiliates:
Total operating profit																1,152,000				399,000				3,661,000				3,314,000
Equity in income (loss) of affiliates:
Land investment	(31,000		)		2,200,000				2,125,000				2,616,000			136,000				(31,000		)		(97,000		)		2,125,000
General and administrative expenses	(1,344,000		)		(1,709,000		)		(5,119,000		)		(5,145,000		)	(1,591,000		)		(1,345,000		)		(4,635,000		)		(5,126,000		)
Interest expense	(1,000		)		(19,000		)		(7,000		)		(85,000		)
Interest income	21,000				17,000				57,000				39,000			46,000				21,000				137,000				57,000
Earnings (loss) before income taxes	$	(956,000	)		$	1,301,000			$	370,000			$	(2,017,000	)
(Loss) earnings before income taxes																$	(257,000	)		$	(956,000	)		$	(934,000	)		$	370,000

~~11.~~9. ACCUMULATED OTHER COMPREHENSIVE ~~INCOME (LOSS)~~LOSS

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


	Three months ended June 30,								Nine months ended June 30,							Three months ended June 30,								Nine months ended June 30,
	2017				2016				2017				2016			2018				2017				2018				2017
Foreign currency translation:
Beginning accumulated foreign currency translation	$	858,000			$	935,000			$	906,000			$	819,000		$	866,000			$	858,000			$	1,053,000			$	906,000
Change in cumulative translation adjustment before reclassifications	81,000				(3,000		)		33,000				113,000			(76,000		)		81,000				(263,000		)		33,000
Income taxes	—				—				—				—			—				—				—				—
Net current period other comprehensive income (loss)	81,000				(3,000		)		33,000				113,000
Net current period other comprehensive (loss) income																(76,000		)		81,000				(263,000		)		33,000
Ending accumulated foreign currency translation	939,000				932,000				939,000				932,000			790,000				939,000				790,000				939,000
Retirement plans:
Beginning accumulated retirement plans benefit cost	(4,633,000		)		(2,864,000		)		(4,826,000		)		(2,941,000		)	(2,048,000		)		(4,633,000		)		(2,111,000		)		(4,826,000		)
Amortization of net actuarial loss and prior service cost	51,000				50,000				244,000				127,000			30,000				51,000				93,000				244,000
Income taxes	—				—				—				—			—				—				—				—
Net current period other comprehensive income	51,000				50,000				244,000				127,000			30,000				51,000				93,000				244,000
Ending accumulated retirement plans benefit cost	(4,582,000		)		(2,814,000		)		(4,582,000		)		(2,814,000		)	(2,018,000		)		(4,582,000		)		(2,018,000		)		(4,582,000		)
Accumulated other comprehensive loss, net of taxes	$	(3,643,000	)		$	(1,882,000	)		$	(3,643,000	)		$	(1,882,000	)	$	(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 86 for additional details).

~~12.~~10. FAIR VALUE MEASUREMENTS

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

~~13.~~ ~~COMMITMENTS AND CONTINGENCIES~~

~~Environmental Matters~~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).

~~In February 2016,~~Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

The estimated fair values of oil and natural gas ~~migration was detected at one of our previously abandoned non-operated wells in Alberta, Canada. Barnwell’s working interest~~properties and the asset retirement obligation incurred in the ~~well is 50%~~drilling of oil and ~~as non-operator we have no control over~~natural gas wells or assumed in the ~~actual cost or timing~~acquisitions of ~~the remediation. In February 2016 we accrued approximately $200,000 for estimated probable environmental remediation costs, which was the balance of the accrual at September 30, 2016. However,~~additional oil and natural gas working interests are based on ~~recent information from~~an estimated discounted cash flow model and market assumptions. The significant Level 3 assumptions used in the ~~operator~~calculation of ~~the well, the cost to remediate will be less than originally~~ estimated ~~and the remaining liability is approximately $2,000 at June 30, 2017, which has not been~~ discounted ~~and was accrued in "Accrued operating and other expenses" on the Condensed Consolidated Balance Sheets.~~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.

~~Because~~Barnwell estimates the fair value of asset retirement obligations based on the ~~inherent uncertainties associated~~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 ~~environmental assessment~~Barnwell’s reserve engineers based on historical information regarding costs incurred to abandon and ~~remediation activities, future expenses to remediate the currently identified site,~~restore similar well sites, information regarding current market conditions and costs, and knowledge of subject well sites ~~identified~~and properties. Asset retirement obligation fair value measurements in the ~~future, if any, could be incurred.~~

~~Guarantee~~

~~See~~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 ~~discussion~~reasonable estimate of ~~Barnwell’s guarantee of the Kukio Resort land development partnership’s performance bonds.~~fair value can be made. Asset retirement obligations are not measured at fair value subsequent to initial recognition.

