Barnwell Industries (BRN) 10-K 20 Dec 16 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Dec. 01, 2016	Mar. 31, 2016
Document and Entity Information
Entity Registrant Name	BARNWELL INDUSTRIES INC
Entity Central Index Key	10,048
Document Type	10-K
Document Period End Date	Sep. 30, 2016
Amendment Flag	false
Current Fiscal Year End Date	--09-30
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Smaller Reporting Company
Entity Public Float			$ 7,026
Entity Common Stock, Shares Outstanding		8,277,160
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS CAD in Thousands, $ in Thousands	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)
Current assets:
Cash and cash equivalents	$ 15,550	$ 8,471
Restricted cash	381	7,458
Accounts and other receivables, net of allowance for doubtful accounts	1,228	2,300
Asset held for sale	1,829	0
Investment held for sale	1,192	1,192
Real estate held for sale	0	5,132
Other current assets	934	1,125
Total current assets	21,114	25,678
Restricted cash, net of current portion	0	119
Investments	3,552	6,288
Property and equipment, net	6,902	9,468
Total assets	31,568	41,553
Current liabilities:
Accounts payable	1,423	2,653
Accrued capital expenditures	439	363
Accrued compensation	449	560
Accrued operating and other expenses	1,031	1,343
Current portion of long-term debt	0	3,440
Current portion of asset retirement obligation	1,017	506
Other current liabilities	377	1,138
Total current liabilities	4,736	10,003
Liability for retirement benefits	6,707	5,409
Asset retirement obligation	6,177	6,430
Deferred income taxes	204	449
Total liabilities	17,824	22,291
Commitments and contingencies (Note 18)
Equity:
Common stock, par value $0.50 per share; authorized, 20,000,000 shares: 8,445,060 issued at September 30, 2016 and 2015	4,223	4,223
Additional paid-in capital	1,345	1,335
Retained earnings	13,852	17,467
Accumulated other comprehensive loss, net	(3,920)	(2,122)
Treasury stock, at cost: 167,900 shares at September 30, 2016 and 2015	(2,286)	(2,286)
Total stockholders’ equity	13,214	18,617
Non-controlling interests	530	645
Total equity	13,744	19,262
Total liabilities and equity	$ 31,568	$ 41,553

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Sep. 30, 2016	Sep. 30, 2015
Statement of Financial Position [Abstract]
Common stock, par value (in dollars per share)	$ 0.50	$ 0.50
Common stock, authorized shares	20,000,000	20,000,000
Common stock, issued shares	8,445,060	8,445,060
Treasury stock, shares	167,900	167,900

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Revenues:
Oil and natural gas	$ 3,177	$ 9,008
Contract drilling	2,233	4,886
Sale of interest in leasehold land, net	1,915	3,244
Residential real estate	5,700	0
Gas processing and other	262	395
Total revenues	13,287	17,533
Costs and expenses:
Oil and natural gas operating	3,142	6,387
Contract drilling operating	2,098	3,692
Residential real estate	5,510	0
General and administrative	6,361	8,551
Depletion, depreciation, and amortization	1,607	3,364
Impairment of assets	1,154	316
Interest expense	97	315
Gain on sales of assets	(472)	(6,489)
Total costs and expenses	19,497	16,136
(Loss) earnings before equity in income of affiliates and income taxes	(6,210)	1,397
Equity in income of affiliates	2,624	1,580
(Loss) earnings before income taxes	(3,586)	2,977
Income tax (benefit) provision	(722)	1,208
Net (loss) earnings	(2,864)	1,769
Less: Net earnings attributable to non-controlling interests	751	506
Net (loss) earnings attributable to Barnwell Industries, Inc. stockholders	$ (3,615)	$ 1,263
Basic net earnings (loss) per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share)	$ (0.44)	$ 0.15
Diluted net earnings (loss) per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share)	$ (0.44)	$ 0.15
Weighted-average number of common shares outstanding:
Basic (in shares)	8,277,160	8,277,160
Diluted (in shares)	8,277,160	8,277,160

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Statement of Comprehensive Income [Abstract]
Net (loss) earnings	$ (2,864)	$ 1,769
Other comprehensive income (loss):
Foreign currency translation adjustments, net of taxes of $0	87	(873)
Retirement plans:
Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	168	105
Net actuarial losses arising during the period, net of taxes of $0	(2,053)	(1,096)
Total other comprehensive loss	(1,798)	(1,864)
Total comprehensive loss	(4,662)	(95)
Less: Comprehensive income attributable to non-controlling interests	751	506
Comprehensive loss attributable to Barnwell Industries, Inc.	$ (5,413)	$ (601)

CONSOLIDATED STATEMENTS OF COM6

CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Statement of Comprehensive Income [Abstract]
Foreign currency translation adjustments, taxes	$ 0	$ 0
Amortization of accumulated other comprehensive loss into net periodic benefit cost, taxes	0	0
Net actuarial losses arising during the period, taxes	$ 0	$ 0

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Cash flows from operating activities:
Net (loss) earnings	$ (2,864)	$ 1,769
Adjustments to reconcile net (loss) earnings to net cash provided by (used in) operating activities:
Equity in income of affiliates	(2,624)	(1,580)
Depletion, depreciation, and amortization	1,607	3,364
Impairment of assets	1,154	316
Gain on sale of oil and natural gas properties	(472)	(6,217)
Gain on sale of contract drilling assets	0	(272)
Foreign exchange loss	0	752
Distribution of income from equity investees	3,714	0
Imputed interest income on note receivable	0	(22)
Retirement benefits expense	519	408
Accretion of asset retirement obligation	464	632
Deferred income tax benefit	(71)	(415)
Asset retirement obligation payments	(459)	(655)
Share-based compensation benefit	(22)	(140)
Retirement plan contributions	(1,106)	(256)
Real estate held for sale	5,132	0
Sale of interest in leasehold land, net	(1,915)	(3,244)
Decrease from changes in current assets and liabilities	(1,287)	(1,572)
Net cash provided by (used in) operating activities	1,770	(7,132)
Cash flows from investing activities:
Decrease (increase) in restricted cash	7,089	(7,300)
Distribution from equity investees in excess of earnings	1,646	0
Proceeds from sale of interest in leasehold land, net of fees paid	1,915	3,244
Proceeds from sale of oil and natural gas assets	493	14,162
Proceeds from sale of contract drilling assets	0	368
Proceeds from sale of investments	0	1,145
Payment to acquire oil and natural gas properties	(769)	(832)
Capital expenditures	(996)	(1,710)
Net cash provided by investing activities	9,378	9,077
Cash flows from financing activities:
Repayments of long-term debt	(3,440)	(7,659)
Decrease (increase) in restricted cash	54	(442)
Contributions from non-controlling interests	0	120
Distributions to non-controlling interests	(866)	(728)
Net cash used in financing activities	(4,252)	(8,709)
Effect of exchange rate changes on cash and cash equivalents	183	(869)
Net increase (decrease) in cash and cash equivalents	7,079	(7,633)
Cash and cash equivalents at beginning of year	8,471	16,104
Cash and cash equivalents at end of year	$ 15,550	$ 8,471

CONSOLIDATED STATEMENTS OF EQUI

CONSOLIDATED STATEMENTS OF EQUITY - USD ($) $ in Thousands	Total	Common Stock	Additional Paid-In Capital	Retained Earnings	Accumulated Other Comprehensive Income (Loss)	Treasury Stock	Non-controlling Interests
Balance at Sep. 30, 2014	$ 19,945	$ 4,223	$ 1,315	$ 16,204	$ (258)	$ (2,286)	$ 747
Balance (in shares) at Sep. 30, 2014		8,277,160
Increase (Decrease) in Stockholders' Equity
Contributions from non-controlling interests	120						120
Distributions to non-controlling interests	(728)						(728)
Net (loss) earnings	1,769			1,263			506
Share-based compensation	20		20
Foreign currency translation adjustments, net of taxes of $0	(873)				(873)
Retirement plans:
Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	105				105
Net actuarial losses arising during the period, net of taxes of $0	(1,096)				(1,096)
Balance at Sep. 30, 2015	19,262	$ 4,223	1,335	17,467	(2,122)	(2,286)	645
Balance (in shares) at Sep. 30, 2015		8,277,160
Increase (Decrease) in Stockholders' Equity
Distributions to non-controlling interests	(866)						(866)
Net (loss) earnings	(2,864)			(3,615)			751
Share-based compensation	10		10
Foreign currency translation adjustments, net of taxes of $0	87				87
Retirement plans:
Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	168				168
Net actuarial losses arising during the period, net of taxes of $0	(2,053)				(2,053)
Balance at Sep. 30, 2016	$ 13,744	$ 4,223	$ 1,345	$ 13,852	$ (3,920)	$ (2,286)	$ 530
Balance (in shares) at Sep. 30, 2016		8,277,160

CONSOLIDATED STATEMENTS OF EQU9

CONSOLIDATED STATEMENTS OF EQUITY (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Statement of Stockholders' Equity [Abstract]
Foreign currency translation adjustments, taxes	$ 0	$ 0
Amortization of accumulated other comprehensive loss into net periodic benefit cost, taxes	0	0
Net actuarial losses arising during the period, taxes	$ 0	$ 0

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Sep. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Description of Business Barnwell is engaged in the following lines of business: 1) acquiring, developing, producing and selling oil and natural gas in Canada, 2) investing in land interests in Hawaii, 3) drilling wells and installing and repairing water pumping systems in Hawaii, and 4) developing homes for sale in Hawaii. Principles of Consolidation The 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 80% -owned joint ventures (Kaupulehu 2007, LLLP and Kaupulehu Investors, LLC). 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 VIEs in which the Company is not deemed to be the primary beneficiary are accounted for by the equity method. Use of Estimates in the Preparation of Financial Statements The preparation of the financial statements in conformity with U.S. GAAP requires management of Barnwell to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Actual results could differ significantly from those estimates. Significant assumptions are required in the valuation of deferred tax assets, asset retirement obligations, share-based payment arrangements, obligations for retirement plans, contract drilling estimated costs to complete, proved oil and natural gas reserves, and the carrying value of other assets, and such assumptions may impact the amount at which such items are recorded. Cash and Cash Equivalents Cash and cash equivalents include cash on hand, demand deposits and short-term investments with original maturities of three months or less. Restricted Cash Restricted cash at September 30, 2016 consists of a $500,000 Canadian dollar, or U.S. $381,000 at the September 30, 2016 exchange rate, guaranteed investment certificate pledged to the Royal Bank of Canada as required by our revolving demand facility. Restricted cash in the prior year consisted of a portion of the proceeds from the sale of Dunvegan held in an escrow account for the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes as well as deposits in an interest reserve account and a cost reserve account for our real estate loan. These amounts were released from restriction in fiscal 2016. Concentration of Credit Risk We maintain bank account balances with high quality financial institutions which often exceed insured limits. We have not experienced any losses with these accounts and believe that we are not exposed to any significant credit risk on cash. Accounts and Other Receivables Accounts receivable are recorded at the invoiced amount and do not bear interest. The allowance for doubtful accounts is Barnwell’s best estimate of the amount of probable credit losses in Barnwell’s existing accounts receivable and is based on historical write-off experience and the application of the specific identification method. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote. Barnwell does not have any off-balance sheet credit exposure related to its customers. Asset and Investment Held for Sale Asset and investment held for sale are reported at the lower of the asset carrying value or fair value less costs to sell. The recorded balances are evaluated for impairment whenever events or changes in circumstances indicate that the balance may not be fully recoverable. This evaluation requires management to make assumptions and apply considerable judgments to, among others, estimates of the timing and amount of future cash flows, uncertainty about future events, including changes in economic conditions, changes in operating performance, and ongoing cost of maintenance and improvements of the assets. Changes in these and other assumptions may require impairment charges that may materially impact the Company’s future operating results. Assets are classified as held for sale if management commits to a plan to sell the property, the Company actively markets the property in its current condition for a price that is reasonable in comparison to its fair value and management considers the sale of such property within one year of the balance sheet date to be probable. Investments in Real Estate Barnwell accounts for sales of Increment I and Increment II leasehold land interests under the full accrual method. Gains from such sales were recognized when the buyer’s investments were adequate to demonstrate a commitment to pay for the property, risks and rewards of ownership transferred to the buyer, and Barnwell did not have a substantial continuing involvement with the property sold. With regard to the sales of Increment I and Increment II leasehold land interests, the percentage of sales payments are contingent future profits which will be recognized when they are realized. All costs of the sales of Increment I and Increment II leasehold land interests were recognized at the time of sale and were not deferred to future periods when any contingent profits will be recognized. Equity Method Investments Affiliated companies, which are limited partnerships or similar entities, in which Barnwell holds more than a 3% to 5% ownership interest, are accounted for as equity method investments. Equity method investment adjustments include Barnwell’s proportionate share of investee income or loss, adjustments to recognize certain differences between Barnwell’s carrying value and Barnwell’s equity in net assets of the investee at the date of investment, impairments and other adjustments required by the equity method. Gains or losses are realized when such investments are sold. Investments in equity method investees are evaluated for impairment as events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. If the carrying amounts of the assets exceed their respective fair values, additional impairment tests are performed to measure the amounts of the impairment losses, if any. When an impairment test demonstrates that the fair value of an investment is less than its carrying value, management will determine whether the impairment is either temporary or other-than-temporary. Examples of factors which may be indicative of an other-than-temporary impairment include (a) the length of time and extent to which fair value has been less than carrying value, (b) the financial condition and near-term prospects of the investee, and (c) the intent and ability to retain the investment in the investee for a period of time sufficient to allow for any anticipated recovery in fair value. If the decline in fair value is determined by management to be other-than-temporary, the carrying value of the investment is written down to its estimated fair value as of the balance sheet date of the reporting period in which the assessment is made. Variable Interest Entities The consolidation of VIEs is required when an enterprise has a controlling financial interest and is therefore the VIE’s primary beneficiary. A controlling financial interest will have both of the following characteristics: (a) the power to direct the activities of a VIE that most significantly impact the VIE’s economic performance and (b) the obligation to absorb losses of the VIE that could potentially be significant to the VIE or the right to receive benefits from the VIE that could potentially be significant to the VIE. The determination of whether an entity is a VIE and, if so, whether the Company is primary beneficiary, may require significant judgment. Barnwell analyzes its unconsolidated affiliates in which it has an investment to determine whether the unconsolidated entities are VIEs and, if so, whether the Company is the primary beneficiary. This analysis includes a qualitative review based on an evaluation of the design of the entity, its organizational structure, including decision making ability and financial agreements, as well as a quantitative review. Our unconsolidated affiliates that have been determined to be VIEs are accounted under the equity method because we do not have a controlling financial interest and are therefore not the VIE’s primary beneficiary (see Note 9). Oil and Natural Gas Properties Barnwell uses the full cost method of accounting under which all costs incurred in the acquisition, exploration and development of oil and natural gas reserves, including costs related to unsuccessful wells and estimated future site restoration and abandonment, are capitalized. We capitalize internal costs that can be directly identified with our acquisition, exploration and development activities and do not include any costs related to production, general corporate overhead or similar activities. Under the full cost method of accounting, we review the carrying value of our oil and natural gas properties, on a country-by-country basis, each quarter in what is commonly referred to as the ceiling test. Under the ceiling test, capitalized costs, net of accumulated depletion and oil and natural gas related deferred income taxes, may not exceed an amount equal to the sum of 1) the discounted present value (at 10% ), using average first-day-of-the-month prices during the 12-month period ending as of the balance sheet date held constant over the life of the reserves, of Barnwell’s estimated future net cash flows from estimated production of proved oil and natural gas reserves as determined by independent petroleum reserve engineers, less estimated future expenditures to be incurred in developing and producing the proved reserves but excluding future cash outflows associated with settling asset retirement obligations; plus 2) the cost of major development projects and unproven properties not subject to depletion, if any; plus 3) the lower of cost or estimated fair value of unproven properties included in costs subject to depletion; less 4) related income tax effects. If net capitalized costs exceed this limit, the excess is expensed. Depletion is computed using the units-of-production method whereby capitalized costs, net of estimated salvage values, plus estimated future costs to develop proved reserves and satisfy asset retirement obligations, are amortized over the total estimated proved reserves on a country-by-country basis. Investments in major development projects are not depleted until either proved reserves are associated with the projects or impairment has been determined. Proceeds from the disposition of oil and natural gas properties 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 in a particular country. Revenues associated with the sale of oil, natural gas and natural gas liquids are recognized in the Consolidated Statements of Operations when the oil, natural gas and natural gas liquids are delivered and title has passed to the customer. Barnwell’s sales reflect its working interest share after royalties. Barnwell’s production is generally delivered and sold at the plant gate. Barnwell does not have transportation volume commitments with pipelines and does not have natural gas imbalances related to natural gas balancing arrangements with its partners. Acquisitions Acquisitions of businesses are accounted for using the acquisition method of accounting. Purchase prices are allocated to acquired assets and assumed liabilities based on their estimated fair value at the time of the acquisition. A business combination may result in the recognition of a gain or goodwill based on the fair value of the assets acquired and liabilities assumed at the acquisition date as compared to the fair value of consideration transferred. Long-lived Assets Long-lived assets to be held and used, other than oil and natural gas properties, are evaluated for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be fully recoverable. Recoverability is measured by comparing the carrying amount of the asset to the future net cash flows expected to result from use of the asset (undiscounted and without interest charges). If it is determined that the asset may not be recoverable, impairment loss is measured as the amount by which the carrying amount of the asset exceeds the fair value of the asset. Long-lived assets to be disposed of are reported at the lower of the asset carrying value or fair value, less cost to sell. Water well drilling rigs, office and other property and equipment are depreciated using the straight-line method based on estimated useful lives. Share-based Compensation Share-based compensation cost is measured at fair value. Barnwell utilizes a closed-form valuation model to determine the fair value of each option award. Expected volatilities are based on the historical volatility of Barnwell’s stock over a period consistent with that of the expected terms of the options. The expected terms of the options represent expectations of future employee exercise and are estimated based on factors such as vesting periods, contractual expiration dates, historical trends in Barnwell’s stock price, and historical exercise behavior. The risk-free rates for periods within the contractual life of the options are based on the yields of U.S. Treasury instruments with terms comparable to the estimated option terms. Expected dividends are based on current and historical dividend payments. Retirement Plans Barnwell accounts for its defined benefit pension plan, Supplemental Employee Retirement Plan, and postretirement medical insurance benefits plan by recognizing the over-funded or under-funded status as an asset or liability in its Consolidated Balance Sheets and recognizes changes in that funded status in the year in which the changes occur through comprehensive income. See further discussion at Note 13. The estimation of Barnwell’s retirement plan obligations, costs and liabilities requires management to estimate the amount and timing of cash outflows for projected future payments and cash inflows for maturities and expected returns on plan assets. These assumptions may have an effect on the amount and timing of future contributions. At the end of each year, Barnwell determines the discount rate to be used to calculate the present value of plan liabilities and the net periodic benefit cost. The discount rate is an estimate of the current interest rate at which the retirement plan liabilities could be effectively settled at the end of the year. In estimating this rate, Barnwell references the Citigroup Pension Liability Index at our balance sheet date which is linked to rates of return on high-quality, fixed-income investments. The discount rate used to value the future benefit obligation as of each year-end is the rate used to determine the periodic benefit cost in the following year. The expected long-term return on assets assumption for the pension plans represents the average rate of return to be earned on plan assets over the period the benefits included in the benefit obligation are to be paid. The actual fair value of plan assets and estimated rate of return is used to determine the expected investment return during the year. The estimated rate of return on plan assets is based on historical trends combined with long-term expectations, the mix of plan assets and long-term inflation assumptions. A decrease (increase) of 50 basis points in the expected return on assets assumption would increase (decrease) pension expense by approximately $43,000 based on the assets of the plan at September 30, 2016 . The effects of changing assumptions are included in unamortized net gains and losses, which directly affect accumulated other comprehensive income. These unamortized gains and losses in excess of certain thresholds are amortized and reclassified to income (loss) over the average remaining service life of active employees. Asset Retirement Obligation Barnwell accounts for asset retirement obligations by recognizing the fair value of a liability for an asset retirement obligation in the period in which it is incurred if a reasonable estimate of fair value can be made. Barnwell estimates the fair value of asset retirement obligations based on the projected discounted future cash outflows required to settle abandonment and restoration liabilities. Such an estimate requires assumptions and judgments regarding the existence of liabilities, the amount and timing of cash outflows required to settle the liability, what constitutes adequate restoration, inflation factors, credit adjusted discount rates, and consideration of changes in legal, regulatory, environmental and political environments. Abandonment and restoration cost estimates are determined in conjunction with Barnwell’s reserve engineers based on historical information regarding costs incurred to abandon and restore similar well sites, information regarding current market conditions and costs, and knowledge of subject well sites and properties. These assumptions represent Level 3 inputs. Barnwell’s estimated site restoration and abandonment costs of its oil and natural gas properties are capitalized as part of the carrying amount of oil and natural gas properties and depleted over the life of the related reserves. When the assumptions used to estimate a recorded asset retirement obligation change, a revision is recorded to both the asset retirement obligation and the capitalized cost of asset retirements. The liability is accreted at the end of each period through charges to oil and natural gas operating expense. Income Taxes Income taxes are determined using the asset and liability method. Deferred tax assets and liabilities are recognized for the estimated future tax impacts of differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates in effect for the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. A valuation allowance is provided when it is more likely than not that some portion or all of the deferred tax asset will not be realized. Management evaluates its potential exposures from tax positions taken that have been or could be challenged by taxing authorities. These potential exposures result because taxing authorities may take positions that differ from those taken by management in the interpretation and application of statutes, regulations and rules. Management considers the possibility of alternative outcomes based upon past experience, previous actions by taxing authorities (e.g., actions taken in other jurisdictions) and advice from tax experts. Recognized tax positions are initially and subsequently measured as the largest amount of tax benefit that is more likely than not of being realized upon ultimate settlement with a taxing authority on a jurisdiction-by-jurisdiction basis. Liabilities for unrecognized tax benefits related to such tax positions are included in long-term liabilities unless the tax position is expected to be settled within the upcoming year, in which case the liabilities are included in current liabilities. Interest and penalties related to uncertain tax positions are included in income tax expense. Contract Drilling Revenues, costs and profits applicable to contract drilling contracts are included in the Consolidated Statements of Operations using the percentage of completion method, principally measured by the percentage of labor dollars incurred to date for each contract to total estimated labor dollars for each contract. Contract losses are recognized in full in the period the losses are identified. The performance of drilling contracts may extend over more than a year and, in the interim periods, estimates of total contract costs and profits are used to determine revenues and profits earned for reporting the results of contract drilling operations. Revisions in the estimates required by subsequent performance and final contract settlements are included as adjustments to the results of operations in the period such revisions and settlements occur. Contracts are normally less than a year in duration. Environmental Barnwell is subject to extensive environmental laws and regulations. These laws, which are constantly changing, regulate the discharge of materials into the environment and maintenance of surface conditions and may require Barnwell to remove or mitigate the environmental effects of the disposal or release of petroleum or chemical substances at various sites. Environmental expenditures are expensed or capitalized depending on their future economic benefit. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefit are expensed. Liabilities for expenditures of a noncapital nature are recorded when environmental assessment and/or remediation is probable, and the costs can be reasonably estimated. Barnwell recognizes an insurance receivable related to environmental expenditures when collection of the receivable is deemed probable. Any recognition of an insurance receivable is recorded by crediting and offsetting the original charge. Any differential arising between insurance recoveries and insurance receivables is expensed or capitalized, consistent with the original treatment. Foreign Currency Translation Assets and liabilities of foreign subsidiaries are translated at the year-end exchange rate. Operating results of foreign subsidiaries are translated at average exchange rates during the period. Translation adjustments have no effect on net income and are included in “Accumulated other comprehensive loss, net” in stockholders’ equity. Fair Value Measurements Fair value is defined as the amount that would be received from the sale of an asset or paid for the transfer of a liability in an orderly transaction between market participants at the measurement date. Fair value measurements are classified and disclosed in one of the following categories: • Level 1: Unadjusted quoted prices in active markets for identical assets and liabilities in active markets and have the highest priority. • Level 2: Inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. • Level 3: Unobservable inputs for the financial asset or liability and have the lowest priority. Recent Accounting Pronouncements In April 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-08, “Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity.” This ASU relates to discontinued operations reporting for disposals of components of an entity that represent strategic shifts that have, or will have, a major effect on an entity’s operations and financial results. The standard expands the disclosures for discontinued operations and requires new disclosures related to individually material disposals that do not meet the definition of a discontinued operation. The Company adopted the provisions of this ASU effective October 1, 2015. The adoption of this update did not have a material impact on Barnwell’s consolidated financial statements. In November 2015, the FASB issued ASU 2015-17, “Balance Sheet Classification of Deferred Taxes,” which eliminates the requirement to present deferred tax assets and liabilities as current and noncurrent in a classified balance sheet. Instead, entities will be required to classify all deferred tax assets and liabilities, along with any related valuation allowance, as noncurrent. The Company prospectively adopted the provisions of this ASU effective July 1, 2016. The adoption of this ASU resulted in a reclassification of current deferred tax assets from the current assets section of the balance sheet to "Deferred income taxes" in the long-term liabilities sections of the balance sheet.