~~14.~~11. INFORMATION RELATING TO THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS


	Nine months ended June 30,							Nine months ended June 30,
	2017				2016			2018				2017
Supplemental disclosure of cash flow information:
Cash paid during the year for:
Interest	$	6,000			$	82,000		$	3,000			$	6,000
Income taxes refunded, net	$	(137,000	)		$	(377,000	)	$	(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 ~~$199,000~~$152,000 and ~~$89,000~~$199,000 during the nine months ended June 30, ~~2017~~2018 and ~~2016,~~2017, respectively. Additionally, capital expenditure accruals related to oil and natural gas asset retirement obligations decreased ~~$62,000~~$399,000 and ~~increased $123,000~~$62,000 during the nine months ended June 30, ~~2017~~2018 and ~~2016,~~2017, respectively.

~~15.~~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;~~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~~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.~~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. ~~During~~

13. SUBSEQUENT EVENTS

In July 2018, the ~~nine months ended June 30, 2016,~~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 ~~$2,255,000 in~~a percentage of sales ~~payments from KD I and KD II~~payment of $165,000 from the sale of ~~three lots~~a lot within Phase II of Increment ~~I and~~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 ~~one~~the remaining residential lot ~~within~~available for sale in Lot 4A of Increment ~~II.~~I. Financial results from the receipt of this payment will be reflected in Barnwell’s year ending September 30, 2018.

~~16.~~ ~~SUBSEQUENT EVENTS~~

~~There were no material subsequent events that would require recognition or disclosure in the accompanying consolidated financial statements.~~

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, ~~2016.~~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 ~~prices (notwithstanding the recent increases in prices); 2) declines in oil and natural gas~~ production due primarily to ~~both~~ oil and natural gas property ~~sales and~~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, ~~and~~ 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.~~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 ~~significant~~ reinvestments that are necessary to sustain our ~~oil and natural gas~~ 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, ~~from percentage of sales payments,~~ if any, and future cash distributions, if any, from the Kukio Resort ~~land development partnerships,~~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 ~~of its existing liquid assets~~ 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 ~~in the longer term~~ 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,

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, ~~2016.~~2017. There have been no significant changes to these critical accounting policies and estimates during the three and nine months ended June 30, ~~2017.~~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

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 ~~ASU No. 2014-09~~Topic 606 for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. ~~Early adoption is permitted as~~Topic 606 permits two methods of adoption: retrospectively to each prior reporting period presented, or the original effective date, which is annual reporting periods beginning after December 15, 2016 and interim periods within those annual periods. The new standard is to be applied retrospectively and permitsmodified retrospective method with the ~~use of either the retrospective or~~ cumulative effect ~~transition method.~~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 ~~currently evaluating~~well underway in its process to assess the ~~effect that~~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 ~~this update~~Topic 606 will have on the ~~consolidated financial statements.~~

In August 2014, the FASB issued ASU No. 2014-15, “Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern,” which requires an entity to evaluate at each reporting period whether there are conditions or events, in the aggregate, that raise substantial doubt about the entity’s ability to continue as a going concern within one year from the date the financial statements are issued and to provide related footnote disclosures in certain circumstances. The amendment is effective for annual reporting periods ending after December 15, 2016 and interim periods within annual periods beginning after December 15, 2016. Early application is permitted. The adoption of this update is not expected to have a material impact on Barnwell’s 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. ~~This~~Subsequent to the issuance of ASU isNo. 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 ~~requires~~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 March 2016, the FASB issued 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. This ASU is effective for annual reporting periods beginning after December 15, 2016 and interim periods within those annual periods, with early adoption permitted. The adoption of this update is not expected to have a material impact on Barnwell’s consolidated financial statements.

In 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. This ASU is effective for annual periods beginning after December 15, 2016 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 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

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 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. This ASU is effective for annual reporting periods beginning after December 15, 2016 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 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 January 2017, the FASB issued ASU No. 2017-01, "Clarifying the Definition of a Business," which clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. The amendments in ASU No. 2017-01 provide a screen to determine when a set is not a business. The screen requires that when substantially all of the fair value of the gross assets acquired (or disposed of) is concentrated in a single identifiable asset or a group of similar identifiable assets, the set is not a business. This screen reduces the number of transactions that need to be further evaluated. If, however, the screen is not met, then the amendments in this ASU (1) require that to be considered a business, a set must include, at a minimum, an input and a substantive process that together significantly contribute to the ability to create output and (2) remove the evaluation of whether a market participant could replace missing elements. Finally, the amendments in this ASU narrow the definition of the term "output" so that it is consistent with the manner in which outputs are described in Topic 606. This ASU is effective for annual reporting periods beginning after December 15, 2017 and interim periods within those annual periods. Early adoption is permitted for transactions that have not been reported in financial statements that have been issued. Barnwell is currently evaluating the impact of adopting this guidance.

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. ~~Barnwell is currently evaluating the effect that the~~The adoption of this update ~~will~~is not expected to have a material impact on ~~the~~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.

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. Kaupulehu Developments is entitled to receive payments from KD I based on the following percentages of the gross receipts from KD I’s sales: 10% of such aggregate gross proceeds greater than $100,000,000 up to $300,000,000; and 14% of such aggregate gross proceeds in excess of $300,000,000. Increment I is an area zoned for approximately 80 single-family lots, of which 2522 remained to be sold at June 30, ~~2017,~~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 entitled to receive payments from KD II based on a percentage of the gross proceeds from KD II’s sales ranging from 8% to 10% of the price of improved or unimproved lots or 2.60% to 3.25% of the price of units constructed on a lot, to be determined in the future depending upon a number of variables, including whether the lots are sold prior to improvement. Kaupulehu Developments is also entitled to receive up50% of distributions otherwise payable from KD II to ~~$8,000,000 in additional payments~~its members after the members of KD II have received distributions equal to the original basis of capital invested in the ~~project. The managing partner of KD II has represented that KD II’s partners are nearing recovery of the original basis of the capital invested in the~~ project, ~~and once that threshold is reached, Kaupulehu Developments would be entitled to receive 50% of any such post-threshold distributions from KD II~~ up to ~~a maximum~~ $8,000,000,of $8,000,000. The amount and timing of any such receipts by Kaupulehu Developments cannot be determined at this time as distributions by KD II are solely at the discretion of KD II’s managing partner, who holds the controlling interest in KD II, and as future distributions are also dependent upon the future performance of KD II’s operations.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. At June 30, 2017, both of the parcels have been sold~~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~~Land Development Partnerships which is comprised of KD Kukio Resorts, LLLP, KD Maniniowali, LLLP and KD

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.~~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, ~~2017, 25~~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.~~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 ~~owns~~owned one residential parcel in the Kaupulehu area that iswas available for ~~sale.~~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.

~~Changes in Business Environment~~

~~Oil and Natural Gas Segment~~

Our revenues, profitability, and future rate of growth are dependent on oil and natural gas prices. Since late 2014 the industry has experienced significant instability in oil and natural gas prices with the lowest level of prices realized in early 2016. Barnwell realized an average price for oil of $40.86 per barrel

during the nine months ended June 30, 2017, an increase of 31% from $31.14 per barrel realized during the same period in the prior year. The increase in the average price for oil in recent months is primarily a result of agreements made by both OPEC and non-OPEC producers in late 2016, and recently extended to March 2018, to reduce production. Barnwell realized an average price for natural gas of $2.14 per Mcf during the nine months ended June 30, 2017, an increase of 81% from $1.18 per Mcf realized during the same period in the prior year. Natural gas prices were depressed to historic low levels in 2016 as a result of weak growth in demand and a mild winter which led to storage levels exceeding the five-year average. While storage remains high in 2017, it has declined from the record levels of 2016.

Credit and capital markets for oil and natural gas companies have been negatively affected as well, resulting in a decline in sources of financing as compared to previous years. Low prices for oil and natural gas have had a material adverse effect on our financial condition, the carrying value of our oil and natural gas properties, our proved reserves, and our ability to finance operations.

Results of Operations

Summary

Net loss attributable to Barnwell for the three months ended June 30, ~~2017~~2018 totaled ~~$512,000,~~$374,000, a ~~$1,287,000 decrease~~$138,000 increase in operating results from net ~~income~~loss of ~~$775,000~~$512,000 for the three months ended June 30, ~~2016.~~2017. The following factors affected the results of operations for the three months ended June 30, ~~2017~~2018 as compared to the prior year period:

A ~~$1,775,000~~$224,000 decrease 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 $366,000 increase 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 $172,000 decrease 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 $246,000 increase in general and administrative expenses primarily related to fees associated with the increase in land investment segment revenues; and

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 $1,226,000 decrease 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 $378,000 decrease 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 $430,000 decrease 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 $405,000 decrease in land investment segment operating profit, before income taxes and non-controlling interests’ share of such ~~profits, due to decreased percentage of sales receipts~~profits;

A $491,000 decrease in general and administrative expenses primarily as a result of ~~no lot sales by the Kukio Resort land development partnerships~~decreased compensation costs and professional fees;

A $2,250,000 gain recognized in the current ~~quarter;~~

~~A $515,000 increase~~year primarily from the sale of oil properties in ~~oil and natural gas segment operating results, before impairment~~the Red Earth area of ~~assets and income taxes, due primarily~~Alberta, Canada compared to ~~additional royalties assessed~~a $527,000 gain recognized in the prior year period ~~a reduction in the depletion rate in the current year period as a result of sales of oil and natural gas properties and from upward revisions of oil and natural gas reserves~~ due to ~~higher rolling average prices, as well as from equalization credits for previously allocated operating expenses received from non-operated properties~~the sale of the New York office in ~~the current year period;~~