LIQUIDITY

LIQUIDITY	12 Months Ended
	Sep. 30, 2016
LIQUIDITY [Abstract]
LIQUIDITY	LIQUIDITY At September 30, 2016, Barnwell had $15,550,000 in cash and cash equivalents and working capital totaled $16,378,000 . Due to the negative impacts of 1) declines in oil and natural gas prices; 2) declines in oil and natural gas production due to both oil and natural gas property sales and the natural decline oil and natural gas wells experience as they age; 3) increasing costs due to both inflation and the age of Barnwell's properties and other factors, Barnwell's existing oil and natural gas assets are projected to have minimal cash flow from operations. 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, the timing of which are both highly uncertain and not within Barnwell’s control, to fund operations and provide capital for reinvestment. If the Company is unable to make sufficient and successful reinvestments, or if unforeseen circumstances arise that impair our ability to sustain or grow the Company, we may 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 after the date of these financial statements.

EARNINGS (LOSS) PER COMMON SHAR

EARNINGS (LOSS) PER COMMON SHARE	12 Months Ended
	Sep. 30, 2016
Earnings Per Share [Abstract]
EARNINGS PER COMMON SHARE	EARNINGS (LOSS) PER COMMON SHARE Basic earnings (loss) per share is computed using the weighted-average number of common shares outstanding for the period. Diluted earnings (loss) per share is calculated using the treasury stock method to reflect the assumed issuance of common shares for all potentially dilutive securities, which consist of outstanding stock options. Potentially dilutive shares are excluded from the computation of diluted earnings (loss) per share if their effect is anti-dilutive. Options to purchase 621,250 shares of common stock were excluded from the computation of diluted shares for both fiscal years 2016 and 2015 , as their inclusion would have been antidilutive. Reconciliations between net earnings (loss) attributable to Barnwell stockholders and common shares outstanding of the basic and diluted net earnings (loss) per share computations are detailed in the following tables: Year ended September 30, 2016 Net Loss Shares Per-Share (Numerator) (Denominator) Amount Basic net loss per share $ (3,615,000 ) 8,277,160 $ (0.44 ) Effect of dilutive securities - common stock options — — Diluted net loss per share $ (3,615,000 ) 8,277,160 $ (0.44 ) Year ended September 30, 2015 Net Earnings Shares Per-Share (Numerator) (Denominator) Amount Basic net earnings per share $ 1,263,000 8,277,160 $ 0.15 Effect of dilutive securities - common stock options — — Diluted net earnings per share $ 1,263,000 8,277,160 $ 0.15

SHARE-BASED PAYMENTS

SHARE-BASED PAYMENTS	12 Months Ended
	Sep. 30, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
SHARE-BASED PAYMENTS	SHARE-BASED PAYMENTS The Company’s share-based compensation benefit and related income tax effects are as follows: Year ended September 30, 2016 2015 Share-based benefit $ (22,000 ) $ (140,000 ) Income tax effect $ — $ — Share-based compensation benefit recognized in (loss) earnings for the years ended September 30, 2016 and 2015 are reflected in “General and administrative” expenses in the Consolidated Statements of Operations. There was no impact on income taxes for the years ended September 30, 2016 and 2015 due to a full valuation allowance on the related deferred tax asset. Description of Share-Based Payment Arrangements The Company’s stock option plans are administered by the Compensation Committee of the Board of Directors. The stockholder-approved 2008 Equity Incentive Plan provides for the issuance of incentive stock options, nonstatutory stock options, stock options with stock appreciation rights, restricted stock, restricted stock units and performance units, qualified performance-based awards, and stock grants to employees, consultants and non-employee members of the Board of Directors. 800,000 shares of Barnwell common stock have been reserved for issuance and as of September 30, 2016 , a total of 62,500 share options remain available for grant. Stock options grants include nonqualified stock options that have exercise prices equal to Barnwell’s stock price on the date of grant, vest annually over a service period of four years commencing one year from the date of grant and expire ten years from the date of grant. Certain options have stock appreciation rights that permit the holder to receive stock, cash or a combination thereof equal to the amount by which the fair market value, at the time of exercise of the option, exceeds the option price. Barnwell currently has a policy of issuing new shares to satisfy share option exercises when the optionee requests shares. As of September 30, 2016 , there was $8,000 of total unrecognized compensation cost related to nonvested share options. That cost is expected to be recognized over 1.2 years . Equity-classified Awards Compensation cost for equity-classified awards is measured at the grant date based on the fair value of the award and is recognized as an expense over the requisite service period. A summary of the activity in Barnwell’s equity-classified share options from October 1, 2015 through September 30, 2016 is presented below: Options Shares Weighted- Weighted- Aggregate Outstanding at October 1, 2015 30,000 $ 3.01 Granted — — Exercised — — Expired/Forfeited — — Outstanding at September 30, 2016 30,000 $ 3.01 7.2 $ — Exercisable at September 30, 2016 15,000 $ 3.01 7.2 $ — Total share-based compensation expense for equity-classified awards vested in the years ended September 30, 2016 and 2015 was $10,000 and $20,000 , respectively. Liability-classified Awards Compensation cost for liability-classified awards is remeasured to current fair value using a closed-form valuation model based on current values at each period end with the change in fair value recognized as an expense or benefit until the award is settled. The following assumptions were used in estimating fair value for all liability-classified share options outstanding: Year ended September 30, 2016 2015 Expected volatility range 56.7% to 72.7% 51.5% to 61.6% Weighted-average volatility 63.6% 52.4% Expected dividends None None Expected term (in years) 1.2 to 7.2 2.2 to 8.2 Risk-free interest rate 0.6% to 1.4% 0.6% to 1.9% Expected forfeitures None None The application of alternative assumptions could produce significantly different estimates of the fair value of share-based compensation, and consequently, the related costs reported in the Consolidated Statements of Operations. A summary of the activity in Barnwell’s liability-classified share options from October 1, 2015 through September 30, 2016 is presented below: Options Shares Weighted- Weighted- Aggregate Outstanding at October 1, 2015 591,250 $ 7.98 Granted — — Exercised — — Expired/Forfeited — — Outstanding at September 30, 2016 591,250 $ 7.98 2.5 $ — Exercisable at September 30, 2016 576,250 $ 8.11 2.4 $ — The following table summarizes the components of the total share-based compensation for liability-classified awards: Year ended September 30, 2016 2015 Due to vesting $ 4,000 $ 10,000 Due to remeasurement (36,000 ) (170,000 ) Total share-based compensation benefit for liability-based awards $ (32,000 ) $ (160,000 )

ACCOUNTS RECEIVABLE AND CONTRAC

ACCOUNTS RECEIVABLE AND CONTRACT COSTS	12 Months Ended
	Sep. 30, 2016
Receivables [Abstract]
ACCOUNTS RECEIVABLE AND CONTRACT COSTS	ACCOUNTS RECEIVABLE AND CONTRACT COSTS Accounts receivable are net of allowances for doubtful accounts of $40,000 and $23,000 as of September 30, 2016 and 2015 , respectively. Included in accounts receivable are contract retainage balances of $202,000 and $257,000 as of September 30, 2016 and 2015 , respectively. The retainage balance as of September 30, 2016 is expected to be collected within one year, generally within 45 days after the related contracts have received final acceptance and approval. Costs and estimated earnings on uncompleted contracts are as follows: September 30, 2016 2015 Costs incurred on uncompleted contracts $ 966,000 $ 1,890,000 Estimated earnings 70,000 226,000 1,036,000 2,116,000 Less billings to date 1,112,000 2,503,000 $ (76,000 ) $ (387,000 ) Costs and estimated earnings on uncompleted contracts are included in the Consolidated Balance Sheets as follows: September 30, 2016 2015 Costs and estimated earnings in excess of billings on uncompleted contracts (included in other current assets) $ 89,000 $ 182,000 Billings in excess of costs and estimated earnings on uncompleted contracts (included in other current liabilities) (165,000 ) (569,000 ) $ (76,000 ) $ (387,000 )

ASSETS HELD FOR SALE

ASSETS HELD FOR SALE	12 Months Ended
	Sep. 30, 2016
Asset held for sale [Abstract]
Asset held for sale	ASSET HELD FOR SALE At September 30, 2016 , the Company had listed for sale its New York office. Accordingly, the Company designated this property as asset held for sale and recorded the carrying value of this property in the aggregate amount of $1,829,000 as "Asset held for sale" on the Company's Consolidated Balance Sheet at September 30, 2016 .

INVESTMENT HELD FOR SALE

INVESTMENT HELD FOR SALE	12 Months Ended
	Sep. 30, 2016
INVESTMENT HELD FOR SALE [Abstract]
Investment held for sale	INVESTMENT HELD FOR SALE At September 30, 2016, Kaupulehu 2007 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. A second residential parcel was sold in October 2014 for $1,250,000 for a nominal loss which is included in "General and administrative" expenses in the Consolidated Statement of Operations for the year ended September 30, 2015.

REAL ESTATE HELD FOR SALE

REAL ESTATE HELD FOR SALE	12 Months Ended
	Sep. 30, 2016
Real Estate [Abstract]
REAL ESTATE HELD FOR SALE	REAL ESTATE HELD FOR SALE 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, income in the amount of $190,000 was recognized during the year ended September 30, 2016.

INVESTMENTS

INVESTMENTS	12 Months Ended
	Sep. 30, 2016
Investments, All Other Investments [Abstract]
INVESTMENTS	INVESTMENTS A summary of Barnwell’s non-current investments is as follows: September 30, 2016 2015 Investment in Kukio Resort land development partnerships $ 3,502,000 $ 6,238,000 Investment in leasehold land interest – Lot 4C 50,000 50,000 Total non-current investments $ 3,552,000 $ 6,288,000 Investment in Kukio Resort land development partnerships On November 27, 2013, Barnwell, through a wholly-owned subsidiary, entered into two limited liability limited partnerships, KD Kona 2013 LLLP and KKM Makai, LLLP, and indirectly acquired a 19.6% non-controlling ownership interest in each of KD Kukio Resorts, LLLP, KD Maniniowali, LLLP and KD Kaupulehu, LLLP for $5,140,000 . 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 is comprised of KD I and KD II, is the developer of Kaupulehu Lot 4A Increments I and II, the area in which Barnwell has interests in percentage of sales payments. Barnwell’s investment in these entities is accounted for using the equity method of accounting. The partnerships derive income from the sale of residential parcels, of which 25 lots remained to be sold at Kaupulehu Increment I and one ocean front parcel over two acres in size remained to be sold in Kaupulehu Increment II at September 30, 2016, as well as from commissions on real estate sales by the real estate sales office. In April 2016, the Kukio Resort land development partnerships made a cash distribution to its partners of which Barnwell received $5,320,000 , after distributing $40,000 to minority interests. Equity in income of affiliates was $2,624,000 and $1,580,000 for the years ended September 30, 2016 and 2015 , respectively. The equity in the underlying net assets of the Kukio Resort land development partnerships exceeds the carrying value of the investment in affiliates by approximately $351,000 as of September 30, 2016 , which is attributable to differences in the value of capitalized development costs and a note receivable. The basis difference for the capitalized development costs will be recognized as the partnerships sell lots and recognize the associated costs. The basis difference for the note receivable will be recognized as the partnerships sell memberships for the Kuki`o Golf and Beach Club for which the receivable relates. The basis difference adjustments of $39,000 and $82,000 , for the years ended September 30, 2016 and 2015 , respectively, increased equity in income of affiliates. 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 September 30, 2016 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 bonds 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 September 30, 2016 , Barnwell’s maximum loss exposure as a result of its investment in the Kukio Resort land development partnerships was approximately $3,827,000 , consisting of the carrying value of the investment of $3,502,000 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 is as follows: Year ended Year ended September 30, 2016 September 30, 2015 Revenue $ 33,874,000 $ 29,898,000 Gross profit $ 15,332,000 $ 13,594,000 Net earnings $ 12,212,000 $ 7,500,000 Percentage of sales payments 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 20). 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: 9% of the gross proceeds from single-family lot sales up to aggregate gross proceeds of $100,000,000 ; 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 . In fiscal 2016 , three single-family lots in Increment I were sold bringing the total amount of gross proceeds from single-family lot sales through September 30, 2016 to $205,000,000 . As of September 30, 2016 , 25 single-family lots, of the 80 lots developed within Increment I, remained to be sold. 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 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 up to $8,000,000 in additional payments after the members of KD II have received distributions equal to the capital they invested in the project. Two ocean front parcels approximately two to three acres in size fronting the ocean were developed within Increment II by KD II, and 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. As of September 30, 2016 , one of the ocean front parcels remained to be sold. The following table summarizes the Increment I and Increment II percentage of sales payment revenues received from KD I and KD II: Year ended September 30, 2016 2015 Sale of interest in leasehold land: Proceeds $ 2,255,000 $ 3,772,000 Fees (340,000 ) (528,000 ) Revenues – sale of interest in leasehold land, net $ 1,915,000 $ 3,244,000 There is no assurance with regards to the amounts of future payments from Increment I or Increment II to be received. Investment in leasehold land interest – Lot 4C Kaupulehu Developments holds an interest in an area of approximately 1,000 acres of vacant leasehold land zoned conservation located adjacent to Lot 4A, which currently has no development potential without both a development agreement with the lessor and zoning reclassification. The lease terminates in December 2025.

OIL AND NATURAL GAS PROPERTIES

OIL AND NATURAL GAS PROPERTIES	12 Months Ended
	Sep. 30, 2016
Extractive Industries [Abstract]
OIL AND NATURAL GAS PROPERTIES	OIL AND NATURAL GAS PROPERTIES 2016 Acquisition On September 12, 2016, Barnwell completed the acquisition of additional working interests in oil and natural gas properties located in the Wood River area of Alberta, Canada, for cash consideration. The sales price per the agreement was adjusted for customary purchase price adjustments to $769,000 in order to, among other things, reflect an economic effective date of September 1, 2016. The final determination of the customary adjustments to the purchase price has not yet been made however it is not expected to result in material adjustments. The Wood River acquisition was accounted for under the acquisition method of accounting, and as such, Barnwell estimated the fair value of the acquired property as of the September 12, 2016 acquisition date. The following table summarizes the allocation of the consideration paid to acquire the properties to the assets acquired and liabilities assumed in the transaction as of the acquisition date. See Note 17 for further information regarding the fair value measurement inputs. Property and equipment $ 813,000 Asset retirement obligation (44,000 ) Net identifiable assets acquired $ 769,000 The results of operations for the Wood River acquisition has been included in the consolidated financial statements from the closing date. Pro forma information is not presented as the pro forma results would not be materially different from the information presented in the Consolidated Statement of Operations. 2015 Acquisitions On November 13, 2014, Barnwell completed the acquisition of additional working interests in oil and natural gas properties located in the Progress area of Alberta, Canada, for cash consideration. The sales price per the agreement was adjusted for customary purchase price adjustments to $526,000 in order to, among other things, reflect an economic effective date of July 1, 2014. The Progress acquisition was accounted for under the acquisition method of accounting, and as such, Barnwell estimated the fair value of the acquired property as of the November 13, 2014 acquisition date. The following table summarizes the allocation of the consideration paid to acquire the properties to the assets acquired and liabilities assumed in the transaction as of the acquisition date. See Note 17 for further information regarding the fair value measurement inputs. Property and equipment $ 751,000 Asset retirement obligation (225,000 ) Net identifiable assets acquired $ 526,000 On August 27, 2015, Barnwell completed the acquisition of additional working interests in oil and natural gas properties located in the Progress area of Alberta, Canada, for cash consideration. The sales price per the agreement was adjusted for customary purchase price adjustments to $306,000 in order to, among other things, reflect an economic effective date of June 1, 2015. The Progress acquisition was accounted for under the acquisition method of accounting, and as such, Barnwell estimated the fair value of the acquired property as of the August 27, 2015 acquisition date. The following table summarizes the allocation of the consideration paid to acquire the properties to the assets acquired and liabilities assumed in the transaction as of the acquisition date. See Note 17 for further information regarding the fair value measurement inputs. Property and equipment $ 397,000 Asset retirement obligation (91,000 ) Net identifiable assets acquired $ 306,000 The results of operations for both of the Progress acquisitions have been included in the consolidated financial statements from the closing dates. Pro forma information is not presented as the pro forma results would not be materially different from the information presented in the Consolidated Statement of Operations. 2015 Disposition Barnwell entered into a purchase and sale agreement with an independent third party and, in September 2015, sold its interests in its principal oil and natural gas properties located in the Dunvegan and Belloy areas of Alberta, Canada. The sales price per the agreement was adjusted for preliminary purchase price adjustments to approximately $21,875,000 in order to, among other things, reflect an economic effective date of April 1, 2015. Barnwell's share, after broker's fees and other closing costs, was approximately $14,162,000 and third parties', who were working interest owners in the properties prior to the sale, share, in the aggregate, was approximately $7,247,000 . The relationship between capitalized costs and proved reserves of the sold property and retained properties was significant as there was a 220% 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 Dunvegan of $6,217,000 in the year ended September 30, 2015 in accordance with the guidance in Rule 4-10(c)(6)(i) of Regulation S-X, 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 $2,013,000 assumed by the purchaser. The disposition was recorded in fiscal 2015 using preliminary purchase price adjustments. Barnwell and the purchaser updated and finalized the purchase price adjustments in accordance with the terms of the purchase and sale agreement during fiscal 2016 which resulted in additional proceeds of $493,000 and the recognition of an additional gain in the amount of $472,000 during the year ended September 30, 2016, bringing the total gain on the sale of these properties to $6,689,000 . The unaudited pro forma results of operations are presented below as though the disposition of Dunvegan occurred on October 1, 2014. The unaudited pro forma results do not purport to represent what our actual results of operations would have been if the disposition had been completed on such date or to project our results of operations for any future date or period. The pro forma information includes adjustments to oil and natural gas segment revenues and operating expenses based on the actual results of operations related to Dunvegan, as well as adjustments for estimated depletion, accretion expense, general and administrative expenses, and income taxes based on an allocation of the estimated impact of Dunvegan on those amounts. Year ended September 30, 2015 Pro forma (unaudited) Historical Pro forma Total revenues $ 17,533,000 $ 13,235,000 Net earnings (loss) $ 1,769,000 $ (761,000 ) Net earnings (loss) attributable to Barnwell Industries, Inc. stockholders $ 1,263,000 $ (1,267,000 ) Net earnings (loss) per common share attributable to Barnwell Industries, Inc. stockholders. $ 0.15 $ (0.15 )

PROPERTY AND EQUIPMENT AND ASSE

PROPERTY AND EQUIPMENT AND ASSET RETIREMENT OBLIGATION	12 Months Ended
	Sep. 30, 2016
PROPERTY AND EQUIPMENT AND ASSET RETIREMENT OBLIGATION
PROPERTY AND EQUIPMENT AND ASSET RETIREMENT OBLIGATION	PROPERTY AND EQUIPMENT AND ASSET RETIREMENT OBLIGATION Barnwell’s property and equipment is detailed as follows: Estimated Gross Accumulated Net At September 30, 2016: Land $ 365,000 $ — $ 365,000 Oil and natural gas properties (full cost accounting) 66,265,000 (61,060,000 ) 5,205,000 Drilling rigs and equipment 3 – 10 years 6,379,000 (5,770,000 ) 609,000 Office 40 years 857,000 (274,000 ) 583,000 Other property and equipment 3 – 17 years 3,002,000 (2,862,000 ) 140,000 Total $ 76,868,000 $ (69,966,000 ) $ 6,902,000 Estimated Gross Accumulated Net At September 30, 2015: Land $ 863,000 $ — $ 863,000 Oil and natural gas properties (full cost accounting) 63,105,000 (57,460,000 ) 5,645,000 Drilling rigs and equipment 3 – 10 years 6,598,000 (5,825,000 ) 773,000 Offices 40 years 2,420,000 (445,000 ) 1,975,000 Other property and equipment 3 – 17 years 2,967,000 (2,755,000 ) 212,000 Total $ 75,953,000 $ (66,485,000 ) $ 9,468,000 See Note 6 for discussion of the designation of the New York office as an asset held for sale at September 30, 2016. See Note 10 for discussion of acquisitions and divestitures of oil and natural gas properties in fiscal 2016 and 2015 . Barnwell recognizes the fair value of a liability for an asset retirement obligation in the period in which it is incurred if a reasonable estimate of fair value can be made. The following is a reconciliation of the asset retirement obligation: Year ended September 30, 2016 2015 Asset retirement obligation as of beginning of year $ 6,936,000 $ 9,163,000 Obligations incurred on new wells drilled or acquired 167,000 316,000 Liabilities associated with properties sold — (2,013,000 ) Revision of estimated obligation (68,000 ) 918,000 Accretion expense 464,000 632,000 Payments (459,000 ) (655,000 ) Foreign currency translation adjustment 154,000 (1,425,000 ) Asset retirement obligation as of end of year 7,194,000 6,936,000 Less current portion (1,017,000 ) (506,000 ) Asset retirement obligation, long-term $ 6,177,000 $ 6,430,000 Asset retirement obligations were reduced by $2,013,000 in fiscal 2015 for those obligations that were assumed by purchasers of Barnwell's oil and natural gas properties. Barnwell recognized an additional $918,000 of abandonment and reclamation capitalized costs and liabilities in fiscal 2015 for upward revisions to prior year estimates of costs as a result of the receipt of new and more specific information regarding costs to abandon wells similar to Barnwell’s. There were no such obligations assumed or significant revisions in fiscal 2016.

LONG-TERM DEBT

LONG-TERM DEBT	12 Months Ended
	Sep. 30, 2016
Debt Disclosure [Abstract]
LONG-TERM DEBT	LONG-TERM DEBT Canadian revolving credit facility On September 30, 2015, Barnwell’s revolving credit facility at Royal Bank of Canada was amended and reduced by the bank to $1,000,000 Canadian dollars, as a result of the sale of the Company's principal oil and natural gas property, Dunvegan, in September 2015. Barnwell repaid the credit facility in full from the proceeds of the disposition. In April 2016, the revolving credit facility was terminated. Barnwell repaid $7,000,000 of the Canadian revolving credit facility during the year ended September 30, 2015 and realized foreign currency transaction losses of $752,000 as a result of the repayment of U.S. dollar denominated debt using Canadian dollars, which is included in "General and administrative" expenses on the Consolidated Statements of Operations for the year ended September 30, 2015. Canadian revolving demand facility In June 2016, Barnwell entered into a new agreement with Royal Bank of Canada for a revolving demand facility in the amount of $500,000 Canadian dollars, or U.S. $381,000 at the September 30, 2016 exchange rate. Borrowings under this facility were $0 and issued letters of credit were $34,000 at September 30, 2016 . The revolving demand facility is available in U.S. dollars at LIBOR plus 1.0% , at Royal Bank of Canada’s U.S. base rate, or in Canadian dollars at Royal Bank of Canada’s prime rate. The obligations under the credit facility are secured by a $500,000 Canadian dollar, or U.S. $381,000 at the September 30, 2016 exchange rate, guaranteed investment certificate pledged to the Royal Bank of Canada, which is classified as "Restricted cash" on the accompanying Consolidated Balance Sheet at September 30, 2016. Real estate loan Barnwell, together with its real estate joint venture, Kaupulehu 2007, had a non-revolving real estate loan with a Hawaii bank. At September 30, 2015, the balance of the real estate loan was $3,440,000 . In April 2016, the home collateralizing the loan was sold and in accordance with the terms of the loan agreement a portion of the proceeds from the sale was used to repay the real estate loan in full.

RETIREMENT PLANS

RETIREMENT PLANS	12 Months Ended
	Sep. 30, 2016
Compensation and Retirement Disclosure [Abstract]
RETIREMENT PLANS	RETIREMENT PLANS Barnwell sponsors a noncontributory defined benefit pension plan (“Pension Plan”) covering substantially all of its U.S. employees, with benefits based on years of service and the employee’s highest consecutive 5 years average earnings. Barnwell’s funding policy is intended to provide for both benefits attributed to service to date and for those expected to be earned in the future. In addition, 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 officers of Barnwell Industries, Inc., the parent company, who have attained at least 20 years of service of which at least 10 years were at the position of Vice President or higher, their spouses and qualifying dependents. The following tables detail the changes in benefit obligations, fair values of plan assets and reconciliations of the funded status of the retirement plans: Pension SERP Postretirement Medical September 30, 2016 2015 2016 2015 2016 2015 Change in Projected Benefit Obligation: Benefit obligation at beginning of year $ 8,683,000 $ 8,299,000 $ 1,900,000 $ 1,767,000 $ 1,319,000 $ 1,227,000 Service cost 261,000 256,000 68,000 62,000 — — Interest cost 364,000 356,000 86,000 77,000 56,000 52,000 Actuarial loss 953,000 110,000 318,000 — 1,111,000 40,000 Benefits paid (206,000 ) (326,000 ) (6,000 ) (6,000 ) — — Administrative expenses paid — (12,000 ) — — — — Benefit obligation at end of year 10,055,000 8,683,000 2,366,000 1,900,000 2,486,000 1,319,000 Change in Plan Assets: Fair value of plan assets at beginning of year 6,488,000 7,022,000 — — — — Actual return (loss) on plan assets 813,000 (446,000 ) — — — — Employer contributions 1,100,000 250,000 6,000 6,000 — — Benefits paid (206,000 ) (326,000 ) (6,000 ) (6,000 ) — — Administrative expenses paid — (12,000 ) — — — — Fair value of plan assets at end of year 8,195,000 6,488,000 — — — — Funded status $ (1,860,000 ) $ (2,195,000 ) $ (2,366,000 ) $ (1,900,000 ) $ (2,486,000 ) $ (1,319,000 ) Pension SERP Postretirement Medical September 30, 2016 2015 2016 2015 2016 2015 Amounts recognized in the Consolidated Balance Sheets: Current liabilities $ — $ — $ (5,000 ) $ (5,000 ) $ — $ — Noncurrent liabilities (1,860,000 ) (2,195,000 ) (2,361,000 ) (1,895,000 ) (2,486,000 ) (1,319,000 ) Net amount $ (1,860,000 ) $ (2,195,000 ) $ (2,366,000 ) $ (1,900,000 ) $ (2,486,000 ) $ (1,319,000 ) Amounts recognized in accumulated other comprehensive loss (income) before income taxes: Net actuarial loss (gain) $ 3,521,000 $ 3,038,000 $ 797,000 $ 506,000 $ 1,001,000 $ (110,000 ) Prior service cost (credit) 70,000 77,000 (70,000 ) (76,000 ) — — Accumulated other comprehensive loss (income) $ 3,591,000 $ 3,115,000 $ 727,000 $ 430,000 $ 1,001,000 $ (110,000 ) Barnwell estimates that it will make approximately $500,000 in contributions to the Pension Plan during fiscal 2017 . The SERP and Postretirement Medical plans are unfunded and Barnwell will fund benefits when payments are made. Expected payments under the Postretirement Medical plan and SERP for fiscal 2017 are not significant. Fluctuations in actual 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. The pension plan actuarial losses in fiscal 2016 were primarily due to a decrease in the discount rate which was slightly offset by actual investment returns being greater than the assumed rate of return and an updated mortality projection scale. The SERP actuarial losses in fiscal 2016 were primarily due to a decrease in the discount rate which was slightly offset by an updated mortality projection scale. The postretirement medical plan actuarial losses in fiscal 2016 were primarily due to increases in the medical insurance premium assumptions and a decrease in the discount rate which were slightly offset by an updated mortality projection scale. The pension plan actuarial losses in fiscal 2015 were primarily due to actual investment returns being lower than the assumed rate of return. The following table presents the weighted-average assumptions used to determine benefit obligations and net benefit costs: Pension SERP Postretirement Medical Year ended September 30, 2016 2015 2016 2015 2016 2015 Assumptions used to determine fiscal year-end benefit obligations: Discount rate 3.50% 4.25% 3.50% 4.25% 3.50% 4.25% Rate of compensation increase 4.00% 4.00% 4.00% 4.00% N/A N/A Assumptions used to determine net benefit costs (years ended): Discount rate 4.25% 4.25% 4.25% 4.25% 4.25% 4.25% Expected return on plan assets 7.00% 7.00% N/A N/A N/A N/A Rate of compensation increase 4.00% 4.00% 4.00% 4.00% N/A N/A The components of net periodic benefit cost are as follows: Pension SERP Postretirement Medical Year ended September 30, 2016 2015 2016 2015 2016 2015 Net periodic benefit cost for the year: Service cost $ 261,000 $ 256,000 $ 68,000 $ 62,000 $ — $ — Interest cost 364,000 356,000 86,000 77,000 56,000 52,000 Expected return on plan assets (484,000 ) (500,000 ) — — — — Amortization of prior service cost (credit) 5,000 5,000 (5,000 ) (5,000 ) — — Amortization of net actuarial loss (gain) 141,000 86,000 27,000 24,000 — (5,000 ) Net periodic benefit cost $ 287,000 $ 203,000 $ 176,000 $ 158,000 $ 56,000 $ 47,000 The amounts that are estimated to be amortized from accumulated other comprehensive loss into net periodic benefit cost in the next fiscal year are as follows: Pension SERP Postretirement Prior service cost (credit) $ 5,000 $ (5,000 ) $ — Net actuarial loss 163,000 36,000 188,000 $ 168,000 $ 31,000 $ 188,000 The accumulated benefit obligation differs from the projected benefit obligation in that it assumes future compensation levels will remain unchanged. The accumulated benefit obligation for the pension plan was $8,566,000 and $7,420,000 at September 30, 2016 and 2015 , respectively. The accumulated benefit obligation for the SERP was $1,822,000 and $1,458,000 at September 30, 2016 and 2015 , respectively. The benefits expected to be paid under the retirement plans as of September 30, 2016 are as follows: Pension SERP Postretirement Expected Benefit Payments: Fiscal year ending September 30, 2017 $ 279,000 $ 5,000 $ — Fiscal year ending September 30, 2018 $ 298,000 $ 4,000 $ 42,000 Fiscal year ending September 30, 2019 $ 284,000 $ 3,000 $ 44,000 Fiscal year ending September 30, 2020 $ 389,000 $ 72,000 $ 39,000 Fiscal year ending September 30, 2021 $ 413,000 $ 73,000 $ 72,000 Fiscal years ending September 30, 2022 through 2026 $ 2,511,000 $ 642,000 $ 413,000 The following table provides the assumed health care cost trend rates related to the measurement of Barnwell’s postretirement medical obligations. Year ended September 30, 2016 2015 Health care cost trend rates assumed for next year 7.75% 8.0% Ultimate cost trend rate 5.0% 5.0% Year that the rate reaches the ultimate trend rate 2028 2028 An 8.0% annual rate of increase in the per capita cost of covered health care benefits was assumed for fiscal 2016 . This assumption is based on the plans’ recent experience. It is assumed that the rate will decrease gradually to 5% for fiscal 2028 and remain level thereafter. The assumed health care cost trend rates have a significant effect on the amounts reported for the postretirement medical obligations. A one-percentage-point change in the assumed health care cost trend rates would have the following effects: 1-Percentage 1-Percentage Effect on total service and interest cost components $ 11,000 $ (9,000 ) Effect on accumulated postretirement benefit obligations $ 527,000 $ (416,000 ) Plan Assets Management communicates periodically with its professional investment advisors to establish investment policies, direct investments and select investment options. The overall investment objective of the Pension Plan is to attain a diversified combination of investments that provides long-term growth in the assets of the plan to fund future benefit obligations while managing risk in order to meet current benefit obligations. Generally, interest and dividends received provide cash flows to fund current benefit obligations. Longer-term obligations are generally estimated to be provided for by growth in equity securities. The Company’s investment policy permits investments in a diversified mix of U.S. and international equities, fixed income securities and cash equivalents. Barnwell’s investments in fixed income securities include corporate bonds, preferred securities, and fixed income exchange-traded funds. The Company’s investments in equity securities primarily include domestic and international large-cap companies, as well as, domestic and international equity securities exchange-traded funds. Plan assets include $4,000 of Barnwell’s stock at September 30, 2016 . The Company’s year-end target allocation, by asset category, and the actual asset allocations were as follows: Target September 30, Asset Category Allocation 2016 2015 Cash and other 0% - 30% 7% 9% Fixed income securities 20% - 60% 23% 22% Equity securities 30% - 70% 70% 69% Actual investment allocations may vary from our target allocations from time to time due to prevailing market conditions. We periodically review our actual investment allocations and rebalance our investments to our target allocations as dictated by current and anticipated market conditions and required cash flows. We categorize plan assets into three levels based upon the assumptions used to price the assets. Level 1 provides the most reliable measure of fair value, whereas Level 3 requires significant management judgment in determining the fair value. Equity securities and exchange-traded funds are valued by obtaining quoted prices on recognized and highly liquid exchanges. Fixed income securities are valued based upon the closing price reported in the active market in which the security is traded. All of our plan assets are categorized as Level 1 assets, and as such, the actual market value is used to determine the fair value of assets. The following tables set forth by level, within the fair value hierarchy, pension plan assets at their fair value: Fair Value Measurements Using: Carrying Quoted Significant Significant Financial Assets: Cash $ 571,000 $ 571,000 $ — $ — Corporate bonds 316,000 316,000 — — Fixed income exchange-traded funds 1,414,000 1,414,000 — — Preferred securities 184,000 184,000 — — Equity securities exchange-traded funds 818,000 818,000 — — Equities 4,892,000 4,892,000 — — Total $ 8,195,000 $ 8,195,000 $ — $ — Fair Value Measurements Using: Carrying Quoted Significant Significant Financial Assets: Cash $ 621,000 $ 621,000 $ — $ — Corporate bonds 354,000 354,000 — — Fixed income exchange-traded funds 819,000 819,000 — — Preferred securities 230,000 230,000 — — Equity securities exchange-traded funds 764,000 764,000 — — Equities 3,700,000 3,700,000 — — Total $ 6,488,000 $ 6,488,000 $ — $ —

INCOME TAXES

INCOME TAXES	12 Months Ended
	Sep. 30, 2016
Income Tax Disclosure [Abstract]
INCOME TAXES	INCOME TAXES The components of earnings (loss) before income taxes, after adjusting the earnings (loss) for non-controlling interests, are as follows: Year ended September 30, 2016 2015 United States $ (360,000 ) $ 1,011,000 Canada (3,977,000 ) 1,460,000 $ (4,337,000 ) $ 2,471,000 The components of the income tax provision (benefit) related to the above income (loss) are as follows: Year ended September 30, 2016 2015 Current (benefit) provision: United States – Federal $ — $ — United States – State — 94,000 — 94,000 Canadian (651,000 ) 1,529,000 Total current (651,000 ) 1,623,000 Deferred (benefit) provision: United States - Federal — (90,000 ) United States - State 220,000 — Canadian (291,000 ) (325,000 ) Total deferred (71,000 ) (415,000 ) $ (722,000 ) $ 1,208,000 During fiscal 2015, Barnwell determined that it was not more likely than not that all of our oil and natural gas deferred tax assets under Canadian tax law were realizable due to significant declines in oil and natural gas prices, which in turn restricted funds available for the oil and natural gas capital expenditures needed to replace production and abate declining reserves. As a result the Company recorded a valuation allowance for the portion of Canadian tax law deferred tax assets related to asset retirement obligations that may not be realizable. The change in the valuation allowance related to asset retirement obligations and Canadian branch tax loss carryforwards that may not be realizable included in the deferred income tax provision (benefit) for the years ended September 30, 2016 and 2015, was a charge of $292,000 and $1,028,000 , respectively. On June 29, 2015, the Canadian province of Alberta enacted legislation that increased the provincial corporate tax rate from 10% to 12% , effective July 1, 2015, bringing the total Canadian statutory tax rate applicable to our business from 28.75% to 30.65% . The impact of the enactment, which was not significant, was recorded as a charge to income taxes during the year ended September 30, 2015. 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, Canadian income taxes are not estimated to have a future benefit as foreign tax credits or deductions for U.S. tax purposes, and U.S. consolidated net operating losses and other deferred tax assets under U.S. tax law are not estimated to have any future U.S. tax benefit. In addition, consolidated taxes include the aforementioned valuation allowance for a portion of deferred tax assets under Canadian tax law. A reconciliation between the reported income tax (benefit) provision and the amount computed by multiplying the earnings (loss) attributable to Barnwell before income taxes by the U.S. federal tax rate of 35% is as follows: Year ended September 30, 2016 2015 Tax (benefit) provision computed by applying statutory rate $ (1,518,000 ) $ 865,000 Increase in the valuation allowance - U.S. federal and Canadian tax law 1,051,000 1,653,000 Additional effect of the foreign tax provision on the total tax provision (484,000 ) (1,243,000 ) U.S. state deferred tax provision 220,000 — Other 9,000 (67,000 ) $ (722,000 ) $ 1,208,000 The tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred tax liabilities are as follows: September 30, 2016 2015 Deferred income tax assets: U.S. tax effect of deferred Canadian taxes $ — $ 91,000 Foreign tax credit carryover 4,028,000 4,661,000 Alternative minimum tax credit carryover 460,000 460,000 U.S. federal net operating loss carryover 8,728,000 4,440,000 Tax basis of investment in land and residential real estate in excess of book basis 836,000 1,115,000 Property and equipment accumulated book depreciation and depletion in excess of tax under U.S. tax law 3,611,000 4,494,000 Liabilities accrued for books but not for tax under U.S. tax law 4,843,000 4,423,000 Liabilities accrued for books but not for tax under Canadian tax law 2,303,000 2,149,000 Other 1,108,000 746,000 Total gross deferred tax assets 25,917,000 22,579,000 Less valuation allowance (23,410,000 ) (21,387,000 ) Net deferred income tax assets 2,507,000 1,192,000 Deferred income tax liabilities: Property and equipment accumulated tax depreciation and depletion in excess of book under Canadian tax law (1,012,000 ) (1,459,000 ) Book basis of investment in land development partnerships in excess of tax basis (1,668,000 ) — Other (31,000 ) (4,000 ) Total deferred income tax liabilities (2,711,000 ) (1,463,000 ) Net deferred income tax liability $ (204,000 ) $ (271,000 ) Net deferred income tax liability is included in the Consolidated Balance Sheets as follows: September 30, 2016 2015 Current deferred income tax asset (included in other current assets) $ — $ 178,000 Deferred income tax liability (204,000 ) (449,000 ) Net deferred income tax liability $ (204,000 ) $ (271,000 ) The total valuation allowance increased $2,023,000 for the year ended September 30, 2016 . The increase was primarily due to an increase in the valuation allowance for deferred tax assets under U.S. federal tax law primarily related to an increase in U.S. federal net operating loss carryovers that are not more likely than not to have a future tax benefit and the aforementioned valuation allowance necessary for the portion of Canadian tax law deferred tax assets that may not be realizable. The increase was partially offset by a decrease in the valuation allowance due to changes in various other deferred tax assets for which a full valuation allowance had been provided. Of the total net increase in the valuation allowance for fiscal 2016 , $1,344,000 was recognized as income tax expense and $679,000 was charged to accumulated other comprehensive loss. Net deferred tax assets at September 30, 2016 of $2,507,000 consists of the portion of deferred tax assets for which it is estimated that it is more likely than not that such future deductions will be realizable as the result of concurrent deferred tax liability reversals or tax loss carryback strategies under Canadian tax law. At September 30, 2016 , Barnwell had foreign tax credit carryovers, alternative minimum tax credit carryovers, and U.S. federal net operating loss carryovers totaling $4,028,000 , $460,000 and $25,671,000 , respectively. All three items were fully offset by valuation allowances at September 30, 2016 . The net operating loss carryovers expire in fiscal years 2032-2036, and the foreign tax credit carryovers expire in fiscal years 2019-2025. FASB ASC Topic 740, Income Taxes , prescribes a threshold for recognizing the financial statement effects of a tax position when it is more likely than not, based on the technical merits, that the position will be sustained upon examination by a taxing authority. Barnwell files U.S. federal income tax returns, income tax returns in various U.S. states, and Canadian federal and provincial tax returns. A number of years may elapse before an uncertain tax position, for which we have unrecognized tax benefits, is audited and finally resolved. While it is often difficult to predict the final outcome or the timing of resolution of any particular uncertain tax position, we believe that our unrecognized tax benefits reflect the more likely than not outcome. We adjust these unrecognized tax benefits, as well as the related interest, based on ongoing changes in facts and circumstances. Settlement of any particular position could require the use of cash. Favorable resolution for an amount less than the amount estimated by Barnwell would be recognized as a decrease in the effective income tax rate in the period of resolution, and unfavorable resolution in excess of the amount estimated by Barnwell would be recognized as an increase in the effective income tax rate in the period of resolution. Below are the changes in unrecognized tax benefits. Year ended September 30, 2016 2015 Balance at beginning of year $ 582,000 $ 660,000 Effect of tax positions taken in prior years — 92,000 Accrued interest related to tax positions taken 20,000 38,000 Lapse of statute (173,000 ) (174,000 ) Translation adjustments (52,000 ) (34,000 ) Balance at end of year $ 377,000 $ 582,000 The total amount of unrecognized tax benefits at September 30, 2016 that, if recognized, would impact the effective tax rate was $377,000 . Included in the liability for unrecognized tax benefits at September 30, 2016 and 2015 , is accrued interest of $35,000 and $113,000 , respectively. Uncertain tax positions consist primarily of Canadian federal and provincial issues that involve transfer pricing adjustments. Because of a lack of clarity and uniformity regarding allowable transfer pricing valuations by differing jurisdictions, it is reasonably possible that the total amount of uncertain tax positions may significantly increase or decrease within the next 12 months , and the estimated range of any such variance is not currently estimable based upon facts and circumstances as of September 30, 2016 . Included below is a summary of the tax years, by jurisdiction, that remain subject to examination by taxing authorities at September 30, 2016 : Jurisdiction Fiscal Years Open U.S. federal 2013 – 2015 Various U.S. states 2013 – 2015 Canada federal 2009 – 2015 Various Canadian provinces 2009 – 2015