A $95,000 decrease in contract drilling operating results, before income taxes, due primarily to losses on certain water well drilling contracts due to unforeseen difficulties such as geological formation issues and well wall subsidences;

~~A $365,000 decrease in general and administrative expenses;~~

~~A $1,154,000 impairment of oil and natural gas properties recorded in the prior year period;~~

~~A $2,231,000 decrease in equity in income (loss) from affiliates as a result of decreased Kukio Resort land development partnerships’ operating results;~~May 2017; and

A ~~$369,000 income tax benefit recognized in the current quarter from the lapsing of the statute of limitations on a previously accrued uncertain tax position.~~

Barnwell earned net income of $514,000 for the nine months ended June 30, 2017, a $2,756,000 increase in operating results from a net loss of $2,242,000 for the nine months ended June 30, 2016. The following factors affected the results of operations for the nine months ended June 30, 2017 as compared to the prior year period:

A $1,755,000 increase in oil and natural gas segment operating results, before impairment of assets and income taxes, due primarily to increases in prices for all products and to a lesser extent from additional royalties assessed in the prior year period, a reduction in the depletion rate and from equalization credits received in the current year period as noted above;

~~A $650,000 increase in contract drilling operating results, before income taxes, primarily resulting from increased activity on a contract for the plugging and abandonment of two geothermal wells;~~

~~A $577,000 decrease in land investment segment operating profit, before income taxes and non-controlling interests’ share of such profits, due to decreased percentage of sales receipts;~~

~~A $1,154,000 impairment of oil and natural gas properties recorded in the prior year period; and~~

~~A $491,000~~$2,222,000 decrease in equity in income from affiliates as a result of decreased Kukio Resort ~~land development partnerships’~~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 ~~decreased~~increased 4% and 5% in the three and nine months ended June 30, ~~2017~~2018, respectively, as compared to the same ~~period in the prior year and remained substantially the same in the nine months ended June 30, 2017 as compared to the same period~~periods in the prior year. The exchange rate of the Canadian dollar to the U.S. dollar ~~increased 1%~~decreased 5% at June 30, ~~2017~~2018, as compared to September 30, ~~2016.~~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 ~~earnings~~ (loss). earnings. Other comprehensive ~~income~~loss due to foreign currency translation adjustments, net of taxes, for the three months ended June 30, ~~2017~~2018 was ~~$81,000, an $84,000~~$76,000, a $157,000 change from other comprehensive ~~loss~~income due to foreign currency translation adjustments, net of taxes, of ~~$3,000~~$81,000 for the same period in the prior year. Other comprehensive ~~income~~

loss due to foreign currency translation adjustments, net of taxes, for the nine months ended June 30, ~~2017~~2018 was ~~$33,000, an $80,000~~$263,000, a $296,000 change from other comprehensive income due to foreign currency translation adjustments, net of taxes, of ~~$113,000~~$33,000 for the same period in the prior year. There were no taxes on other comprehensive loss or income ~~(loss)~~ due to foreign currency translation adjustments in the three and nine months ended June 30, ~~2017~~2018 and ~~2016~~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														Average Price Per Unit
	Three months ended								Increase						Three months ended								Increase
	June 30,								(Decrease)						June 30,								(Decrease)
	2017				2016				$				%		2018				2017				$				%
Natural Gas (Mcf)*	$	1.84			$	0.85			$	0.99			116	%	$	0.72			$	1.84			$	(1.12	)		(61	%)
Oil (Bbls)**	$	39.05			$	39.81			$	(0.76	)		(2	%)	$	55.20			$	39.05			$	16.15			41	%
Liquids (Bbls)**	$	28.00			$	25.00			$	3.00			12	%	$	44.00			$	28.00			$	16.00			57	%


	Average Price Per Unit														Average Price Per Unit
	Nine months ended								Increase						Nine months ended								Increase
	June 30,								(Decrease)						June 30,								(Decrease)
	2017				2016				$				%		2018				2017				$				%
Natural Gas (Mcf)*	$	2.14			$	1.18			$	0.96			81	%	$	1.24			$	2.14			$	(0.90	)		(42	%)
Oil (Bbls)**	$	40.86			$	31.14			$	9.72			31	%	$	49.74			$	40.86			$	8.88			22	%
Liquids (Bbls)**	$	29.13			$	23.02			$	6.11			27	%	$	42.32			$	29.13			$	13.19			45	%


	Net Production											Net Production
	Three months ended						Increase					Three months ended						Increase
	June 30,						(Decrease)					June 30,						(Decrease)
	2017			2016			Units			%		2018			2017			Units			%
Natural Gas (Mcf)*	90,000			114,000			(24,000	)		(21	%)	67,000			90,000			(23,000	)		(26	%)
Oil (Bbls)**	19,000			21,000			(2,000	)		(10	%)	10,000			19,000			(9,000	)		(47	%)
Liquids (Bbls)**	1,000			1,000			—			—	%	1,000			1,000			—			—	%