SEGMENT AND GEOGRAPHIC INFORMAT

SEGMENT AND GEOGRAPHIC INFORMATION	12 Months Ended
	Sep. 30, 2016
Segment Reporting [Abstract]
SEGMENT AND GEOGRAPHIC INFORMATION	SEGMENT AND GEOGRAPHIC 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); 3) drilling wells and installing and repairing water pumping systems in Hawaii (contract drilling); and 4) developing homes for sale in Hawaii (residential real estate). 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. Year ended September 30, 2016 2015 Revenues: Oil and natural gas $ 3,177,000 $ 9,008,000 Land investment 1,915,000 3,244,000 Contract drilling 2,233,000 4,886,000 Residential real estate 5,700,000 — Other 216,000 341,000 Total before interest income 13,241,000 17,479,000 Interest income 46,000 54,000 Total revenues $ 13,287,000 $ 17,533,000 Depletion, depreciation, and amortization: Oil and natural gas $ 1,236,000 $ 2,987,000 Contract drilling 251,000 272,000 Other 120,000 105,000 Total depletion, depreciation, and amortization $ 1,607,000 $ 3,364,000 Impairment: Oil and natural gas $ 1,154,000 $ — Residential real estate — 316,000 Total impairment $ 1,154,000 $ 316,000 Operating profit (loss) (before general and administrative expenses): Oil and natural gas $ (2,355,000 ) $ (366,000 ) Land investment 1,915,000 3,244,000 Contract drilling (116,000 ) 922,000 Residential real estate 190,000 (316,000 ) Other 96,000 236,000 Gain on sales of assets 472,000 6,489,000 Total operating profit 202,000 10,209,000 Equity in income of affiliates: Land investment 2,624,000 1,580,000 General and administrative expenses (6,361,000 ) (8,551,000 ) Interest expense (97,000 ) (315,000 ) Interest income 46,000 54,000 (Loss) earnings before income taxes $ (3,586,000 ) $ 2,977,000 Capital Expenditures: Year ended September 30, 2016 2015 Oil and natural gas $ 1,872,000 $ 3,512,000 Contract drilling 66,000 124,000 Other 2,000 79,000 Total $ 1,940,000 $ 3,715,000 Assets By Segment: September 30, 2016 2015 Oil and natural gas (1) $ 6,323,000 $ 7,298,000 Land investment (2) 4,744,000 7,480,000 Contract drilling (2) 1,438,000 2,338,000 Residential real estate (2) — 5,132,000 Other: Cash and cash equivalents 15,550,000 8,471,000 Restricted cash 381,000 7,577,000 Corporate and other 3,132,000 3,257,000 Total $ 31,568,000 $ 41,553,000 ______________ (1) Primarily located in the province of Alberta, Canada. (2) Located in Hawaii. Long-Lived Assets By Geographic Area: September 30, 2016 2015 United States $ 5,187,000 $ 10,135,000 Canada 5,267,000 5,740,000 Total $ 10,454,000 $ 15,875,000 Revenue By Geographic Area: Year ended September 30, 2016 2015 United States $ 9,886,000 $ 8,237,000 Canada 3,355,000 9,242,000 Total (excluding interest income) $ 13,241,000 $ 17,479,000

ACCUMULATED OTHER COMPREHENSIVE

ACCUMULATED OTHER COMPREHENSIVE (LOSS) INCOME	12 Months Ended
	Sep. 30, 2016
Equity [Abstract]
ACCUMULATED OTHER COMPREHENSIVE (LOSS) INCOME	ACCUMULATED OTHER COMPREHENSIVE (LOSS) INCOME Components of accumulated other comprehensive (loss) income, net of taxes, are as follows: Year ended September 30, 2016 2015 Foreign currency translation: Beginning accumulated foreign currency translation $ 819,000 $ 1,692,000 Change in cumulative translation adjustment before reclassifications 87,000 (1,625,000 ) Amounts reclassified from accumulated other comprehensive income — 752,000 Income taxes — — Net current period other comprehensive income (loss) 87,000 (873,000 ) Ending accumulated foreign currency translation 906,000 819,000 Retirement plans: Beginning accumulated retirement plans benefit cost (2,941,000 ) (1,950,000 ) Amortization of net actuarial loss and prior service cost 168,000 105,000 Net actuarial loss arising during the period (2,053,000 ) (1,096,000 ) Income taxes — — Net current period other comprehensive loss (1,885,000 ) (991,000 ) Ending accumulated retirement plans benefit cost (4,826,000 ) (2,941,000 ) Accumulated other comprehensive loss, net of taxes $ (3,920,000 ) $ (2,122,000 ) The realized foreign currency transaction loss in fiscal 2015 related to the repayment of debt was reclassified from accumulated other comprehensive income to “General and administrative” expenses on the accompanying Consolidated Statement of Operations. 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 Consolidated Statements of Operations (see Note 13 for additional details).

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	12 Months Ended
	Sep. 30, 2016
Fair Value Disclosures [Abstract]
FAIR VALUE MEASUREMENTS	FAIR VALUE MEASUREMENTS The carrying values of cash and cash equivalents, 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. The carrying value of debt approximates fair value as the terms approximate current market terms for similar debt instruments of comparable risk and maturities. A $316,000 impairment of the value of the real estate held for sale was recognized in the year ended September 30, 2015. In determining the fair value of Barnwell’s real estate held for sale at September 30, 2015, prices for comparable sales transactions were used by an independent real estate consulting and appraisal firm to estimate fair value, which has been classified as a Level 2 valuation. The estimated fair values of oil and natural gas properties and the asset retirement obligation assumed in the acquisitions of additional oil and natural gas working interests are based on an estimated discounted cash flow model and market assumptions. The significant Level 3 assumptions used in the calculation of estimated discounted cash flows included future commodity prices, projections of estimated quantities of oil and natural gas reserves, expectations for timing and amount of future development, operating and asset retirement costs, projections of future rates of production, expected recovery rates and risk adjusted discount rates. See Note 10 for additional information regarding oil and natural gas property acquisitions. Barnwell estimates the fair value of asset retirement obligations based on the projected discounted future cash outflows required to settle abandonment and restoration liabilities. Such an estimate requires assumptions and judgments regarding the existence of liabilities, the amount and timing of cash outflows required to settle the liability, what constitutes adequate restoration, inflation factors, credit adjusted discount rates, and consideration of changes in legal, regulatory, environmental and political environments. Abandonment and restoration cost estimates are determined in conjunction with Barnwell’s reserve engineers based on historical information regarding costs incurred to abandon and restore similar well sites, information regarding current market conditions and costs, and knowledge of subject well sites and properties. Asset retirement obligation fair value measurements in the current period were Level 3 fair value measurements. As further described in Note 11, the Company recognizes the fair value of a liability for an asset retirement obligation in the period in which it is incurred if a reasonable estimate of fair value can be made. Asset retirement obligations are not measured at fair value subsequent to initial recognition.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Sep. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES Lease Commitments Barnwell has several non-cancelable operating leases for office space, contract drilling base yard space and leasehold land. Rental expense was $404,000 and $408,000 for the years ended September 30, 2016 and 2015 , respectively. Barnwell is committed under these leases for minimum rental payments summarized by fiscal year as follows: Fiscal year ending 2017 $ 261,000 2018 138,000 2019 118,000 2020 118,000 2021 118,000 Thereafter through 2026 130,000 Total $ 883,000 The lease payments for leasehold land were subject to renegotiation as of January 1, 2006. Per the lease agreement, the lease payments will remain unchanged pending an appraisal, whereupon the lease rent could be adjusted to fair market value. Barnwell does not know the amount of the new lease payments which could be effective upon performance of the appraisal; they may remain unchanged or increase, and Barnwell currently expects the adjustment, if any, to not be material. The future rental payment disclosures above assume the minimum lease payments for leasehold land in effect at December 31, 2005 remain unchanged through December 2025, the end of the lease term. The lease agreement for the contract drilling base yard space has stated minimum lease payments with scheduled rent increases through June 30, 2017, after which the lease payments are adjusted to fair market rent at set redetermination dates through the date of the lease termination on June 30, 2047. Environmental Matters In January 2015, there was an oil and saltwater release from one of our operated oil pipelines in Alberta, Canada. The gross environmental remediation costs were approximately $2,200,000 . Barnwell’s working interest in the well is 58% , and we have recovered all of the monies from the other working interest owners for their share of the costs. We have collected insurance proceeds, less an $80,000 deductible, for our share of the costs. There was no remaining liability at September 30, 2016. In February 2016, a gas migration was detected at one of our previously abandoned non-operated wells in Alberta, Canada. We have estimated that probable environmental remediation costs will be within the range of $400,000 to $800,000 . Barnwell’s working interest in the well is 50% , and accordingly we accrued approximately $200,000 at September 30, 2016, which has not been discounted and was accrued in "Accrued operating and other expenses" on the Consolidated Balance Sheet, however as non-operator we have no control over the actual cost or timing of the eventual remediation. Because of the inherent uncertainties associated with environmental assessment and remediation activities, future expenses to remediate the currently identified sites, and sites identified in the future, if any, could be incurred. Guarantee See Note 9 for a discussion of Barnwell’s guarantee of the Kukio Resort land development partnership’s performance bonds. Legal and Regulatory Matters Barnwell is routinely involved in disputes with third parties that occasionally require litigation. In addition, Barnwell is required to maintain compliance with all current governmental controls and regulations in the ordinary course of business. Barnwell’s management is not aware of any claims or litigation involving Barnwell that are likely to have a material adverse effect on its results of operations, financial position or liquidity. Other Matters Barnwell is obligated to pay Nearco, Inc. 10.4% of Kaupulehu Developments’ gross receipts from real estate transactions. The fees represent compensation for promotion and marketing of Kaupulehu Developments’ property and were determined based on the estimated fair value of such services. In conjunction with the closing of the Increment II transaction in fiscal 2006, Kaupulehu Developments entered into an agreement to pay its external real estate legal counsel 1.5% of all Increment II percentage of sales payments received by Kaupulehu Developments for services provided by its external real estate legal counsel in the negotiation and closing of the Increment II transaction.

INFORMATION RELATING TO THE CON

INFORMATION RELATING TO THE CONSOLIDATED STATEMENTS OF CASH FLOWS	12 Months Ended
	Sep. 30, 2016
Supplemental Cash Flow Elements [Abstract]
INFORMATION RELATING TO THE CONSOLIDATED STATEMENTS OF CASH FLOWS	INFORMATION RELATING TO THE CONSOLIDATED STATEMENTS OF CASH FLOWS The following table details the effect of changes in current assets and liabilities on the Consolidated Statements of Cash Flows, and presents supplemental cash flow information: Year ended September 30, 2016 2015 Increase (decrease) from changes in: Receivables $ 1,081,000 $ 324,000 Other current assets 49,000 (447,000 ) Accounts payable (1,456,000 ) (439,000 ) Accrued compensation (79,000 ) (323,000 ) Other current liabilities (882,000 ) (687,000 ) Decrease from changes in current assets and liabilities $ (1,287,000 ) $ (1,572,000 ) Supplemental disclosure of cash flow information: Cash paid during the year for: Interest $ 94,000 $ 306,000 Income taxes (refunded) paid, net $ (219,000 ) $ 1,812,000 Capital expenditure accruals related to oil and natural gas acquisition and development increased $76,000 and decreased $61,000 during the years ended September 30, 2016 and 2015 , respectively. Additionally, during the years ended September 30, 2016 and 2015 , capital expenditure accruals related to oil and natural gas asset retirement obligations increased $99,000 and $1,234,000 , respectively.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Sep. 30, 2016
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	RELATED PARTY TRANSACTIONS Kaupulehu Developments is entitled to receive a percentage of the gross receipts from the sales of lots in Increment I from KD I and the sales of lots and/or residential units in Increment II from KD II. KD I and KD II are part of the Kukio Resort land development partnerships in which Barnwell holds an indirect 19.6% non-controlling ownership interest accounted for under the equity method of investment. The percentage payments are part of transactions which took place in 2004 and 2006 where Kaupulehu Developments sold its leasehold interests in Increment I and Increment II to KD I's and KD II's predecessors in interest, respectively, which was prior to Barnwell’s affiliation with KD I and KD II which commenced on November 27, 2013, the acquisition date of our ownership interest in the Kukio Resort land development partnerships. During the year ended September 30, 2016 , Barnwell received $2,255,000 in percentage of sales payments from KD I and KD II from the sale of three lots within Phase II of Increment I and the sale of one lot within Increment II. During the year ended September 30, 2015 , Barnwell received $3,772,000 in percentage of sales payments from KD I from the sale of six contiguous lots within Phase I of Increment I to a single buyer and 11 lots within Phase II of Increment I.

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Sep. 30, 2016
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS There were no material subsequent events that would require recognition or disclosure in the accompanying consolidated financial statements.

SUMMARY OF SELECTED QUARTERLY F

SUMMARY OF SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED)	12 Months Ended
	Sep. 30, 2016
Quarterly Financial Information Disclosure [Abstract]
SUMMARY OF SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED)	SUMMARY OF SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED) Disclosure is not required as Barnwell qualifies as a smaller reporting company.

SUPPLEMENTARY OIL AND NATURAL G

SUPPLEMENTARY OIL AND NATURAL GAS INFORMATION (UNAUDITED)	12 Months Ended
	Sep. 30, 2016
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
SUPPLEMENTARY OIL AND NATURAL GAS INFORMATION (UNAUDITED)	SUPPLEMENTARY OIL AND NATURAL GAS INFORMATION (UNAUDITED) The following tables summarize information relative to Barnwell’s oil and natural gas operations, which are conducted in Canada. Proved reserves are the estimated quantities of oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. Proved producing oil and natural gas reserves are reserves that can be expected to be recovered through existing wells with existing equipment and operating methods. The estimated net interests in total proved and proved producing reserves are based upon subjective engineering judgments and may be affected by the limitations inherent in such estimations. The process of estimating reserves is subject to continual revision as additional information becomes available as a result of drilling, testing, reservoir studies and production history. There can be no assurance that such estimates will not be materially revised in subsequent periods. (A) Oil and Natural Gas Reserves The following table summarizes changes in the estimates of Barnwell’s net interests in total proved developed reserves of oil and natural gas liquids and natural gas, which are all in Canada. The Company has no proved undeveloped reserves. All of the information regarding reserves in this Form 10-K is derived from the report of our independent petroleum reserve engineers, InSite, and is included as an Exhibit to this Form 10-K. OIL & NGL GAS Total Proved reserves: Balance at September 30, 2014 724,000 9,465,000 2,356,000 Revisions of previous estimates 79,000 (520,000 ) (11,000 ) Extensions, discoveries and other additions — 3,000 1,000 Acquisitions of reserves 46,000 543,000 140,000 Less sales of reserves (237,000 ) (4,679,000 ) (1,044,000 ) Less production (143,000 ) (1,688,000 ) (434,000 ) Balance at September 30, 2015 469,000 3,124,000 1,008,000 Revisions of previous estimates (23,000 ) (1,320,000 ) (251,000 ) Extensions, discoveries and other additions 54,000 95,000 70,000 Acquisitions of reserves 34,000 18,000 37,000 Less production (84,000 ) (476,000 ) (166,000 ) Balance at September 30, 2016 450,000 1,441,000 698,000 (B) Capitalized Costs Relating to Oil and Natural Gas Producing Activities All capitalized costs relating to oil and natural gas producing activities, which were being depleted in all years, are summarized as follows: September 30, 2016 2015 Proved properties $ 66,044,000 $ 62,960,000 Unproved properties 221,000 145,000 Total capitalized costs 66,265,000 63,105,000 Accumulated depletion and depreciation 61,060,000 57,460,000 Net capitalized costs $ 5,205,000 $ 5,645,000 (C) Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development Year ended September 30, 2016 2015 Acquisition of properties: Unproved $ 161,000 $ 28,000 Proved 608,000 804,000 Exploration costs — — Development costs 1,103,000 2,680,000 Total $ 1,872,000 $ 3,512,000 Development costs incurred in the table above include additions and revisions to Barnwell’s asset retirement obligation of $99,000 and $1,234,000 for the years ended September 30, 2016 and 2015 , respectively. (D) Results of Operations for Oil and Natural Gas Producing Activities Year ended September 30, 2016 2015 Net revenues $ 3,177,000 $ 9,008,000 Production costs (3,142,000 ) (6,387,000 ) Depletion (1,236,000 ) (2,987,000 ) Impairment of assets (1,154,000 ) — Pre-tax results of operations (1) (2,355,000 ) (366,000 ) Estimated income tax benefit (expense) (2) 297,000 (921,000 ) Results of operations (1) $ (2,058,000 ) $ (1,287,000 ) _________________ (1) Before gain on sale of oil and natural gas properties, general and administrative expenses, interest expense, and foreign exchange gains and losses. (2) Estimated income tax benefit (expense) includes charges to deferred income taxes for the valuation allowance necessary for the portion of Canadian tax law deferred tax assets that may not be realizable. (E) Standardized Measure, Including Year-to-Year Changes Therein, of Estimated Discounted Future Net Cash Flows The following tables utilize reserve and production data estimated by independent petroleum reserve engineers. The information may be useful for certain comparison purposes but should not be solely relied upon in evaluating Barnwell or its performance. Moreover, the projections should not be construed as realistic estimates of future cash flows, nor should the standardized measure be viewed as representing current value. The estimated future cash flows at September 30, 2016 and 2015 were based on average sales prices in effect on the first day of the month for the preceding twelve month period in accordance with SEC Release No. 33-8995. The future production and development costs represent the estimated future expenditures that we will incur to develop and produce the proved reserves, assuming continuation of existing economic conditions. The future income tax expenses were computed by applying statutory income tax rates in existence at September 30, 2016 and 2015 to the future pre-tax net cash flows relating to proved reserves, net of the tax basis of the properties involved. Material revisions to reserve estimates may occur in the future, development and production of the oil and natural gas reserves may not occur in the periods assumed and actual prices realized and actual costs incurred are expected to vary significantly from those used. Management does not rely upon this information in making investment and operating decisions; rather, those decisions are based upon a wide range of factors, including estimates of probable reserves as well as proved reserves and price and cost assumptions different than those reflected herein. Standardized Measure of Discounted Future Net Cash Flows September 30, 2016 2015 Future cash inflows $ 17,259,000 $ 27,749,000 Future production costs (11,951,000 ) (18,468,000 ) Future development costs (426,000 ) (935,000 ) Future income tax expenses (1,016,000 ) (2,361,000 ) Future net cash flows 3,866,000 5,985,000 10% annual discount for timing of cash flows (956,000 ) (1,950,000 ) Standardized measure of discounted future net cash flows $ 2,910,000 $ 4,035,000 Changes in the Standardized Measure of Discounted Future Net Cash Flows Year ended September 30, 2016 2015 Beginning of year $ 4,035,000 $ 24,147,000 Sales of oil and natural gas produced, net of production costs (35,000 ) (2,621,000 ) Net changes in prices and production costs, net of royalties and wellhead taxes (4,134,000 ) (8,042,000 ) Extensions and discoveries 1,285,000 1,000 Net change due to purchases and sales of minerals in place 470,000 (9,103,000 ) Revisions of previous quantity estimates (343,000 ) 634,000 Net change in income taxes 98,000 1,658,000 Accretion of discount 412,000 2,021,000 Other - changes in the timing of future production and other 1,018,000 (1,009,000 ) Other - net change in Canadian dollar translation rate 104,000 (3,651,000 ) Net change (1,125,000 ) (20,112,000 ) End of year $ 2,910,000 $ 4,035,000

SUMMARY OF SIGNIFICANT ACCOUN33

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Sep. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidation	Principles of Consolidation The 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 80% -owned joint ventures (Kaupulehu 2007, LLLP and Kaupulehu Investors, LLC). 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 VIEs in which the Company is not deemed to be the primary beneficiary are accounted for by the equity method.
Use of Estimates in the Preparation of Financial Statements	Use of Estimates in the Preparation of Financial Statements The preparation of the financial statements in conformity with U.S. GAAP requires management of Barnwell to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. Actual results could differ significantly from those estimates. Significant assumptions are required in the valuation of deferred tax assets, asset retirement obligations, share-based payment arrangements, obligations for retirement plans, contract drilling estimated costs to complete, proved oil and natural gas reserves, and the carrying value of other assets, and such assumptions may impact the amount at which such items are recorded.
Cash and Cash Equivalents	Cash and Cash Equivalents Cash and cash equivalents include cash on hand, demand deposits and short-term investments with original maturities of three months or less.
Restricted Cash	Restricted Cash Restricted cash at September 30, 2016 consists of a $500,000 Canadian dollar, or U.S. $381,000 at the September 30, 2016 exchange rate, guaranteed investment certificate pledged to the Royal Bank of Canada as required by our revolving demand facility. Restricted cash in the prior year consisted of a portion of the proceeds from the sale of Dunvegan held in an escrow account for the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes as well as deposits in an interest reserve account and a cost reserve account for our real estate loan. These amounts were released from restriction in fiscal 2016.
Concentration of Credit Risk	Concentration of Credit Risk We maintain bank account balances with high quality financial institutions which often exceed insured limits. We have not experienced any losses with these accounts and believe that we are not exposed to any significant credit risk on cash.
Accounts and Other Receivables	Accounts and Other Receivables Accounts receivable are recorded at the invoiced amount and do not bear interest. The allowance for doubtful accounts is Barnwell’s best estimate of the amount of probable credit losses in Barnwell’s existing accounts receivable and is based on historical write-off experience and the application of the specific identification method. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote. Barnwell does not have any off-balance sheet credit exposure related to its customers.
Asset and Investment Held for Sale	Asset and Investment Held for Sale Asset and investment held for sale are reported at the lower of the asset carrying value or fair value less costs to sell. The recorded balances are evaluated for impairment whenever events or changes in circumstances indicate that the balance may not be fully recoverable. This evaluation requires management to make assumptions and apply considerable judgments to, among others, estimates of the timing and amount of future cash flows, uncertainty about future events, including changes in economic conditions, changes in operating performance, and ongoing cost of maintenance and improvements of the assets. Changes in these and other assumptions may require impairment charges that may materially impact the Company’s future operating results. Assets are classified as held for sale if management commits to a plan to sell the property, the Company actively markets the property in its current condition for a price that is reasonable in comparison to its fair value and management considers the sale of such property within one year of the balance sheet date to be probable.
Investments in Real Estate	Investments in Real Estate Barnwell accounts for sales of Increment I and Increment II leasehold land interests under the full accrual method. Gains from such sales were recognized when the buyer’s investments were adequate to demonstrate a commitment to pay for the property, risks and rewards of ownership transferred to the buyer, and Barnwell did not have a substantial continuing involvement with the property sold. With regard to the sales of Increment I and Increment II leasehold land interests, the percentage of sales payments are contingent future profits which will be recognized when they are realized. All costs of the sales of Increment I and Increment II leasehold land interests were recognized at the time of sale and were not deferred to future periods when any contingent profits will be recognized.
Equity Method Investments	Equity Method Investments Affiliated companies, which are limited partnerships or similar entities, in which Barnwell holds more than a 3% to 5% ownership interest, are accounted for as equity method investments. Equity method investment adjustments include Barnwell’s proportionate share of investee income or loss, adjustments to recognize certain differences between Barnwell’s carrying value and Barnwell’s equity in net assets of the investee at the date of investment, impairments and other adjustments required by the equity method. Gains or losses are realized when such investments are sold. Investments in equity method investees are evaluated for impairment as events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. If the carrying amounts of the assets exceed their respective fair values, additional impairment tests are performed to measure the amounts of the impairment losses, if any. When an impairment test demonstrates that the fair value of an investment is less than its carrying value, management will determine whether the impairment is either temporary or other-than-temporary. Examples of factors which may be indicative of an other-than-temporary impairment include (a) the length of time and extent to which fair value has been less than carrying value, (b) the financial condition and near-term prospects of the investee, and (c) the intent and ability to retain the investment in the investee for a period of time sufficient to allow for any anticipated recovery in fair value. If the decline in fair value is determined by management to be other-than-temporary, the carrying value of the investment is written down to its estimated fair value as of the balance sheet date of the reporting period in which the assessment is made.
Variable Interest Entities	Variable Interest Entities The consolidation of VIEs is required when an enterprise has a controlling financial interest and is therefore the VIE’s primary beneficiary. A controlling financial interest will have both of the following characteristics: (a) the power to direct the activities of a VIE that most significantly impact the VIE’s economic performance and (b) the obligation to absorb losses of the VIE that could potentially be significant to the VIE or the right to receive benefits from the VIE that could potentially be significant to the VIE. The determination of whether an entity is a VIE and, if so, whether the Company is primary beneficiary, may require significant judgment. Barnwell analyzes its unconsolidated affiliates in which it has an investment to determine whether the unconsolidated entities are VIEs and, if so, whether the Company is the primary beneficiary. This analysis includes a qualitative review based on an evaluation of the design of the entity, its organizational structure, including decision making ability and financial agreements, as well as a quantitative review. Our unconsolidated affiliates that have been determined to be VIEs are accounted under the equity method because we do not have a controlling financial interest and are therefore not the VIE’s primary beneficiary (see Note 9).
Oil and Natural Gas Properties	Oil and Natural Gas Properties Barnwell uses the full cost method of accounting under which all costs incurred in the acquisition, exploration and development of oil and natural gas reserves, including costs related to unsuccessful wells and estimated future site restoration and abandonment, are capitalized. We capitalize internal costs that can be directly identified with our acquisition, exploration and development activities and do not include any costs related to production, general corporate overhead or similar activities. Under the full cost method of accounting, we review the carrying value of our oil and natural gas properties, on a country-by-country basis, each quarter in what is commonly referred to as the ceiling test. Under the ceiling test, capitalized costs, net of accumulated depletion and oil and natural gas related deferred income taxes, may not exceed an amount equal to the sum of 1) the discounted present value (at 10% ), using average first-day-of-the-month prices during the 12-month period ending as of the balance sheet date held constant over the life of the reserves, of Barnwell’s estimated future net cash flows from estimated production of proved oil and natural gas reserves as determined by independent petroleum reserve engineers, less estimated future expenditures to be incurred in developing and producing the proved reserves but excluding future cash outflows associated with settling asset retirement obligations; plus 2) the cost of major development projects and unproven properties not subject to depletion, if any; plus 3) the lower of cost or estimated fair value of unproven properties included in costs subject to depletion; less 4) related income tax effects. If net capitalized costs exceed this limit, the excess is expensed. Depletion is computed using the units-of-production method whereby capitalized costs, net of estimated salvage values, plus estimated future costs to develop proved reserves and satisfy asset retirement obligations, are amortized over the total estimated proved reserves on a country-by-country basis. Investments in major development projects are not depleted until either proved reserves are associated with the projects or impairment has been determined. Proceeds from the disposition of oil and natural gas properties 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 in a particular country. Revenues associated with the sale of oil, natural gas and natural gas liquids are recognized in the Consolidated Statements of Operations when the oil, natural gas and natural gas liquids are delivered and title has passed to the customer. Barnwell’s sales reflect its working interest share after royalties. Barnwell’s production is generally delivered and sold at the plant gate. Barnwell does not have transportation volume commitments with pipelines and does not have natural gas imbalances related to natural gas balancing arrangements with its partners.
Acquisitions	Acquisitions Acquisitions of businesses are accounted for using the acquisition method of accounting. Purchase prices are allocated to acquired assets and assumed liabilities based on their estimated fair value at the time of the acquisition. A business combination may result in the recognition of a gain or goodwill based on the fair value of the assets acquired and liabilities assumed at the acquisition date as compared to the fair value of consideration transferred.
Long-lived Assets	Long-lived Assets Long-lived assets to be held and used, other than oil and natural gas properties, are evaluated for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be fully recoverable. Recoverability is measured by comparing the carrying amount of the asset to the future net cash flows expected to result from use of the asset (undiscounted and without interest charges). If it is determined that the asset may not be recoverable, impairment loss is measured as the amount by which the carrying amount of the asset exceeds the fair value of the asset. Long-lived assets to be disposed of are reported at the lower of the asset carrying value or fair value, less cost to sell. Water well drilling rigs, office and other property and equipment are depreciated using the straight-line method based on estimated useful lives.
Share-based Compensation	Share-based Compensation Share-based compensation cost is measured at fair value. Barnwell utilizes a closed-form valuation model to determine the fair value of each option award. Expected volatilities are based on the historical volatility of Barnwell’s stock over a period consistent with that of the expected terms of the options. The expected terms of the options represent expectations of future employee exercise and are estimated based on factors such as vesting periods, contractual expiration dates, historical trends in Barnwell’s stock price, and historical exercise behavior. The risk-free rates for periods within the contractual life of the options are based on the yields of U.S. Treasury instruments with terms comparable to the estimated option terms. Expected dividends are based on current and historical dividend payments.
Retirement Plans	Retirement Plans Barnwell accounts for its defined benefit pension plan, Supplemental Employee Retirement Plan, and postretirement medical insurance benefits plan by recognizing the over-funded or under-funded status as an asset or liability in its Consolidated Balance Sheets and recognizes changes in that funded status in the year in which the changes occur through comprehensive income. See further discussion at Note 13. The estimation of Barnwell’s retirement plan obligations, costs and liabilities requires management to estimate the amount and timing of cash outflows for projected future payments and cash inflows for maturities and expected returns on plan assets. These assumptions may have an effect on the amount and timing of future contributions. At the end of each year, Barnwell determines the discount rate to be used to calculate the present value of plan liabilities and the net periodic benefit cost. The discount rate is an estimate of the current interest rate at which the retirement plan liabilities could be effectively settled at the end of the year. In estimating this rate, Barnwell references the Citigroup Pension Liability Index at our balance sheet date which is linked to rates of return on high-quality, fixed-income investments. The discount rate used to value the future benefit obligation as of each year-end is the rate used to determine the periodic benefit cost in the following year. The expected long-term return on assets assumption for the pension plans represents the average rate of return to be earned on plan assets over the period the benefits included in the benefit obligation are to be paid. The actual fair value of plan assets and estimated rate of return is used to determine the expected investment return during the year. The estimated rate of return on plan assets is based on historical trends combined with long-term expectations, the mix of plan assets and long-term inflation assumptions. A decrease (increase) of 50 basis points in the expected return on assets assumption would increase (decrease) pension expense by approximately $43,000 based on the assets of the plan at September 30, 2016 . The effects of changing assumptions are included in unamortized net gains and losses, which directly affect accumulated other comprehensive income. These unamortized gains and losses in excess of certain thresholds are amortized and reclassified to income (loss) over the average remaining service life of active employees.
Asset Retirement Obligation	Asset Retirement Obligation Barnwell accounts for asset retirement obligations by recognizing the fair value of a liability for an asset retirement obligation in the period in which it is incurred if a reasonable estimate of fair value can be made. Barnwell estimates the fair value of asset retirement obligations based on the projected discounted future cash outflows required to settle abandonment and restoration liabilities. Such an estimate requires assumptions and judgments regarding the existence of liabilities, the amount and timing of cash outflows required to settle the liability, what constitutes adequate restoration, inflation factors, credit adjusted discount rates, and consideration of changes in legal, regulatory, environmental and political environments. Abandonment and restoration cost estimates are determined in conjunction with Barnwell’s reserve engineers based on historical information regarding costs incurred to abandon and restore similar well sites, information regarding current market conditions and costs, and knowledge of subject well sites and properties. These assumptions represent Level 3 inputs. Barnwell’s estimated site restoration and abandonment costs of its oil and natural gas properties are capitalized as part of the carrying amount of oil and natural gas properties and depleted over the life of the related reserves. When the assumptions used to estimate a recorded asset retirement obligation change, a revision is recorded to both the asset retirement obligation and the capitalized cost of asset retirements. The liability is accreted at the end of each period through charges to oil and natural gas operating expense.
Income Taxes	Income Taxes Income taxes are determined using the asset and liability method. Deferred tax assets and liabilities are recognized for the estimated future tax impacts of differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates in effect for the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. A valuation allowance is provided when it is more likely than not that some portion or all of the deferred tax asset will not be realized. Management evaluates its potential exposures from tax positions taken that have been or could be challenged by taxing authorities. These potential exposures result because taxing authorities may take positions that differ from those taken by management in the interpretation and application of statutes, regulations and rules. Management considers the possibility of alternative outcomes based upon past experience, previous actions by taxing authorities (e.g., actions taken in other jurisdictions) and advice from tax experts. Recognized tax positions are initially and subsequently measured as the largest amount of tax benefit that is more likely than not of being realized upon ultimate settlement with a taxing authority on a jurisdiction-by-jurisdiction basis. Liabilities for unrecognized tax benefits related to such tax positions are included in long-term liabilities unless the tax position is expected to be settled within the upcoming year, in which case the liabilities are included in current liabilities. Interest and penalties related to uncertain tax positions are included in income tax expense.
Contract Drilling	Contract Drilling Revenues, costs and profits applicable to contract drilling contracts are included in the Consolidated Statements of Operations using the percentage of completion method, principally measured by the percentage of labor dollars incurred to date for each contract to total estimated labor dollars for each contract. Contract losses are recognized in full in the period the losses are identified. The performance of drilling contracts may extend over more than a year and, in the interim periods, estimates of total contract costs and profits are used to determine revenues and profits earned for reporting the results of contract drilling operations. Revisions in the estimates required by subsequent performance and final contract settlements are included as adjustments to the results of operations in the period such revisions and settlements occur. Contracts are normally less than a year in duration.
Environmental	Environmental Barnwell is subject to extensive environmental laws and regulations. These laws, which are constantly changing, regulate the discharge of materials into the environment and maintenance of surface conditions and may require Barnwell to remove or mitigate the environmental effects of the disposal or release of petroleum or chemical substances at various sites. Environmental expenditures are expensed or capitalized depending on their future economic benefit. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefit are expensed. Liabilities for expenditures of a noncapital nature are recorded when environmental assessment and/or remediation is probable, and the costs can be reasonably estimated. Barnwell recognizes an insurance receivable related to environmental expenditures when collection of the receivable is deemed probable. Any recognition of an insurance receivable is recorded by crediting and offsetting the original charge. Any differential arising between insurance recoveries and insurance receivables is expensed or capitalized, consistent with the original treatment.
Foreign Currency Translation	Foreign Currency Translation Assets and liabilities of foreign subsidiaries are translated at the year-end exchange rate. Operating results of foreign subsidiaries are translated at average exchange rates during the period. Translation adjustments have no effect on net income and are included in “Accumulated other comprehensive loss, net” in stockholders’ equity.
Fair Value Measurements	Fair Value Measurements Fair value is defined as the amount that would be received from the sale of an asset or paid for the transfer of a liability in an orderly transaction between market participants at the measurement date. Fair value measurements are classified and disclosed in one of the following categories: • Level 1: Unadjusted quoted prices in active markets for identical assets and liabilities in active markets and have the highest priority. • Level 2: Inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. • Level 3: Unobservable inputs for the financial asset or liability and have the lowest priority.
Recent Accounting Pronouncements	Recent Accounting Pronouncements In April 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-08, “Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity.” This ASU relates to discontinued operations reporting for disposals of components of an entity that represent strategic shifts that have, or will have, a major effect on an entity’s operations and financial results. The standard expands the disclosures for discontinued operations and requires new disclosures related to individually material disposals that do not meet the definition of a discontinued operation. The Company adopted the provisions of this ASU effective October 1, 2015. The adoption of this update did not have a material impact on Barnwell’s consolidated financial statements. In November 2015, the FASB issued ASU 2015-17, “Balance Sheet Classification of Deferred Taxes,” which eliminates the requirement to present deferred tax assets and liabilities as current and noncurrent in a classified balance sheet. Instead, entities will be required to classify all deferred tax assets and liabilities, along with any related valuation allowance, as noncurrent. The Company prospectively adopted the provisions of this ASU effective July 1, 2016. The adoption of this ASU resulted in a reclassification of current deferred tax assets from the current assets section of the balance sheet to "Deferred income taxes" in the long-term liabilities sections of the balance sheet.

EARNINGS (LOSS) PER COMMON SH34

EARNINGS (LOSS) PER COMMON SHARE (Tables)	12 Months Ended
	Sep. 30, 2016
Earnings Per Share [Abstract]
Reconciliations between net earnings (loss) attributable to stockholders and common shares outstanding of the basic and diluted net earnings (loss) per share computations	Reconciliations between net earnings (loss) attributable to Barnwell stockholders and common shares outstanding of the basic and diluted net earnings (loss) per share computations are detailed in the following tables: Year ended September 30, 2016 Net Loss Shares Per-Share (Numerator) (Denominator) Amount Basic net loss per share $ (3,615,000 ) 8,277,160 $ (0.44 ) Effect of dilutive securities - common stock options — — Diluted net loss per share $ (3,615,000 ) 8,277,160 $ (0.44 ) Year ended September 30, 2015 Net Earnings Shares Per-Share (Numerator) (Denominator) Amount Basic net earnings per share $ 1,263,000 8,277,160 $ 0.15 Effect of dilutive securities - common stock options — — Diluted net earnings per share $ 1,263,000 8,277,160 $ 0.15

SHARE-BASED PAYMENTS (Tables)

SHARE-BASED PAYMENTS (Tables)	12 Months Ended
	Sep. 30, 2016
Share-based payments
Schedule of share-based compensation (benefit) expense	The Company’s share-based compensation benefit and related income tax effects are as follows: Year ended September 30, 2016 2015 Share-based benefit $ (22,000 ) $ (140,000 ) Income tax effect $ — $ —
Equity-classified share options
Share-based payments
Summary of the activity in share options	A summary of the activity in Barnwell’s equity-classified share options from October 1, 2015 through September 30, 2016 is presented below: Options Shares Weighted- Weighted- Aggregate Outstanding at October 1, 2015 30,000 $ 3.01 Granted — — Exercised — — Expired/Forfeited — — Outstanding at September 30, 2016 30,000 $ 3.01 7.2 $ — Exercisable at September 30, 2016 15,000 $ 3.01 7.2 $ —
Liability-classified share options
Share-based payments
Schedule of share-based compensation (benefit) expense	The following table summarizes the components of the total share-based compensation for liability-classified awards: Year ended September 30, 2016 2015 Due to vesting $ 4,000 $ 10,000 Due to remeasurement (36,000 ) (170,000 ) Total share-based compensation benefit for liability-based awards $ (32,000 ) $ (160,000 )
Summary of the activity in share options	A summary of the activity in Barnwell’s liability-classified share options from October 1, 2015 through September 30, 2016 is presented below: Options Shares Weighted- Weighted- Aggregate Outstanding at October 1, 2015 591,250 $ 7.98 Granted — — Exercised — — Expired/Forfeited — — Outstanding at September 30, 2016 591,250 $ 7.98 2.5 $ — Exercisable at September 30, 2016 576,250 $ 8.11 2.4 $ —
Schedule of assumptions used in estimating fair value	The following assumptions were used in estimating fair value for all liability-classified share options outstanding: Year ended September 30, 2016 2015 Expected volatility range 56.7% to 72.7% 51.5% to 61.6% Weighted-average volatility 63.6% 52.4% Expected dividends None None Expected term (in years) 1.2 to 7.2 2.2 to 8.2 Risk-free interest rate 0.6% to 1.4% 0.6% to 1.9% Expected forfeitures None None

ACCOUNTS RECEIVABLE AND CONTR36

ACCOUNTS RECEIVABLE AND CONTRACT COSTS (Tables)	12 Months Ended
	Sep. 30, 2016
Receivables [Abstract]
Schedule of costs and estimated earnings (loss) on uncompleted contracts	Costs and estimated earnings on uncompleted contracts are as follows: September 30, 2016 2015 Costs incurred on uncompleted contracts $ 966,000 $ 1,890,000 Estimated earnings 70,000 226,000 1,036,000 2,116,000 Less billings to date 1,112,000 2,503,000 $ (76,000 ) $ (387,000 )
Schedule of costs and estimated earnings (loss) on uncompleted contracts included in the Consolidated Balance Sheets	Costs and estimated earnings on uncompleted contracts are included in the Consolidated Balance Sheets as follows: September 30, 2016 2015 Costs and estimated earnings in excess of billings on uncompleted contracts (included in other current assets) $ 89,000 $ 182,000 Billings in excess of costs and estimated earnings on uncompleted contracts (included in other current liabilities) (165,000 ) (569,000 ) $ (76,000 ) $ (387,000 )

INVESTMENTS (Tables)

INVESTMENTS (Tables)	12 Months Ended
	Sep. 30, 2016
Investments, All Other Investments [Abstract]
Summary of investments	A summary of Barnwell’s non-current investments is as follows: September 30, 2016 2015 Investment in Kukio Resort land development partnerships $ 3,502,000 $ 6,238,000 Investment in leasehold land interest – Lot 4C 50,000 50,000 Total non-current investments $ 3,552,000 $ 6,288,000
Summarized financial information for the land development partnerships	Summarized financial information for the Kukio Resort land development partnerships is as follows: Year ended Year ended September 30, 2016 September 30, 2015 Revenue $ 33,874,000 $ 29,898,000 Gross profit $ 15,332,000 $ 13,594,000 Net earnings $ 12,212,000 $ 7,500,000
Summary of Increment I percentage of sales payment revenues received	The following table summarizes the Increment I and Increment II percentage of sales payment revenues received from KD I and KD II: Year ended September 30, 2016 2015 Sale of interest in leasehold land: Proceeds $ 2,255,000 $ 3,772,000 Fees (340,000 ) (528,000 ) Revenues – sale of interest in leasehold land, net $ 1,915,000 $ 3,244,000

OIL AND NATURAL GAS PROPERTIES

OIL AND NATURAL GAS PROPERTIES (Tables)	12 Months Ended
	Sep. 30, 2016
Extractive Industries [Abstract]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	The Progress acquisition was accounted for under the acquisition method of accounting, and as such, Barnwell estimated the fair value of the acquired property as of the August 27, 2015 acquisition date. The following table summarizes the allocation of the consideration paid to acquire the properties to the assets acquired and liabilities assumed in the transaction as of the acquisition date. See Note 17 for further information regarding the fair value measurement inputs. Property and equipment $ 397,000 Asset retirement obligation (91,000 ) Net identifiable assets acquired $ 306,000 The Wood River acquisition was accounted for under the acquisition method of accounting, and as such, Barnwell estimated the fair value of the acquired property as of the September 12, 2016 acquisition date. The following table summarizes the allocation of the consideration paid to acquire the properties to the assets acquired and liabilities assumed in the transaction as of the acquisition date. See Note 17 for further information regarding the fair value measurement inputs. Property and equipment $ 813,000 Asset retirement obligation (44,000 ) Net identifiable assets acquired $ 769,000 The Progress acquisition was accounted for under the acquisition method of accounting, and as such, Barnwell estimated the fair value of the acquired property as of the November 13, 2014 acquisition date. The following table summarizes the allocation of the consideration paid to acquire the properties to the assets acquired and liabilities assumed in the transaction as of the acquisition date. See Note 17 for further information regarding the fair value measurement inputs. Property and equipment $ 751,000 Asset retirement obligation (225,000 ) Net identifiable assets acquired $ 526,000
Pro forma information including adjustments to oil and natural gas segment revenues and operating expenses	The pro forma information includes adjustments to oil and natural gas segment revenues and operating expenses based on the actual results of operations related to Dunvegan, as well as adjustments for estimated depletion, accretion expense, general and administrative expenses, and income taxes based on an allocation of the estimated impact of Dunvegan on those amounts. Year ended September 30, 2015 Pro forma (unaudited) Historical Pro forma Total revenues $ 17,533,000 $ 13,235,000 Net earnings (loss) $ 1,769,000 $ (761,000 ) Net earnings (loss) attributable to Barnwell Industries, Inc. stockholders $ 1,263,000 $ (1,267,000 ) Net earnings (loss) per common share attributable to Barnwell Industries, Inc. stockholders. $ 0.15 $ (0.15 )