	Net Production											Net Production
	Nine months ended						Increase					Nine months ended						Increase
	June 30,						(Decrease)					June 30,						(Decrease)
	2017			2016			Units			%		2018			2017			Units			%
Natural Gas (Mcf)*	293,000			366,000			(73,000	)		(20	%)	220,000			293,000			(73,000	)		(25	%)
Oil (Bbls)**	64,000			60,000			4,000			7	%	41,000			64,000			(23,000	)		(36	%)
Liquids (Bbls)**	3,000			4,000			(1,000	)		(25	%)	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

The oil and natural gas segment generated ~~$175,000~~$49,000 of operating ~~income~~loss before general and administrative expenses in the three months ended June 30, ~~2017~~2018, ~~an increase~~a decrease in operating results of ~~$515,000~~$224,000 as compared to the ~~$340,000~~$175,000 operating ~~loss~~profit before general and administrative expenses ~~and impairment of oil and natural gas properties~~ generated during the same period of the prior year. The oil and natural gas

segment generated ~~$552,000~~$174,000 of operating ~~income~~profit before general and administrative expenses in the nine months ended June 30, ~~2017~~2018, ~~an increase~~a decrease in operating results of ~~$1,755,000~~$378,000 as compared to the ~~$1,203,000~~$552,000 operating ~~loss~~profit before general and administrative expenses ~~and impairment of oil and natural gas properties~~ generated during the same period of the prior year.

Oil and natural gas revenues ~~increased $172,000 (22%~~decreased $324,000 (34%) and $1,062,000 (30%) for the three and nine months ended June 30, ~~2017~~2018, respectively, as compared to the same ~~period~~periods in the prior year, primarily due to ~~approximately $200,000 of additional royalties assessed in the prior year period which~~ decreased ~~net revenues. Oil~~oil and natural gas ~~revenues increased $1,253,000 (56%)~~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, ~~2017~~2018 as compared to the same ~~period~~periods in the prior ~~year primarily due to increases in prices for all products as well as the royalty assessment in the prior year period mentioned above.~~year.

Oil and natural gas operating expenses decreased ~~$137,000 (18%~~$76,000 (12%) and $489,000 (22%) for the three and nine months ended June 30, ~~2017~~2018, respectively, as compared to the same ~~period~~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 ~~in the current year period which decreased operating expenses. Oil~~ and ~~natural gas operating expenses decreased $244,000 (10%) for the nine months ended June 30, 2017 as compared to the same period in the prior year, primarily as a result of~~ 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 ~~period~~quarter and was adjusted down to approximately $23,000 ~~in the current year period~~ based on ~~recent~~updated information from the ~~operator, as well as due to the equalization credit received in the current year period mentioned above.~~operator.

Sale of interest in leasehold land

Kaupulehu Developments is entitled to receive a percentage of ~~the gross receipts~~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;~~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.~~Land Development Partnerships.

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


	Three months ended June 30,								Nine months ended June 30,							Three months ended June 30,								Nine months ended June 30,
	2017				2016				2017				2016			2018				2017				2018				2017
Sale of interest in leasehold land:
Revenues - sale of interest in leasehold land	$	—			$	1,775,000			$	1,678,000			$	2,255,000		$	1,310,000			$	—			$	1,310,000			$	1,678,000
Fees - included in general and administrative expenses	—				(273,000		)		(260,000		)		(340,000		)	(175,000		)		—				(175,000		)		(260,000		)
Proceeds from the sale of interest in leasehold land, net of fees paid	$	—			$	1,502,000			$	1,418,000			$	1,915,000		$	1,135,000			$	—			$	1,135,000			$	1,418,000

The Kukio Resort ~~land development partnerships~~Land Development Partnerships had noone lot ~~sales~~sale during the three and nine months ended June 30, ~~2017.~~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. During the three months ended June 30, 2016, KD I sold one single-family lot within Phase II of Increment I and KD II sold the first of two large ocean front lots within Increment II for $20,000,000 and Kaupulehu Developments received a percentage of sales payment in the amount of $1,600,000 from KD II representing 8% of the gross sales price of the parcel and during the nine months ended June 30, 2016, KD I sold a total of three single-family lots in Phase II of Increment I and KD II sold a total of one large ocean front lot within Increment II.