PROPERTY AND EQUIPMENT AND AS39

PROPERTY AND EQUIPMENT AND ASSET RETIREMENT OBLIGATION (Tables)	12 Months Ended
	Sep. 30, 2016
PROPERTY AND EQUIPMENT AND ASSET RETIREMENT OBLIGATION
Schedule of property and equipment	Barnwell’s property and equipment is detailed as follows: Estimated Gross Accumulated Net At September 30, 2016: Land $ 365,000 $ — $ 365,000 Oil and natural gas properties (full cost accounting) 66,265,000 (61,060,000 ) 5,205,000 Drilling rigs and equipment 3 – 10 years 6,379,000 (5,770,000 ) 609,000 Office 40 years 857,000 (274,000 ) 583,000 Other property and equipment 3 – 17 years 3,002,000 (2,862,000 ) 140,000 Total $ 76,868,000 $ (69,966,000 ) $ 6,902,000 Estimated Gross Accumulated Net At September 30, 2015: Land $ 863,000 $ — $ 863,000 Oil and natural gas properties (full cost accounting) 63,105,000 (57,460,000 ) 5,645,000 Drilling rigs and equipment 3 – 10 years 6,598,000 (5,825,000 ) 773,000 Offices 40 years 2,420,000 (445,000 ) 1,975,000 Other property and equipment 3 – 17 years 2,967,000 (2,755,000 ) 212,000 Total $ 75,953,000 $ (66,485,000 ) $ 9,468,000
Schedule of reconciliation of the asset retirement obligation	The following is a reconciliation of the asset retirement obligation: Year ended September 30, 2016 2015 Asset retirement obligation as of beginning of year $ 6,936,000 $ 9,163,000 Obligations incurred on new wells drilled or acquired 167,000 316,000 Liabilities associated with properties sold — (2,013,000 ) Revision of estimated obligation (68,000 ) 918,000 Accretion expense 464,000 632,000 Payments (459,000 ) (655,000 ) Foreign currency translation adjustment 154,000 (1,425,000 ) Asset retirement obligation as of end of year 7,194,000 6,936,000 Less current portion (1,017,000 ) (506,000 ) Asset retirement obligation, long-term $ 6,177,000 $ 6,430,000

RETIREMENT PLANS (Tables)

RETIREMENT PLANS (Tables)	12 Months Ended
	Sep. 30, 2016
Compensation and Retirement Disclosure [Abstract]
Schedule of changes in benefit obligations, fair values of plan assets and reconciliations of the funded status of the retirement plans	The following tables detail the changes in benefit obligations, fair values of plan assets and reconciliations of the funded status of the retirement plans: Pension SERP Postretirement Medical September 30, 2016 2015 2016 2015 2016 2015 Change in Projected Benefit Obligation: Benefit obligation at beginning of year $ 8,683,000 $ 8,299,000 $ 1,900,000 $ 1,767,000 $ 1,319,000 $ 1,227,000 Service cost 261,000 256,000 68,000 62,000 — — Interest cost 364,000 356,000 86,000 77,000 56,000 52,000 Actuarial loss 953,000 110,000 318,000 — 1,111,000 40,000 Benefits paid (206,000 ) (326,000 ) (6,000 ) (6,000 ) — — Administrative expenses paid — (12,000 ) — — — — Benefit obligation at end of year 10,055,000 8,683,000 2,366,000 1,900,000 2,486,000 1,319,000 Change in Plan Assets: Fair value of plan assets at beginning of year 6,488,000 7,022,000 — — — — Actual return (loss) on plan assets 813,000 (446,000 ) — — — — Employer contributions 1,100,000 250,000 6,000 6,000 — — Benefits paid (206,000 ) (326,000 ) (6,000 ) (6,000 ) — — Administrative expenses paid — (12,000 ) — — — — Fair value of plan assets at end of year 8,195,000 6,488,000 — — — — Funded status $ (1,860,000 ) $ (2,195,000 ) $ (2,366,000 ) $ (1,900,000 ) $ (2,486,000 ) $ (1,319,000 )
Schedule of amounts recognized in the consolidated balance sheets	Pension SERP Postretirement Medical September 30, 2016 2015 2016 2015 2016 2015 Amounts recognized in the Consolidated Balance Sheets: Current liabilities $ — $ — $ (5,000 ) $ (5,000 ) $ — $ — Noncurrent liabilities (1,860,000 ) (2,195,000 ) (2,361,000 ) (1,895,000 ) (2,486,000 ) (1,319,000 ) Net amount $ (1,860,000 ) $ (2,195,000 ) $ (2,366,000 ) $ (1,900,000 ) $ (2,486,000 ) $ (1,319,000 ) Amounts recognized in accumulated other comprehensive loss (income) before income taxes: Net actuarial loss (gain) $ 3,521,000 $ 3,038,000 $ 797,000 $ 506,000 $ 1,001,000 $ (110,000 ) Prior service cost (credit) 70,000 77,000 (70,000 ) (76,000 ) — — Accumulated other comprehensive loss (income) $ 3,591,000 $ 3,115,000 $ 727,000 $ 430,000 $ 1,001,000 $ (110,000 )
Schedule of amounts recognized in accumulated other comprehensive (loss) income	Pension SERP Postretirement Medical September 30, 2016 2015 2016 2015 2016 2015 Amounts recognized in the Consolidated Balance Sheets: Current liabilities $ — $ — $ (5,000 ) $ (5,000 ) $ — $ — Noncurrent liabilities (1,860,000 ) (2,195,000 ) (2,361,000 ) (1,895,000 ) (2,486,000 ) (1,319,000 ) Net amount $ (1,860,000 ) $ (2,195,000 ) $ (2,366,000 ) $ (1,900,000 ) $ (2,486,000 ) $ (1,319,000 ) Amounts recognized in accumulated other comprehensive loss (income) before income taxes: Net actuarial loss (gain) $ 3,521,000 $ 3,038,000 $ 797,000 $ 506,000 $ 1,001,000 $ (110,000 ) Prior service cost (credit) 70,000 77,000 (70,000 ) (76,000 ) — — Accumulated other comprehensive loss (income) $ 3,591,000 $ 3,115,000 $ 727,000 $ 430,000 $ 1,001,000 $ (110,000 )
Schedule of weighted-average assumptions used to determine benefit obligations and net periodic benefit costs	The following table presents the weighted-average assumptions used to determine benefit obligations and net benefit costs: Pension SERP Postretirement Medical Year ended September 30, 2016 2015 2016 2015 2016 2015 Assumptions used to determine fiscal year-end benefit obligations: Discount rate 3.50% 4.25% 3.50% 4.25% 3.50% 4.25% Rate of compensation increase 4.00% 4.00% 4.00% 4.00% N/A N/A Assumptions used to determine net benefit costs (years ended): Discount rate 4.25% 4.25% 4.25% 4.25% 4.25% 4.25% Expected return on plan assets 7.00% 7.00% N/A N/A N/A N/A Rate of compensation increase 4.00% 4.00% 4.00% 4.00% N/A N/A
Schedule of components of net periodic benefit cost	The components of net periodic benefit cost are as follows: Pension SERP Postretirement Medical Year ended September 30, 2016 2015 2016 2015 2016 2015 Net periodic benefit cost for the year: Service cost $ 261,000 $ 256,000 $ 68,000 $ 62,000 $ — $ — Interest cost 364,000 356,000 86,000 77,000 56,000 52,000 Expected return on plan assets (484,000 ) (500,000 ) — — — — Amortization of prior service cost (credit) 5,000 5,000 (5,000 ) (5,000 ) — — Amortization of net actuarial loss (gain) 141,000 86,000 27,000 24,000 — (5,000 ) Net periodic benefit cost $ 287,000 $ 203,000 $ 176,000 $ 158,000 $ 56,000 $ 47,000
Schedule of amounts that are estimated to be amortized from accumulated other comprehensive loss into net periodic benefit cost in the next fiscal year	The amounts that are estimated to be amortized from accumulated other comprehensive loss into net periodic benefit cost in the next fiscal year are as follows: Pension SERP Postretirement Prior service cost (credit) $ 5,000 $ (5,000 ) $ — Net actuarial loss 163,000 36,000 188,000 $ 168,000 $ 31,000 $ 188,000
Schedule of benefits expected to be paid under the retirement plans	The benefits expected to be paid under the retirement plans as of September 30, 2016 are as follows: Pension SERP Postretirement Expected Benefit Payments: Fiscal year ending September 30, 2017 $ 279,000 $ 5,000 $ — Fiscal year ending September 30, 2018 $ 298,000 $ 4,000 $ 42,000 Fiscal year ending September 30, 2019 $ 284,000 $ 3,000 $ 44,000 Fiscal year ending September 30, 2020 $ 389,000 $ 72,000 $ 39,000 Fiscal year ending September 30, 2021 $ 413,000 $ 73,000 $ 72,000 Fiscal years ending September 30, 2022 through 2026 $ 2,511,000 $ 642,000 $ 413,000
Schedule of assumed health care cost trend rates related to the measurement of postretirement medical obligations	The following table provides the assumed health care cost trend rates related to the measurement of Barnwell’s postretirement medical obligations. Year ended September 30, 2016 2015 Health care cost trend rates assumed for next year 7.75% 8.0% Ultimate cost trend rate 5.0% 5.0% Year that the rate reaches the ultimate trend rate 2028 2028
Schedule of effects of one-percentage-point change in the assumed health care cost trend rates	A one-percentage-point change in the assumed health care cost trend rates would have the following effects: 1-Percentage 1-Percentage Effect on total service and interest cost components $ 11,000 $ (9,000 ) Effect on accumulated postretirement benefit obligations $ 527,000 $ (416,000 )
Schedule of year-end target allocation, by asset category, and the actual asset allocations	The Company’s year-end target allocation, by asset category, and the actual asset allocations were as follows: Target September 30, Asset Category Allocation 2016 2015 Cash and other 0% - 30% 7% 9% Fixed income securities 20% - 60% 23% 22% Equity securities 30% - 70% 70% 69%
Schedule of pension plan assets at fair value	The following tables set forth by level, within the fair value hierarchy, pension plan assets at their fair value: Fair Value Measurements Using: Carrying Quoted Significant Significant Financial Assets: Cash $ 571,000 $ 571,000 $ — $ — Corporate bonds 316,000 316,000 — — Fixed income exchange-traded funds 1,414,000 1,414,000 — — Preferred securities 184,000 184,000 — — Equity securities exchange-traded funds 818,000 818,000 — — Equities 4,892,000 4,892,000 — — Total $ 8,195,000 $ 8,195,000 $ — $ — Fair Value Measurements Using: Carrying Quoted Significant Significant Financial Assets: Cash $ 621,000 $ 621,000 $ — $ — Corporate bonds 354,000 354,000 — — Fixed income exchange-traded funds 819,000 819,000 — — Preferred securities 230,000 230,000 — — Equity securities exchange-traded funds 764,000 764,000 — — Equities 3,700,000 3,700,000 — — Total $ 6,488,000 $ 6,488,000 $ — $ —

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Sep. 30, 2016
Income Tax Disclosure [Abstract]
Components of income (loss) before income taxes, after adjusting the income (loss) for non-controlling interests	The components of earnings (loss) before income taxes, after adjusting the earnings (loss) for non-controlling interests, are as follows: Year ended September 30, 2016 2015 United States $ (360,000 ) $ 1,011,000 Canada (3,977,000 ) 1,460,000 $ (4,337,000 ) $ 2,471,000
Schedule of components of the income tax provision (benefit)	The components of the income tax provision (benefit) related to the above income (loss) are as follows: Year ended September 30, 2016 2015 Current (benefit) provision: United States – Federal $ — $ — United States – State — 94,000 — 94,000 Canadian (651,000 ) 1,529,000 Total current (651,000 ) 1,623,000 Deferred (benefit) provision: United States - Federal — (90,000 ) United States - State 220,000 — Canadian (291,000 ) (325,000 ) Total deferred (71,000 ) (415,000 ) $ (722,000 ) $ 1,208,000
Summary of reconciliation between the reported income tax provision (benefit) and the amount computed by multiplying the loss by the U.S. federal tax rate	A reconciliation between the reported income tax (benefit) provision and the amount computed by multiplying the earnings (loss) attributable to Barnwell before income taxes by the U.S. federal tax rate of 35% is as follows: Year ended September 30, 2016 2015 Tax (benefit) provision computed by applying statutory rate $ (1,518,000 ) $ 865,000 Increase in the valuation allowance - U.S. federal and Canadian tax law 1,051,000 1,653,000 Additional effect of the foreign tax provision on the total tax provision (484,000 ) (1,243,000 ) U.S. state deferred tax provision 220,000 — Other 9,000 (67,000 ) $ (722,000 ) $ 1,208,000
Schedule of tax effects of temporary differences that give rise to significant portions of the deferred tax assets and liabilities	The tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred tax liabilities are as follows: September 30, 2016 2015 Deferred income tax assets: U.S. tax effect of deferred Canadian taxes $ — $ 91,000 Foreign tax credit carryover 4,028,000 4,661,000 Alternative minimum tax credit carryover 460,000 460,000 U.S. federal net operating loss carryover 8,728,000 4,440,000 Tax basis of investment in land and residential real estate in excess of book basis 836,000 1,115,000 Property and equipment accumulated book depreciation and depletion in excess of tax under U.S. tax law 3,611,000 4,494,000 Liabilities accrued for books but not for tax under U.S. tax law 4,843,000 4,423,000 Liabilities accrued for books but not for tax under Canadian tax law 2,303,000 2,149,000 Other 1,108,000 746,000 Total gross deferred tax assets 25,917,000 22,579,000 Less valuation allowance (23,410,000 ) (21,387,000 ) Net deferred income tax assets 2,507,000 1,192,000 Deferred income tax liabilities: Property and equipment accumulated tax depreciation and depletion in excess of book under Canadian tax law (1,012,000 ) (1,459,000 ) Book basis of investment in land development partnerships in excess of tax basis (1,668,000 ) — Other (31,000 ) (4,000 ) Total deferred income tax liabilities (2,711,000 ) (1,463,000 ) Net deferred income tax liability $ (204,000 ) $ (271,000 ) Net deferred income tax liability is included in the Consolidated Balance Sheets as follows: September 30, 2016 2015 Current deferred income tax asset (included in other current assets) $ — $ 178,000 Deferred income tax liability (204,000 ) (449,000 ) Net deferred income tax liability $ (204,000 ) $ (271,000 )
Schedule of changes in unrecognized tax benefits	Below are the changes in unrecognized tax benefits. Year ended September 30, 2016 2015 Balance at beginning of year $ 582,000 $ 660,000 Effect of tax positions taken in prior years — 92,000 Accrued interest related to tax positions taken 20,000 38,000 Lapse of statute (173,000 ) (174,000 ) Translation adjustments (52,000 ) (34,000 ) Balance at end of year $ 377,000 $ 582,000
Summary of tax years, by jurisdiction, that remain subject to examination by taxing authorities	Included below is a summary of the tax years, by jurisdiction, that remain subject to examination by taxing authorities at September 30, 2016 : Jurisdiction Fiscal Years Open U.S. federal 2013 – 2015 Various U.S. states 2013 – 2015 Canada federal 2009 – 2015 Various Canadian provinces 2009 – 2015

SEGMENT AND GEOGRAPHICAL INFORM

SEGMENT AND GEOGRAPHICAL INFORMATION (Tables)	12 Months Ended
	Sep. 30, 2016
Segment Reporting [Abstract]
Schedule of financial information related to reporting segments	The following table presents certain financial information related to Barnwell’s reporting segments. All revenues reported are from external customers with no intersegment sales or transfers. Year ended September 30, 2016 2015 Revenues: Oil and natural gas $ 3,177,000 $ 9,008,000 Land investment 1,915,000 3,244,000 Contract drilling 2,233,000 4,886,000 Residential real estate 5,700,000 — Other 216,000 341,000 Total before interest income 13,241,000 17,479,000 Interest income 46,000 54,000 Total revenues $ 13,287,000 $ 17,533,000 Depletion, depreciation, and amortization: Oil and natural gas $ 1,236,000 $ 2,987,000 Contract drilling 251,000 272,000 Other 120,000 105,000 Total depletion, depreciation, and amortization $ 1,607,000 $ 3,364,000 Impairment: Oil and natural gas $ 1,154,000 $ — Residential real estate — 316,000 Total impairment $ 1,154,000 $ 316,000 Operating profit (loss) (before general and administrative expenses): Oil and natural gas $ (2,355,000 ) $ (366,000 ) Land investment 1,915,000 3,244,000 Contract drilling (116,000 ) 922,000 Residential real estate 190,000 (316,000 ) Other 96,000 236,000 Gain on sales of assets 472,000 6,489,000 Total operating profit 202,000 10,209,000 Equity in income of affiliates: Land investment 2,624,000 1,580,000 General and administrative expenses (6,361,000 ) (8,551,000 ) Interest expense (97,000 ) (315,000 ) Interest income 46,000 54,000 (Loss) earnings before income taxes $ (3,586,000 ) $ 2,977,000 Capital Expenditures: Year ended September 30, 2016 2015 Oil and natural gas $ 1,872,000 $ 3,512,000 Contract drilling 66,000 124,000 Other 2,000 79,000 Total $ 1,940,000 $ 3,715,000 Assets By Segment: September 30, 2016 2015 Oil and natural gas (1) $ 6,323,000 $ 7,298,000 Land investment (2) 4,744,000 7,480,000 Contract drilling (2) 1,438,000 2,338,000 Residential real estate (2) — 5,132,000 Other: Cash and cash equivalents 15,550,000 8,471,000 Restricted cash 381,000 7,577,000 Corporate and other 3,132,000 3,257,000 Total $ 31,568,000 $ 41,553,000 ______________ (1) Primarily located in the province of Alberta, Canada. (2) Located in Hawaii.
Schedule of long-lived assets and revenue by geographic area	Long-Lived Assets By Geographic Area: September 30, 2016 2015 United States $ 5,187,000 $ 10,135,000 Canada 5,267,000 5,740,000 Total $ 10,454,000 $ 15,875,000 Revenue By Geographic Area: Year ended September 30, 2016 2015 United States $ 9,886,000 $ 8,237,000 Canada 3,355,000 9,242,000 Total (excluding interest income) $ 13,241,000 $ 17,479,000

ACCUMULATED OTHER COMPREHENSI43

ACCUMULATED OTHER COMPREHENSIVE (LOSS) INCOME (Tables)	12 Months Ended
	Sep. 30, 2016
Equity [Abstract]
Schedule of components of accumulated other comprehensive (loss) income, net of taxes	Components of accumulated other comprehensive (loss) income, net of taxes, are as follows: Year ended September 30, 2016 2015 Foreign currency translation: Beginning accumulated foreign currency translation $ 819,000 $ 1,692,000 Change in cumulative translation adjustment before reclassifications 87,000 (1,625,000 ) Amounts reclassified from accumulated other comprehensive income — 752,000 Income taxes — — Net current period other comprehensive income (loss) 87,000 (873,000 ) Ending accumulated foreign currency translation 906,000 819,000 Retirement plans: Beginning accumulated retirement plans benefit cost (2,941,000 ) (1,950,000 ) Amortization of net actuarial loss and prior service cost 168,000 105,000 Net actuarial loss arising during the period (2,053,000 ) (1,096,000 ) Income taxes — — Net current period other comprehensive loss (1,885,000 ) (991,000 ) Ending accumulated retirement plans benefit cost (4,826,000 ) (2,941,000 ) Accumulated other comprehensive loss, net of taxes $ (3,920,000 ) $ (2,122,000 )

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Sep. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Summary of minimum rental payments under non-cancelable operating leases	Barnwell is committed under these leases for minimum rental payments summarized by fiscal year as follows: Fiscal year ending 2017 $ 261,000 2018 138,000 2019 118,000 2020 118,000 2021 118,000 Thereafter through 2026 130,000 Total $ 883,000

INFORMATION RELATING TO THE C45

INFORMATION RELATING TO THE CONSOLIDATED STATEMENTS OF CASH FLOWS (Tables)	12 Months Ended
	Sep. 30, 2016
Supplemental Cash Flow Elements [Abstract]
Schedule of supplemental cash flow information	The following table details the effect of changes in current assets and liabilities on the Consolidated Statements of Cash Flows, and presents supplemental cash flow information: Year ended September 30, 2016 2015 Increase (decrease) from changes in: Receivables $ 1,081,000 $ 324,000 Other current assets 49,000 (447,000 ) Accounts payable (1,456,000 ) (439,000 ) Accrued compensation (79,000 ) (323,000 ) Other current liabilities (882,000 ) (687,000 ) Decrease from changes in current assets and liabilities $ (1,287,000 ) $ (1,572,000 ) Supplemental disclosure of cash flow information: Cash paid during the year for: Interest $ 94,000 $ 306,000 Income taxes (refunded) paid, net $ (219,000 ) $ 1,812,000