As of June 30, ~~2017, 25~~2018, 22 single-family lots of the 80 lots developed within Increment I remained to be sold. ~~Two ocean front parcels approximately two to three acres in size were developed within Increment II by KD II, both of which have been sold, and the~~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 ~~$240,000 (200%~~$481,000 (81%) ~~and $330,000 (125%), respectively,~~ for the three months ended June 30, ~~2017,~~2018, as compared to the same period in the prior year. The contract drilling segment generated a ~~$302,000~~$64,000 operating ~~loss~~profit before general and administrative expenses in the three months ended June 30, ~~2017, a decrease~~2018, an increase in operating results of ~~$95,000~~$366,000 as compared to the ~~$207,000~~$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 ~~period~~ 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.

~~Contract drilling revenues and contract drilling costs increased $1,844,000 (123%) and $1,176,000 (82%), respectively,~~ The decrease in operating results for the nine months ended June 30, 2017, as compared to the same period in the prior year. The contract drilling segment generated a $534,000 operating profit before general and administrative expenses in the nine months ended June 30, 2017, an increase in operating results of ~~$650,000~~ ~~as compared to the $116,000 operating~~ ~~loss~~ ~~generated during the same period of the prior year. The increase in operating results~~2018 as compared to the prior year period was primarily due to ~~increased activity~~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 ~~March 31, 2017,~~June 30, 2017. The operating profit

in the prior year period from this higher value contract was partially offset by ~~the current year period~~ losses on certain water well drilling contracts due to unforeseen difficulties ~~such~~ as ~~geological formation issues and well wall subsidences.~~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.

~~Residential real estate revenues and expenses~~

In April 2016, the residence that was available for sale in Lot 4A Increment I was sold for $5,700,000 in gross proceeds, before commission and other closing costs, and as a result of the sale operating profit before general and administrative expenses in the amount of $190,000 was recognized during the three and nine months ended June 30, 2016.

~~Gas processing and other~~

~~Gas processing and other revenues~~ ~~decreased$86,000~~ (~~68%) and~~ ~~$92,000~~ (~~39%~~) for the three and nine months ended June 30, 2017, respectively, as compared to the same periods in the prior year primarily due to adjustments of previously allocated gas processing facility revenues of approximately $71,000 received in the prior year quarter.

General and administrative expenses

General and administrative expenses ~~decreased $365,000 (21%~~increased $246,000 (18%) for the three months ended June 30, ~~2017,~~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 ~~$152,000~~$379,000 decrease in compensation costs ~~and~~resulting from a ~~$217,000~~ decrease in ~~professional fees, primarily fees related to percentage~~retirement plan expenses, executive bonuses, and stock appreciation rights, a decrease of ~~sales payments.~~

General and administrative expenses decreased $26,000 (1%) for the nine months ended June 30, 2017, as compared to the same period in the prior year. A $179,000 increase in director's fees was more than offset by an $80,000 decrease$85,000 in professional fees related to ~~percentage of sales payments,~~lower land investment segment proceeds received in the current year period, and a ~~$65,000~~ decrease in ~~holding~~ costs ~~related to the home that~~associated with Barnwell's New York office, which was sold in April 2016, a $34,000 decrease in compensation costs, as well as other miscellaneous decreases. The Chairman of the Board resigned as Chief Executive Officer effective December 31, 2016 and as such began collecting a director's fee on January 1,May 2017.

Depletion, depreciation, and amortization

Depletion, depreciation, and amortization decreased ~~$214,000 (48%~~$47,000 (20%) and ~~$259,000 (22%~~$248,000 (26%) for the three and nine months ended June 30, ~~2017,~~2018, respectively, as compared to the same periods in the prior year, ~~primarily~~ due to ~~a reduction~~decreases in production and the impact of oil and natural gas property sales on the depletion rate in the current year ~~period as a result of sales of oil and natural gas properties and from upward revisions of oil and natural gas reserves due to higher rolling average prices, as well as from decreases~~periods. This decrease was partially offset by an increase in ~~production.~~

~~Impairment of oil and natural gas assets~~

~~Under~~ the full cost method of accounting, the Company performs quarterly oil and natural gas ceiling test calculations. Barnwell’s net capitalized costs exceeded the ceiling limitations at June 30, 2016. As such, Barnwell reduced the carrying value of its oil and natural gas properties by $1,154,000depletion rate for the three and nine months ended June 30, ~~2016. No such reduction~~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 ~~necessary~~$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 ~~current year period.~~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.

Gain on sales of assets

~~On May 2,~~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.

In September 2015, Barnwell sold its interests in its principal oil and natural gas properties located in the Dunvegan and Belloy areas of Alberta, Canada. The disposition was recorded in the fourth quarter of fiscal 2015 using preliminary purchase price adjustments. The purchase price was subject to final adjustments in accordance with the terms of the purchase and sale agreement. Barnwell and the purchaser updated the estimated purchase price adjustments during the quarter ended June 30, 2016, which resulted in the recognition of an additional gain in the amount of $472,000 during the three and nine months ended June 30, 2016.

Equity in income (loss) of affiliates

Barnwell’s investment in the Kukio Resort ~~land development partnerships~~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 as compared to~~2017. The allocated income ~~of $2,200,000~~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, ~~2016.~~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 ~~in the current year period~~ is ~~primarily~~ due to ~~no lots being sold by~~ the investee ~~partnerships in~~partnerships' sale of the ~~current year period, as compared to two lots sold in the prior year period, including the first~~second of two large ocean front parcels in Kaupulehu Increment II for ~~$20,000,000~~$20,975,000 in ~~April~~December 2016.

Barnwell was allocated partnership income of $2,125,000 during the nine months ended June 30, 2017, as compared to allocated income of $2,616,000 during the nine months ended June 30, 2016. The decrease in the allocated partnership income in the current year period is primarily due to decreased lot sales.

Income taxes

Barnwell’s effective consolidated income tax rate for the three and nine months ended June 30, ~~2017~~,2018, after adjusting (loss) earnings ~~(loss)~~ before income taxes for non-controlling interests, was ~~46%~~30% and ~~417%~~40%, respectively, as compared to ~~(10)%~~46% and ~~19%~~417% for the three and nine months ended June 30, ~~2016~~,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~~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. ~~In addition,~~

The Tax Cuts and Jobs Act ("TCJA") was enacted on December 22, 2017. The TCJA includes various changes to the ~~current~~tax law, including a permanent reduction in the U.S. corporate income tax ~~benefit~~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 ~~three~~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 nine months ended June 30, ~~2017 includes~~2018 as the Company has a ~~$369,000 benefit from the lapsing~~full valuation allowance on its net deferred tax assets under U.S. federal tax law. The repeal of the ~~statute~~corporate AMT provides a mechanism for the refund over time of ~~limitations~~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 ~~a previously accrued uncertain~~information available to date. However, the TCJA makes broad and complex changes to the U.S. tax ~~position.~~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 ~~(loss)~~ attributable to non-controlling interests ~~decreased $600,000 (100%) and $222,000 (29%)~~ for the three ~~and nine~~ months ended June 30, ~~2017, respectively,~~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 ~~due~~ to ~~less percentage of sales~~an increase in land investment segment proceeds received and ~~a decrease in the amount of~~ Kukio ~~land development partnership~~Land Development Partnership income allocated to non-controlling interests in the current year ~~periods~~period as compared to the same ~~periods~~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, ~~2017,~~2018, Barnwell had ~~$19,043,000~~$19,639,000 in working capital.

Cash Flows

Cash flows used in operations totaled ~~$1,830,000~~$4,321,000 for the nine months ended June 30, ~~2017,~~2018, as compared to cash flows ~~provided by~~used in operations of ~~$3,044,000~~$1,830,000 for the same period in the prior year. ~~This $4,874,000~~The following factors affected the $2,491,000 decrease in operating cash flows ~~was primarily due~~for the nine months ended June 30, 2018, as compared to ~~net proceeds of $5,132,000 received from~~ the ~~sale of the real estate held for sale in April 2016, whereas there were no such item in the current year period, and a $1,550,000 decrease in the amount of~~prior year:

A $2,164,000 distribution of income received from the Kukio Resort ~~land development partnerships~~Land Development Partnerships in the prior year period whereas there was no such distribution in the current year ~~period, which were partially offset by increases~~period;

Decreases in ~~both~~ oil and natural gas and contract drilling ~~operating results.~~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 ~~$2,570,000~~$2,482,000 during the nine months ended June 30, ~~2017,~~2018, as compared to ~~$9,932,000~~cash flows provided by investing activities of $2,570,000 during the same period of the prior year. The ~~$7,362,000~~$88,000 decrease in investing cash flows was primarily due to a ~~$7,089,000 release~~$235,000 decrease in the distribution of ~~restricted cash~~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, ~~$2,480,000~~and a $468,000 decrease in ~~purchases~~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 ~~and a $994,000 decrease in~~compared to the amount of distribution of capital received from the Kukio Resort land development partnerships in the current year period. These items were partially offset by $3,598,000 of proceeds from the sale of the New York office and certain oil and natural gas properties in the currentprior year period.

Net cash used in financing activities totaled ~~$239,000~~$594,000 for the nine months ended June 30, ~~2017,~~2018, as compared to ~~$4,252,000~~$239,000 during the same period of the prior year. The ~~$4,013,000~~$355,000 change in financing cash flows was ~~primarily~~ due to ~~$3,440,000~~a $23,000 decrease in ~~debt repayments~~distributions to non-controlling interests in the current year period as compared to the prior year period, ~~as a result of the sale of the real estate held for sale in April 2016~~ and a ~~$318,000 increase in the~~$372,000 release of restricted cash induring the ~~current~~prior year period.