SUPPLEMENTARY OIL AND NATURAL46

SUPPLEMENTARY OIL AND NATURAL GAS INFORMATION (UNAUDITED) (Tables)	12 Months Ended
	Sep. 30, 2016
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Summary of changes in the estimates of net interests in total proved developed reserves of oil and natural gas liquids and natural gas	OIL & NGL GAS Total Proved reserves: Balance at September 30, 2014 724,000 9,465,000 2,356,000 Revisions of previous estimates 79,000 (520,000 ) (11,000 ) Extensions, discoveries and other additions — 3,000 1,000 Acquisitions of reserves 46,000 543,000 140,000 Less sales of reserves (237,000 ) (4,679,000 ) (1,044,000 ) Less production (143,000 ) (1,688,000 ) (434,000 ) Balance at September 30, 2015 469,000 3,124,000 1,008,000 Revisions of previous estimates (23,000 ) (1,320,000 ) (251,000 ) Extensions, discoveries and other additions 54,000 95,000 70,000 Acquisitions of reserves 34,000 18,000 37,000 Less production (84,000 ) (476,000 ) (166,000 ) Balance at September 30, 2016 450,000 1,441,000 698,000
Schedule of capitalized costs relating to oil and natural gas producing activities	All capitalized costs relating to oil and natural gas producing activities, which were being depleted in all years, are summarized as follows: September 30, 2016 2015 Proved properties $ 66,044,000 $ 62,960,000 Unproved properties 221,000 145,000 Total capitalized costs 66,265,000 63,105,000 Accumulated depletion and depreciation 61,060,000 57,460,000 Net capitalized costs $ 5,205,000 $ 5,645,000
Schedule of costs incurred in oil and natural gas property acquisition, exploration and development	Year ended September 30, 2016 2015 Acquisition of properties: Unproved $ 161,000 $ 28,000 Proved 608,000 804,000 Exploration costs — — Development costs 1,103,000 2,680,000 Total $ 1,872,000 $ 3,512,000
Schedule of results of operations for oil and natural gas producing activities	Year ended September 30, 2016 2015 Net revenues $ 3,177,000 $ 9,008,000 Production costs (3,142,000 ) (6,387,000 ) Depletion (1,236,000 ) (2,987,000 ) Impairment of assets (1,154,000 ) — Pre-tax results of operations (1) (2,355,000 ) (366,000 ) Estimated income tax benefit (expense) (2) 297,000 (921,000 ) Results of operations (1) $ (2,058,000 ) $ (1,287,000 ) _________________ (1) Before gain on sale of oil and natural gas properties, general and administrative expenses, interest expense, and foreign exchange gains and losses. (2) Estimated income tax benefit (expense) includes charges to deferred income taxes for the valuation allowance necessary for the portion of Canadian tax law deferred tax assets that may not be realizable.
Schedule of standardized measure of discounted future net cash flows	September 30, 2016 2015 Future cash inflows $ 17,259,000 $ 27,749,000 Future production costs (11,951,000 ) (18,468,000 ) Future development costs (426,000 ) (935,000 ) Future income tax expenses (1,016,000 ) (2,361,000 ) Future net cash flows 3,866,000 5,985,000 10% annual discount for timing of cash flows (956,000 ) (1,950,000 ) Standardized measure of discounted future net cash flows $ 2,910,000 $ 4,035,000
Schedule of changes in standardized measure of discounted future net cash flows	Year ended September 30, 2016 2015 Beginning of year $ 4,035,000 $ 24,147,000 Sales of oil and natural gas produced, net of production costs (35,000 ) (2,621,000 ) Net changes in prices and production costs, net of royalties and wellhead taxes (4,134,000 ) (8,042,000 ) Extensions and discoveries 1,285,000 1,000 Net change due to purchases and sales of minerals in place 470,000 (9,103,000 ) Revisions of previous quantity estimates (343,000 ) 634,000 Net change in income taxes 98,000 1,658,000 Accretion of discount 412,000 2,021,000 Other - changes in the timing of future production and other 1,018,000 (1,009,000 ) Other - net change in Canadian dollar translation rate 104,000 (3,651,000 ) Net change (1,125,000 ) (20,112,000 ) End of year $ 2,910,000 $ 4,035,000

SUMMARY OF SIGNIFICANT ACCOUN47

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) CAD in Thousands, $ in Thousands	12 Months Ended
	Sep. 30, 2016USD ($)venture	Sep. 30, 2016CAD	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)
Principles of Consolidation
Number of 80%-owned joint ventures | venture	2
Restricted Cash and Investments [Abstract]
Restricted cash		CAD 500	$ 381	$ 7,458
Retirement Plans
Increase (decrease) pension expense | $	$ 43
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Abstract]
Discount Rate	10.00%
Minimum
Equity Method Investments
Ownership interest in affiliated companies required to account investments under equity method investments (more than)	3.00%
Maximum
Equity Method Investments
Ownership interest in affiliated companies required to account investments under equity method investments (more than)	5.00%
Retirement Plans
Decrease (increase) in the expected return on plan assets assumption	0.50%
Kaupulehu Developments
Principles of Consolidation
Ownership interest in subsidiaries	77.60%
KD Kona 2013 LLLP
Principles of Consolidation
Ownership interest in subsidiaries	75.00%
Kaupulehu 2007, LLLP
Principles of Consolidation
Ownership interest in subsidiaries	80.00%
Kaupulehu Investors, LLC
Principles of Consolidation
Ownership interest in subsidiaries	80.00%

LIQUIDITY (Details)

LIQUIDITY (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2014
Liquidity [Line Items]
Cash and cash equivalents	$ 15,550	$ 8,471	$ 16,104
Working capital	$ 16,378

EARNINGS (LOSS) PER COMMON SH49

EARNINGS (LOSS) PER COMMON SHARE (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Net Earnings (Loss) (Numerator)
Basic	$ (3,615)	$ 1,263
Diluted	$ (3,615)	$ 1,263
Shares (Denominator)
Basic (in shares)	8,277,160	8,277,160
Effect of dilutive securities-common stock options (in shares)	0	0
Diluted (in shares)	8,277,160	8,277,160
Per-Share Amount
Basic net earnings (loss) per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share)	$ (0.44)	$ 0.15
Diluted net earnings (loss) per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share)	$ (0.44)	$ 0.15
Options
Antidilutive shares of common stock excluded from the computation of diluted shares
Antidilutive shares excluded from computation of earnings (loss) per share (in shares)	621,250	621,250

SHARE-BASED PAYMENTS (Details)

SHARE-BASED PAYMENTS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Components of the total share-based compensation
Share-based compensation (benefit) expense	$ (22)	$ (140)
Income tax effect related to share-based compensation benefit	0	0
Total unrecognized compensation cost	$ 8
Period over which unrecognized compensation cost is expected to be recognized	1 year 2 months 13 days
Liability-classified share options
Components of the total share-based compensation
Share Based Compensation Expense Due to Vesting	$ 4	10
Share Based Compensation Expense (Benefit) Due to Remeasurement	(36)	(170)
Share-based compensation (benefit) expense	(32)	(160)
Equity-classified share options
Components of the total share-based compensation
Share-based compensation (benefit) expense	$ 10	$ 20
2008 Equity Incentive Plan
Components of the total share-based compensation
Shares authorized and reserved for issuance	800,000
Shares available for grant	62,500
Vesting period	4 years
Period from the date of grant from which vesting commences	1 year
Expiration period	10 years

SHARE-BASED PAYMENTS Equity- an

SHARE-BASED PAYMENTS Equity- and Liability- Classified Awards (Details) - USD ($)	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Liability-classified share options
Shares
Outstanding at the beginning of the period (in shares)	591,250
Granted (in shares)	0
Exercised (in shares)	0
Expired/Forfeited (in shares)	0
Outstanding at the end of the period (in shares)	591,250	591,250
Exercisable at the end of period (in shares)	576,250
Weighted-Average Exercise Price
Outstanding at the beginning of the period (in dollars per share)	$ 7.98
Granted (in dollars per share)	0
Exercised (in dollars per share)	0
Expired/Forfeited (in dollars per share)	0
Outstanding at the end of the period (in dollars per share)	7.98	$ 7.98
Exercisable at the end of period (in dollars per share)	$ 8.11
Weighted-Average Remaining Contractual Term
Options outstanding, weighted average contractual life	2 years 6 months 2 days
Options exercisable, weighted average contractual life	2 years 4 months 26 days
Aggregate Intrinsic Value
Options outstanding, aggregate intrinsic value	$ 0
Options exercisable, aggregate intrinsic value	$ 0
Assumptions used in estimating fair value
Expected volatility range, minimum	56.70%	51.50%
Expected volatility range, maximum	72.70%	61.60%
Weighted-average volatility	63.60%	52.40%
Expected dividends	0.00%	0.00%
Risk-free interest rate, minimum	0.60%	0.60%
Risk-free interest rate, maximum	1.40%	1.90%
Expected forfeitures	0.00%	0.00%
Liability-classified share options | Minimum
Assumptions used in estimating fair value
Expected term	1 year 2 months 13 days	2 years 2 months 12 days
Liability-classified share options | Maximum
Assumptions used in estimating fair value
Expected term	7 years 2 months 13 days	8 years 2 months 12 days
Equity-classified share options
Shares
Outstanding at the beginning of the period (in shares)	30,000
Granted (in shares)	0
Exercised (in shares)	0
Expired/Forfeited (in shares)	0
Outstanding at the end of the period (in shares)	30,000	30,000
Exercisable at the end of period (in shares)	15,000
Weighted-Average Exercise Price
Outstanding at the beginning of the period (in dollars per share)	$ 3.01
Granted (in dollars per share)	0
Exercised (in dollars per share)	0
Expired/Forfeited (in dollars per share)	0
Outstanding at the end of the period (in dollars per share)	3.01	$ 3.01
Exercisable at the end of period (in dollars per share)	$ 3.01
Weighted-Average Remaining Contractual Term
Options outstanding, weighted average contractual life	7 years 2 months 13 days
Options exercisable, weighted average contractual life	7 years 2 months 13 days
Aggregate Intrinsic Value
Options outstanding, aggregate intrinsic value	$ 0
Options exercisable, aggregate intrinsic value	$ 0

ACCOUNTS RECEIVABLE AND CONTR52

ACCOUNTS RECEIVABLE AND CONTRACT COSTS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Receivables [Abstract]
Allowances for doubtful accounts	$ 40	$ 23
Contract retainage balance included in accounts receivable	$ 202	257
Expected collection period of retainage balance	1 year
Expected collection period of retainage balance after the related contracts have received final acceptance and approval	45 days
Costs and estimated earnings (loss) on uncompleted contracts
Costs incurred on uncompleted contracts	$ 966	1,890
Estimated earnings	70	226
Costs and estimated earnings (loss) on uncompleted contracts	1,036	2,116
Less billings to date	1,112	2,503
Net costs and estimated earnings (loss) in excess of (less than) billings	(76)	(387)
Costs and estimated earnings (loss) on uncompleted contracts included in the consolidated balance sheets
Costs and estimated earnings in excess of billings on uncompleted contracts (included in other current assets)	89	182
Billings in excess of costs and estimated earnings on uncompleted contracts (included in other current liabilities)	(165)	(569)
Net costs and estimated earnings (loss) in excess of (less than) billings	$ (76)	$ (387)

ASSETS HELD FOR SALE Assets Hel

ASSETS HELD FOR SALE Assets Held for Sale (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Sep. 30, 2015
ASSETS HELD FOR SALE [Abstract]
Asset held for sale	$ 1,829	$ 0

INVESTMENT HELD FOR SALE Invest

INVESTMENT HELD FOR SALE Investment held for sale (Details)	1 Months Ended
	Oct. 31, 2014USD ($)	Sep. 30, 2016parcel
Investment in Land [Line Items]
Proceeds from sale of property held-for-sale | $	$ 1,250,000
Investment in land
Investment in Land [Line Items]
Number of residential parcels owned | parcel		1

REAL ESTATE HELD FOR SALE (Deta

REAL ESTATE HELD FOR SALE (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Real estate held for sale
Residential real estate	$ 5,700	$ 0
Operating Income (Loss)	202	$ 10,209
Kaupulehu 2007, LLLP
Real estate held for sale
Residential real estate	5,700
Operating Income (Loss)	$ 190

INVESTMENTS (Details)

INVESTMENTS (Details)	Nov. 27, 2013USD ($)partnership	Sep. 30, 2016USD ($)aincrementlot	Sep. 30, 2015USD ($)
Summary of investments
Total investments		$ 3,552,000	$ 6,288,000
Equity in income of affiliates		2,624,000	1,580,000
Revenues sale of interest in leasehold land, net		$ 1,915,000	3,244,000
Kaupulehu Developments
Summary of investments
Area of land (in acres) | a		870
Number of development increments | increment		2
Sale of interest in leasehold land: Proceeds		$ 2,255,000	3,772,000
Sale of interest in leasehold land: Fees		(340,000)	(528,000)
Revenues sale of interest in leasehold land, net		1,915,000	3,244,000
KD Kaupulehu LLLP Increment I | Kaupulehu Developments
Summary of investments
Gross proceeds from sale of Increment I single-family lots on which payments to be received from KD I is based		$ 205,000,000
Number of Lots Remaining to be Sold | lot		25
Number of lots sold | lot		3
Number of lots developed | lot		80
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | Aggregate gross proceeds up to $100,000,000
Summary of investments
Payments Entitled to be Received as Percentage of Gross Proceeds from Sale of Single Family Lots		9.00%
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | Aggregate gross proceeds greater than $100,000,000 up to $300,000,000
Summary of investments
Payments Entitled to be Received as Percentage of Gross Proceeds from Sale of Single Family Lots		10.00%
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | Aggregate gross proceeds in excess of $300,000,000
Summary of investments
Payments Entitled to be Received as Percentage of Gross Proceeds from Sale of Single Family Lots		14.00%
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | Minimum | Aggregate gross proceeds greater than $100,000,000 up to $300,000,000
Summary of investments
Gross proceeds from sale of Increment I single-family lots on which payments to be received from KD I is based		$ 100,000,000
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | Minimum | Aggregate gross proceeds in excess of $300,000,000
Summary of investments
Gross proceeds from sale of Increment I single-family lots on which payments to be received from KD I is based		300,000,000
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | Maximum | Aggregate gross proceeds up to $100,000,000
Summary of investments
Gross proceeds from sale of Increment I single-family lots on which payments to be received from KD I is based		100,000,000
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | Maximum | Aggregate gross proceeds greater than $100,000,000 up to $300,000,000
Summary of investments
Gross proceeds from sale of Increment I single-family lots on which payments to be received from KD I is based		300,000,000
KD Kaupulehu LLLP Increment II | Kaupulehu Developments
Summary of investments
Contingent Payments, Unrecorded		$ 8,000,000
Number of lots developed | lot		2
KD Kaupulehu LLLP Increment II | Kaupulehu Developments | Minimum
Summary of investments
Payments Entitled to be Received as Percentage of Gross Proceeds from Sale of Single Family Lots		8.00%
Payments Entitled to be Received as Percentage of Gross Proceeds from Sale of Units on a Lot		2.60%
Summarized financial information
Increment II Lot size | a		2
KD Kaupulehu LLLP Increment II | Kaupulehu Developments | Maximum
Summary of investments
Payments Entitled to be Received as Percentage of Gross Proceeds from Sale of Single Family Lots		10.00%
Payments Entitled to be Received as Percentage of Gross Proceeds from Sale of Units on a Lot		3.25%
Summarized financial information
Increment II Lot size | a		3
Investment in land development partnerships
Summary of investments
Total investments		$ 3,502,000	6,238,000
Number of limited liability limited partnerships formed | partnership	2
Cash Distribution from Equity Method Investment		5,320,000
Minority interests portion of distribution from equity investee		40,000
Equity in income of affiliates		2,624,000	1,580,000
Basis difference between the underlying equity in net assets of the investee and the carrying value of the entity's investment		351,000
Basis difference adjustment		39,000	82,000
Bonds issued by the surety		325,000
Maximum loss exposure		3,827,000
Summarized financial information
Revenue		33,874,000	29,898,000
Gross profit		15,332,000	13,594,000
Net earnings		$ 12,212,000	7,500,000
Investment in land development partnerships | KD Kukio Resorts, LLLP, KD Maniniowali, LLLP, and KD Kaupulehu, LLLP
Summary of investments
Ownership interest acquired, aggregate cost	$ 5,140,000
Investment in land development partnerships | KD Kukio Resorts, LLLP
Summary of investments
Ownership interest acquired	19.60%
Investment in land development partnerships | KD Maniniowali, LLLP
Summary of investments
Ownership interest acquired	19.60%
Investment in land development partnerships | KD Kaupulehu, LLLP
Summary of investments
Ownership interest acquired	19.60%
Investment in land | KD Kaupulehu LLLP Increment I
Summary of investments
Number of residential parcels held by equity method investment | lot		25
Investment in land | KD Kaupulehu LLLP Increment II
Summary of investments
Number of residential parcels held by equity method investment | lot		1
Investment in leasehold land interest - Lot 4C
Summary of investments
Total investments		$ 50,000	$ 50,000
Area of land (in acres) | a		1,000

OIL AND NATURAL GAS PROPERTIE57

OIL AND NATURAL GAS PROPERTIES (Details) - USD ($)	1 Months Ended	12 Months Ended		24 Months Ended
	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 12, 2016	Aug. 27, 2015	Nov. 13, 2014
Oil and natural gas properties
Liabilities associated with properties sold		$ 0	$ 2,013,000
Revenues		13,287,000	17,533,000
Net earnings (loss)		(2,864,000)	1,769,000
Net earnings (loss) attributable to Barnwell Industries, Inc. stockholders		$ (3,615,000)	$ 1,263,000
Basic net earnings (loss) per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share)		$ (0.44)	$ 0.15
Oil and natural gas properties | Progress November 2014 [Member]
Oil and natural gas properties
Property and equipment							$ 751,000
Asset retirement obligation							(225,000)
Net identifiable assets acquired							$ 526,000
Oil and natural gas properties | Progress August 2015 [Member]
Oil and natural gas properties
Property and equipment						$ 397,000
Asset retirement obligation						(91,000)
Net identifiable assets acquired						$ 306,000
Oil and natural gas properties | Wood River Sept 2016 [Member]
Oil and natural gas properties
Property and equipment					$ 813,000
Asset retirement obligation					(44,000)
Net identifiable assets acquired					$ 769,000
Oil and natural gas properties | Dunvegan and Belloy areas of Alberta
Oil and natural gas properties
Divestiture of businesses, sale price	$ 21,875,000
Proceeds from divestiture of businesses	$ 14,162,000	$ 493,000
Percent difference in capitalized costs divided by proved reserves	220.00%
Gain (loss) recognized from property sales		$ 472,000	$ 6,217,000
Liabilities associated with properties sold			2,013,000
Revenues			17,533,000
Net earnings (loss)			1,769,000
Net earnings (loss) attributable to Barnwell Industries, Inc. stockholders			$ 1,263,000
Basic net earnings (loss) per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share)			$ 0.15
Cumulative gain on sale of oil and gas property				$ 6,689,000
Oil and natural gas properties | Dunvegan and Belloy areas of Alberta | Pro Forma
Oil and natural gas properties
Revenues			$ 13,235,000
Net earnings (loss)			(761,000)
Net earnings (loss) attributable to Barnwell Industries, Inc. stockholders			$ (1,267,000)
Basic net earnings (loss) per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share)			$ (0.15)
Oil and natural gas properties | Dunvegan and Belloy areas of Alberta | Working Interest Owner
Oil and natural gas properties
Proceeds from divestiture of businesses	$ 7,247,000

PROPERTY AND EQUIPMENT AND AS58

PROPERTY AND EQUIPMENT AND ASSET RETIREMENT OBLIGATION (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Property and equipment
Gross Property and Equipment	$ 76,868	$ 75,953
Accumulated Depletion, Depreciation, and Amortization	(69,966)	(66,485)
Net Property and Equipment	6,902	9,468
Change in the asset retirement obligation
Balance at the beginning of the year	6,936	9,163
Obligations incurred on new wells drilled or acquired	167	316
Liabilities associated with properties sold	0	(2,013)
Revision of estimated obligation	(68)	918
Accretion expense	464	632
Payments	(459)	(655)
Foreign currency translation adjustment	154	(1,425)
Balance at the end of the year	7,194	6,936
Less current portion	(1,017)	(506)
Asset retirement obligation, long-term	6,177	6,430
Land
Property and equipment
Gross Property and Equipment	365	863
Net Property and Equipment	365	863
Oil and natural gas properties
Property and equipment
Gross Property and Equipment	66,265	63,105
Accumulated Depletion, Depreciation, and Amortization	(61,060)	(57,460)
Net Property and Equipment	5,205	5,645
Drilling rigs and equipment
Property and equipment
Gross Property and Equipment	6,379	6,598
Accumulated Depletion, Depreciation, and Amortization	(5,770)	(5,825)
Net Property and Equipment	$ 609	$ 773
Drilling rigs and equipment | Minimum
Property and equipment
Estimated useful lives	3 years	3 years
Drilling rigs and equipment | Maximum
Property and equipment
Estimated useful lives	10 years	10 years
Offices
Property and equipment
Estimated useful lives	40 years	40 years
Gross Property and Equipment	$ 857	$ 2,420
Accumulated Depletion, Depreciation, and Amortization	(274)	(445)
Net Property and Equipment	583	1,975
Other property and equipment
Property and equipment
Gross Property and Equipment	3,002	2,967
Accumulated Depletion, Depreciation, and Amortization	(2,862)	(2,755)
Net Property and Equipment	$ 140	$ 212
Other property and equipment | Minimum
Property and equipment
Estimated useful lives	3 years	3 years
Other property and equipment | Maximum
Property and equipment
Estimated useful lives	17 years	17 years

LONG-TERM DEBT (Details)

LONG-TERM DEBT (Details)	12 Months Ended
	Sep. 30, 2016CAD	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2015CAD	Sep. 30, 2015USD ($)
Long-term debt
Restricted cash	CAD 500,000		$ 381,000		$ 7,458,000
Canadian revolving credit facility
Long-term debt
Maximum borrowing capacity | CAD				CAD 1,000,000
Realized foreign currency transaction (gain) loss		$ 752,000
Repayment of the credit facility		$ 7,000,000
Revolving Demand Facility [Member]
Long-term debt
Long-term debt			0
Maximum borrowing capacity	500,000		381,000
Issued letters of credit			34,000
Restricted cash	CAD 500,000		$ 381,000
Revolving Demand Facility [Member] | London Interbank Offer Rate
Long-term debt
Interest rate margin	1.00%
Real Estate Loan [Member]
Long-term debt
Long-term debt					$ 3,440,000

RETIREMENT PLANS (Details)