~~Credit Arrangements~~

In June 2016, Barnwell entered into an agreement with Royal Bank of Canada for a revolving demand facility in the amount of $500,000 Canadian dollars. Borrowings under this facility were $0 at September 30, 2016. The obligations under the credit facility were secured by a $500,000 Canadian dollar guaranteed investment certificate pledged to Royal Bank of Canada, which is classified as "Restricted cash" on the accompanying Condensed Consolidated Balance Sheet at U.S. $381,000, at the September 30, 2016 exchange rate. In April 2017, the revolving demand facility was canceled and the guaranteed investment certificate matured and the funds were reclassified to cash.

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 ~~$35,000~~$121,000 and ~~$299,000~~$321,000 for the three and nine months ended June 30, ~~2017,~~2018, respectively, as compared to ~~$56,000~~$35,000 and ~~$586,000~~$299,000 for the same periods in the prior year. Barnwell ~~estimates that there will be nominal additional investment~~expects to make approximately $10,500,000 in investments in oil and natural gas properties infor the ~~fourth quarter~~remainder of fiscal ~~2017.~~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 ~~June~~October 2017, Barnwell entered into a Purchase and Sale Agreement with an independent third party and sold ~~a portion of~~ its oil and natural gas ~~property~~properties located in the ~~Progress and Valhalla areas~~Pouce Coupe area of Alberta, Canada. The sales price per the agreement was adjusted to $79,000 for customary purchase price adjustments to ~~$1,076,000 in order to, among other things,~~ reflect anthe economic activity from the effective date of ~~April~~May 1, ~~2017.~~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.

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, ~~$552,000~~$752,000 was withheld and remitted by the buyer to the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income ~~taxes related to the sale.~~taxes. Net oil ~~and natural gas~~ production from ~~this property~~these properties was approximately ~~11,000 Boe,~~23,000 Bbls, or approximately 7%16% of total net ~~oil and natural gas~~ production, for the year ended September 30, ~~2016.~~2017. As of September 30, ~~2016,~~2017, estimated net proved oil ~~and natural gas~~ reserve volumes associated with these properties was ~~95,000 Boe,~~104,000 Bbls, or approximately ~~14%~~11% of the total reserve volumes at that date.

In July 2018, the ~~nine months ended June 30, 2017, Barnwell also sold miscellaneous~~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 ~~proceeds~~Barnwell's interests is approximately $10,500,000 and is subject to customary adjustment to the purchase price at closing. Certain of ~~$162,000,~~the assets which would be conveyed to the Company pursuant to the Purchase and Sales Agreement are subject to third parties' rights of ~~which $66,000 was withheld and remitted~~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 ~~buyer to the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes related to the sales.~~

In accordance with full cost method rules, property sales are credited to the full cost pool, with no gain or loss recognized, unless such a sale would significantly alter the relationship between capitalized costs and the proved reserves attributable to these costs. No gain or loss was recognized in fiscal 2017 as these sales to multiple counterparties in unrelated transactions did not individually, or in aggregate, result in a significant alterationCompany (see Note 13 of the ~~relationship between capitalized costs and proved reserves.~~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 ~~noncompliant~~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, ~~2017,~~2018, the current portion of the asset retirement obligation was ~~$1,040,000.~~$410,000.

~~Contingencies~~

~~Environmental Matters~~

In February 2016, a gas migration was detected at one of our previously abandoned non-operated wells in Alberta, Canada. Barnwell’s working interest in the well is 50% and as non-operator we have no control over the actual cost or timing of the remediation. In February 2016 we accrued approximately $200,000 for estimated probable environmental remediation costs, which was the balance of the accrual at September 30, 2016. However, based on recent information from the operator of the well, the cost to remediate will be less than originally estimated and the remaining liability is approximately $2,000 at June 30, 2017.

Because of the inherent uncertainties associated with environmental assessment and remediation activities, future expenses to remediate the currently identified site, and sites identified in the future, if any, could be incurred.

~~Guarantee~~

~~See Note 5 for a discussion of Barnwell’s guarantee of the Kukio Resort land development partnership’s performance bonds.~~

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, ~~2017,~~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, ~~2017~~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.

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, ~~2017~~2018 that materially affected, or is reasonably likely to materially affect, Barnwell’s internal control over financial reporting.

PART II - OTHER INFORMATION

ITEM 6. EXHIBITS



Exhibit Number		Description

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

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

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

101.INS		XBRL Instance Document

101.SCH		XBRL Taxonomy Extension Schema Document

101.CAL		XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF		XBRL Taxonomy Extension Definition Linkbase Document

101.LAB		XBRL Taxonomy Extension Label Linkbase Document

101.PRE		XBRL Taxonomy Extension Presentation Linkbase Document

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



		BARNWELL INDUSTRIES, INC.
		(Registrant)


Date:	August ~~9, 2017~~13, 2018	/s/ Russell M. Gifford
		Russell M. Gifford
		Chief Financial Officer,
		Executive Vice President,
		Treasurer and Secretary

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

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