RETIREMENT PLANS (Details) - USD ($)	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Change in Plan Assets:
Fair value of plan assets at beginning of year	$ 6,488,000
Fair value of plan assets at end of year	8,195,000	$ 6,488,000
Amounts recognized in the Consolidated Balance Sheets:
Noncurrent liabilities	$ (6,707,000)	(5,409,000)
Pension Plan
Retirement plans
Period of employee's highest average earnings on which benefits are based	5 years
Change in Projected Benefit Obligation:
Benefit obligation at beginning of year	$ 8,683,000	8,299,000
Service cost	261,000	256,000
Interest cost	364,000	356,000
Actuarial loss	953,000	110,000
Benefits paid	(206,000)	(326,000)
Administrative expenses paid	0	(12,000)
Benefit obligation at end of year	10,055,000	8,683,000
Change in Plan Assets:
Fair value of plan assets at beginning of year	6,488,000	7,022,000
Actual return (loss) on plan assets	813,000	(446,000)
Employer contributions	1,100,000	250,000
Benefits paid	(206,000)	(326,000)
Administrative expenses paid	0	(12,000)
Fair value of plan assets at end of year	8,195,000	6,488,000
Funded status	(1,860,000)	(2,195,000)
Amounts recognized in the Consolidated Balance Sheets:
Noncurrent liabilities	(1,860,000)	(2,195,000)
Net amount	(1,860,000)	(2,195,000)
Amounts recognized in accumulated other comprehensive loss (income) before income taxes:
Net actuarial loss (gain)	3,521,000	3,038,000
Prior service cost (credit)	70,000	77,000
Accumulated other comprehensive loss (income)	3,591,000	$ 3,115,000
Other disclosures
Expected contributions	$ 500,000
Assumptions used to determine fiscal year-end benefit obligations:
Discount rate	3.50%	4.25%
Rate of compensation increase	4.00%	4.00%
Assumptions used to determine net benefit costs (years ended):
Discount rate	4.25%	4.25%
Expected return on plan assets	7.00%	7.00%
Rate of compensation increase	4.00%	4.00%
Net periodic benefit cost for the year:
Service cost	$ 261,000	$ 256,000
Interest cost	364,000	356,000
Expected return on plan assets	(484,000)	(500,000)
Amortization of prior service cost (credit)	5,000	5,000
Amortization of net actuarial loss (gain)	141,000	86,000
Net periodic benefit cost	287,000	203,000
Amounts that are estimated to be amortized from accumulated other comprehensive loss into net periodic benefit cost in the next fiscal year
Prior service cost (credit)	5,000
Net actuarial loss (gain)	163,000
Total amount	168,000
Accumulated benefit obligation	8,566,000	7,420,000
Expected Benefit Payments:
Fiscal year ending September 30, 2017	279,000
Fiscal year ending September 30, 2018	298,000
Fiscal year ending September 30, 2019	284,000
Fiscal year ending September 30, 2020	389,000
Fiscal year ending September 30, 2021	413,000
Fiscal years ending September 30, 2022 through 2026	2,511,000
SERP
Change in Projected Benefit Obligation:
Benefit obligation at beginning of year	1,900,000	1,767,000
Service cost	68,000	62,000
Interest cost	86,000	77,000
Actuarial loss	318,000	0
Benefits paid	(6,000)	(6,000)
Benefit obligation at end of year	2,366,000	1,900,000
Change in Plan Assets:
Employer contributions	6,000	6,000
Benefits paid	(6,000)	(6,000)
Funded status	(2,366,000)	(1,900,000)
Amounts recognized in the Consolidated Balance Sheets:
Current liabilities	(5,000)	(5,000)
Noncurrent liabilities	(2,361,000)	(1,895,000)
Net amount	(2,366,000)	(1,900,000)
Amounts recognized in accumulated other comprehensive loss (income) before income taxes:
Net actuarial loss (gain)	797,000	506,000
Prior service cost (credit)	(70,000)	(76,000)
Accumulated other comprehensive loss (income)	$ 727,000	$ 430,000
Assumptions used to determine fiscal year-end benefit obligations:
Discount rate	3.50%	4.25%
Rate of compensation increase	4.00%	4.00%
Assumptions used to determine net benefit costs (years ended):
Discount rate	4.25%	4.25%
Rate of compensation increase	4.00%	4.00%
Net periodic benefit cost for the year:
Service cost	$ 68,000	$ 62,000
Interest cost	86,000	77,000
Amortization of prior service cost (credit)	(5,000)	(5,000)
Amortization of net actuarial loss (gain)	27,000	24,000
Net periodic benefit cost	176,000	158,000
Amounts that are estimated to be amortized from accumulated other comprehensive loss into net periodic benefit cost in the next fiscal year
Prior service cost (credit)	(5,000)
Net actuarial loss (gain)	36,000
Total amount	31,000
Accumulated benefit obligation	1,822,000	1,458,000
Expected Benefit Payments:
Fiscal year ending September 30, 2017	5,000
Fiscal year ending September 30, 2018	4,000
Fiscal year ending September 30, 2019	3,000
Fiscal year ending September 30, 2020	72,000
Fiscal year ending September 30, 2021	73,000
Fiscal years ending September 30, 2022 through 2026	$ 642,000
Postretirement Medical
Retirement plans
Minimum period of service to be attained for being covered under the plan	20 years
Minimum period of service to be attained at the position of Vice President or higher for being covered under the plan	10 years
Change in Projected Benefit Obligation:
Benefit obligation at beginning of year	$ 1,319,000	1,227,000
Service cost	0	0
Interest cost	56,000	52,000
Actuarial loss	1,111,000	40,000
Benefit obligation at end of year	2,486,000	1,319,000
Change in Plan Assets:
Funded status	(2,486,000)	(1,319,000)
Amounts recognized in the Consolidated Balance Sheets:
Noncurrent liabilities	(2,486,000)	(1,319,000)
Net amount	(2,486,000)	(1,319,000)
Amounts recognized in accumulated other comprehensive loss (income) before income taxes:
Net actuarial loss (gain)	1,001,000	(110,000)
Prior service cost (credit)	0	0
Accumulated other comprehensive loss (income)	$ 1,001,000	$ (110,000)
Assumptions used to determine fiscal year-end benefit obligations:
Discount rate	3.50%	4.25%
Assumptions used to determine net benefit costs (years ended):
Discount rate	4.25%	4.25%
Net periodic benefit cost for the year:
Service cost	$ 0	$ 0
Interest cost	56,000	52,000
Amortization of prior service cost (credit)	0	0
Amortization of net actuarial loss (gain)	0	(5,000)
Net periodic benefit cost	56,000	$ 47,000
Amounts that are estimated to be amortized from accumulated other comprehensive loss into net periodic benefit cost in the next fiscal year
Net actuarial loss (gain)	188,000
Total amount	188,000
Expected Benefit Payments:
Fiscal year ending September 30, 2018	42,000
Fiscal year ending September 30, 2019	44,000
Fiscal year ending September 30, 2020	39,000
Fiscal year ending September 30, 2021	72,000
Fiscal years ending September 30, 2022 through 2026	$ 413,000
Assumed health care cost trend rates related to the measurement of entity's postretirement medical obligations
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	7.75%	8.00%
Ultimate cost trend rate	5.00%	5.00%
Year that the rate reaches the ultimate trend rate	2,028	2,028
Health care cost trend rates assumed for current fiscal year	8.00%
Effects of one-percentage-point change in the assumed health care cost trend rates
Effect on total service and interest cost components, increase	$ 11,000
Effect on accumulated postretirement benefit obligations, increase	527,000
Effect on total service and interest cost components, decrease	(9,000)
Effect on accumulated postretirement benefit obligations, decrease	$ (416,000)

RETIREMENT PLANS - FAIR VALUE (

RETIREMENT PLANS - FAIR VALUE (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Plan assets
Entity's stock included in plan assets	$ 4
Pension plan assets at the fair value
Fair value measurements	8,195	$ 6,488
Quoted Prices in Active Markets (Level 1)
Pension plan assets at the fair value
Fair value measurements	$ 8,195	$ 6,488
Cash and cash equivalents
Entity's year-end target allocation, by asset category, and the actual asset allocations
Target allocation, minimum	0.00%
Target allocation, maximum	30.00%
Actual asset allocation	7.00%	9.00%
Fixed income securities
Entity's year-end target allocation, by asset category, and the actual asset allocations
Target allocation, minimum	20.00%
Target allocation, maximum	60.00%
Actual asset allocation	23.00%	22.00%
Equity securities
Entity's year-end target allocation, by asset category, and the actual asset allocations
Target allocation, minimum	30.00%
Target allocation, maximum	70.00%
Actual asset allocation	70.00%	69.00%
Cash
Pension plan assets at the fair value
Fair value measurements	$ 571	$ 621
Cash | Quoted Prices in Active Markets (Level 1)
Pension plan assets at the fair value
Fair value measurements	571	621
Corporate bonds
Pension plan assets at the fair value
Fair value measurements	316	354
Corporate bonds | Quoted Prices in Active Markets (Level 1)
Pension plan assets at the fair value
Fair value measurements	316	354
Fixed income exchange-traded funds
Pension plan assets at the fair value
Fair value measurements	1,414	819
Fixed income exchange-traded funds | Quoted Prices in Active Markets (Level 1)
Pension plan assets at the fair value
Fair value measurements	1,414	819
Preferred securities
Pension plan assets at the fair value
Fair value measurements	184	230
Preferred securities | Quoted Prices in Active Markets (Level 1)
Pension plan assets at the fair value
Fair value measurements	184	230
Equity securities exchange- traded funds
Pension plan assets at the fair value
Fair value measurements	818	764
Equity securities exchange- traded funds | Quoted Prices in Active Markets (Level 1)
Pension plan assets at the fair value
Fair value measurements	818	764
Equities
Pension plan assets at the fair value
Fair value measurements	4,892	3,700
Equities | Quoted Prices in Active Markets (Level 1)
Pension plan assets at the fair value
Fair value measurements	$ 4,892	$ 3,700

INCOME TAXES (Details)

INCOME TAXES (Details) - USD ($) $ in Thousands	Jul. 01, 2015	Jun. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Components of income (loss) before income taxes, after adjusting the income (loss) for non-controlling interests
United States			$ (360)	$ 1,011
Canada			(3,977)	1,460
Total			(4,337)	2,471
Current (benefit) provision :
United States - State			0	94
Total United States			0	94
Canadian			(651)	1,529
Total current			(651)	1,623
Deferred benefit:
United States - Federal			0	(90)
United States - State			220	0
Canadian			(291)	(325)
Total deferred			(71)	(415)
Total			$ (722)	1,208
Reconciliation between the reported income tax provision (benefit) and the amount computed by multiplying the earnings (loss) attributable to the entity by the U.S. federal tax rate
U.S. federal tax rate			35.00%
Tax (benefit) provision computed by applying statutory rate			$ (1,518)	865
Increase in the valuation allowance - U.S. federal and Canadian tax law			1,051	1,653
Additional effect of the foreign tax provision on the total tax provision			(484)	(1,243)
U.S. state deferred tax provision			220	0
Other			9	(67)
Total			(722)	1,208
Deferred income tax assets:
U.S. tax effect of deferred Canadian taxes			0	91
Foreign tax credit carryover			4,028	4,661
Alternative minimum tax credit carryover			460	460
U.S. federal net operating loss carryover			8,728	4,440
Tax basis of investment in land and residential real estate in excess of book basis			836	1,115
Property and equipment accumulated book depreciation and depletion in excess of tax under U.S. tax law			3,611	4,494
Liabilities accrued for books but not for tax under U.S. tax law			4,843	4,423
Liabilities accrued for books but not for tax under Canadian tax law			2,303	2,149
Other			1,108	746
Total gross deferred tax assets			25,917	22,579
Less Valuation allowance			(23,410)	(21,387)
Net deferred income tax assets			2,507	1,192
Deferred income tax liabilities:
Property and equipment accumulated tax depreciation and depletion in excess of book under Canadian tax law			(1,012)	(1,459)
Book basis of investment in land development partnerships in excess of tax basis			(1,668)	0
Other			(31)	(4)
Total deferred income tax liabilities			(2,711)	(1,463)
Deferred Tax Liabilities, Net			(204)	(271)
Net deferred income tax liability included in Consolidated Balance Sheets:
Current deferred income tax asset (included in other current assets)			0	178
Deferred income tax liability			(204)	(449)
Valuation allowance, other disclosures
Increase in valuation allowance			2,023
Increase in valuation allowance recognized as income tax expense			1,344
Increase in valuation allowance charged to accumulated other comprehensive loss			679
Alternative minimum tax credit
Tax credit carryforward
Tax credit carryovers			460
Foreign
Tax credit carryforward
Tax credit carryovers			4,028
Valuation allowance, other disclosures
Alberta corporate tax rate	12.00%	10.00%
Canadian statutory tax rate	30.65%	28.75%
Foreign | Canada Revenue Agency
Valuation allowance, other disclosures
Increase in valuation allowance			292	$ 1,028
Federal
Tax credit carryforward
Operating loss carryovers			$ 25,671

INCOME TAXES - Unrecognized Tax

INCOME TAXES - Unrecognized Tax Benefits (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Changes in uncertain tax positions
Balance at the beginning of the period	$ 582	$ 660
Effect of tax positions taken in prior years	0	92
Accrued interest related to tax positions taken	20	38
Lapse of statute	(173)	(174)
Translation adjustments	(52)	(34)
Balance at the end of the period	377	582
Amount of unrecognized tax benefits that if recognized, would impact effective tax rate	377
Accrued interest	$ 35	$ 113

SEGMENT AND GEOGRAPHIC INFORM64

SEGMENT AND GEOGRAPHIC INFORMATION (Details) - USD ($)	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Revenues:
Total before interest income	$ 13,241,000	$ 17,479,000
Interest income	46,000	54,000
Total revenues	13,287,000	17,533,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	1,607,000	3,364,000
Impairment:
Impairment of assets	1,154,000	316,000
Operating profit (loss) (before general and administrative expenses):
Total operating profit (loss)	202,000	10,209,000
Equity in income (loss) of affiliates:
Equity in income of affiliates	2,624,000	1,580,000
General and administrative expenses	(6,361,000)	(8,551,000)
Interest expense	(97,000)	(315,000)
Interest income	46,000	54,000
(Loss) earnings before income taxes	(3,586,000)	2,977,000
Capital Expenditures:
Capital Expenditure	1,940,000	3,715,000
Assets By Segment:
Total assets	31,568,000	41,553,000
Land investment
Equity in income (loss) of affiliates:
Equity in income of affiliates	2,624,000	1,580,000
Intersegment elimination
Revenues:
Total revenues	0	0
Operating Segments | Oil and natural gas
Revenues:
Total before interest income	3,177,000	9,008,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	1,236,000	2,987,000
Impairment:
Impairment of assets	1,154,000	0
Operating profit (loss) (before general and administrative expenses):
Total operating profit (loss)	(2,355,000)	(366,000)
Capital Expenditures:
Capital Expenditure	1,872,000	3,512,000
Assets By Segment:
Total assets	6,323,000	7,298,000
Operating Segments | Land investment
Revenues:
Total before interest income	1,915,000	3,244,000
Operating profit (loss) (before general and administrative expenses):
Total operating profit (loss)	1,915,000	3,244,000
Assets By Segment:
Total assets	4,744,000	7,480,000
Operating Segments | Contract drilling
Revenues:
Total before interest income	2,233,000	4,886,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	251,000	272,000
Operating profit (loss) (before general and administrative expenses):
Total operating profit (loss)	(116,000)	922,000
Capital Expenditures:
Capital Expenditure	66,000	124,000
Assets By Segment:
Total assets	1,438,000	2,338,000
Operating Segments | Residential real estate
Revenues:
Total before interest income	5,700,000	0
Impairment:
Impairment of assets	0	316,000
Operating profit (loss) (before general and administrative expenses):
Total operating profit (loss)	190,000	(316,000)
Assets By Segment:
Total assets	0	5,132,000
Corporate and Other
Revenues:
Total before interest income	216,000	341,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	120,000	105,000
Capital Expenditures:
Capital Expenditure	2,000	79,000
Assets By Segment:
Total assets	3,132,000	3,257,000
Corporate and Other | Cash and cash equivalents
Assets By Segment:
Total assets	15,550,000	8,471,000
Corporate and Other | Restricted cash
Assets By Segment:
Total assets	381,000	7,577,000
Other operating (loss) profit | Corporate and Other
Operating profit (loss) (before general and administrative expenses):
Total operating profit (loss)	96,000	236,000
Gain on sale of assets | Corporate and Other
Operating profit (loss) (before general and administrative expenses):
Total operating profit (loss)	$ 472,000	$ 6,489,000

SEGMENT AND GEOGRAPHIC INFORM65

SEGMENT AND GEOGRAPHIC INFORMATION - GEOGRAPHIC AREAS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Geographic information
Long-lived assets	$ 10,454	$ 15,875
Total revenue (excluding interest income)	13,241	17,479
United States
Geographic information
Long-lived assets	5,187	10,135
Total revenue (excluding interest income)	9,886	8,237
Canada
Geographic information
Long-lived assets	5,267	5,740
Total revenue (excluding interest income)	$ 3,355	$ 9,242

ACCUMULATED OTHER COMPREHENSI66

ACCUMULATED OTHER COMPREHENSIVE (LOSS) INCOME (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Foreign currency translation:
Balance at beginning of period	$ 819	$ 1,692
Change in cumulative translation adjustment before reclassifications	87	(1,625)
Amounts reclassified from accumulated other comprehensive income	0	752
Income taxes	0	0
Net current period other comprehensive income (loss)	87	(873)
Balance at end of the period	906	819
Retirement plans:
Balance at beginning of period	(2,941)	(1,950)
Amortization of net actuarial loss and prior service cost	168	105
Net actuarial loss arising during the period	(2,053)	(1,096)
Income taxes	0	0
Net current period other comprehensive loss	(1,885)	(991)
Balance at end of the period	(4,826)	(2,941)
Accumulated other comprehensive loss, net of taxes	$ (3,920)	$ (2,122)

FAIR VALUE MEASUREMENTS (Detail

FAIR VALUE MEASUREMENTS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Real estate held for sale	$ 0	$ 5,132
Impairment of assets	$ 1,154	316
Fair Value, Inputs, Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Impairment of assets		$ 316

COMMITMENTS AND CONTINGENCIES68

COMMITMENTS AND CONTINGENCIES (Detail) - USD ($)	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Kaupulehu Developments
Commitments and contingencies
Fees to be paid to Nearco	10.40%
Percentage of Increment II receipts to be paid to external real estate counsel for services provided in the negotiation and closing of the Increment II transaction	1.50%
Oil pipeline release [Member]
Commitments and contingencies
Probable environmental remediation costs	$ 2,200,000
Percentage of working interest	58.00%
Insurance deductible	$ 80,000
Accrual for environmental remediation costs	$ 0
Gas leak [Member]
Commitments and contingencies
Percentage of working interest	50.00%
Accrual for environmental remediation costs	$ 200,000
Minimum | Gas leak [Member]
Commitments and contingencies
Probable environmental remediation costs	400,000
Maximum | Gas leak [Member]
Commitments and contingencies
Probable environmental remediation costs	800,000
Lease Agreements [Member]
Commitments and contingencies
Rental expense	404,000	$ 408,000
Minimum rental payments
2,017	261,000
2,018	138,000
2,019	118,000
2,020	118,000
2,021	118,000
Thereafter through 2026	130,000
Total	$ 883,000

INFORMATION RELATING TO THE C69

INFORMATION RELATING TO THE CONSOLIDATED STATEMENTS OF CASH FLOWS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Increase (decrease) from changes in:
Receivables	$ 1,081	$ 324
Other current assets	49	(447)
Accounts payable	(1,456)	(439)
Accrued compensation	(79)	(323)
Other current liabilities	(882)	(687)
Decrease from changes in current assets and liabilities	(1,287)	(1,572)
Supplemental disclosure of cash flow information:
Interest	94	306
Income taxes (refunded) paid, net	(219)	1,812
Supplemental disclosures of cash flow information:
Increase in capital expenditure accruals related to oil and natural gas asset retirement obligations	99	1,234
Oil and natural gas
Supplemental disclosures of cash flow information:
Increase (decrease) in capital expenditure accruals related to oil and natural gas exploration and development	76	(61)
Increase in capital expenditure accruals related to oil and natural gas asset retirement obligations	$ 99	$ 1,234

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details) - Kaupulehu Developments $ in Thousands	12 Months Ended
	Sep. 30, 2016USD ($)lot	Sep. 30, 2015USD ($)lot
Related party transactions
Proceeds received from percentage of sales payments | $	$ 2,255	$ 3,772
KD Kaupulehu, LLLP | Investment in land development partnerships
Related party transactions
Ownership interest acquired	19.60%
Proceeds received from percentage of sales payments | $	$ 2,255	$ 3,772
Increment I [Member] | Phase I | KD Kaupulehu, LLLP | Investment in land development partnerships
Related party transactions
Number of lots sold		6
Increment I [Member] | Phase II | KD Kaupulehu, LLLP | Investment in land development partnerships
Related party transactions
Number of lots sold	3	11
Increment II [Member] | KD Kaupulehu, LLLP | Investment in land development partnerships
Related party transactions
Number of lots sold	1

SUPPLEMENTARY OIL AND NATURAL71

SUPPLEMENTARY OIL AND NATURAL GAS INFORMATION (UNAUDITED) (Details) bbl in Thousands, MMcf in Thousands, $ in Thousands	12 Months Ended
	Sep. 30, 2016USD ($)BoeMMcfbbl	Sep. 30, 2015USD ($)BoeMMcfbbl	Sep. 30, 2016USD ($)Boe	Sep. 30, 2015USD ($)
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Proved undeveloped reserves | Boe			0
Changes in the estimates of net interests in total proved developed reserves of oil and natural gas liquids and natural gas
Balance at the beginning of the period | Boe	1,008,000	2,356,000
Revisions of previous estimates | Boe	(251,000)	(11,000)
Extensions, discoveries and other additions | Boe	70,000	1,000
Acquisitions of reserves | Boe	37,000	140,000
Less sales of reserves | Boe	0	(1,044,000)
Less production | Boe	(166,000)	(434,000)
Balance at the end of the period | Boe	698,000	1,008,000
Capitalized Costs Relating to Oil and Natural Gas Producing Activities
Proved properties			$ 66,044	$ 62,960
Unproved properties			221	145
Total capitalized costs			66,265	63,105
Accumulated depletion and depreciation			61,060	57,460
Net capitalized costs			5,205	5,645
Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development
Acquisition of unproved properties	$ 161	$ 28
Acquisition of proved properties	608	804
Exploration costs	0	0
Development costs	1,103	2,680
Total	1,872	3,512
Additions and revisions to asset retirement obligation included in development costs	99	1,234
Results of Operations for Oil and Natural Gas Producing Activities
Net revenues	3,177	9,008
Production costs	(3,142)	(6,387)
Depletion	(1,236)	(2,987)
Impairment of assets	(1,154)	0
Pre-tax results of operations	(2,355)	(366)
Estimated income tax benefit (expense)	297	(921)
Results of operations	(2,058)	(1,287)
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Abstract]
Future cash inflows			17,259	27,749
Future production costs			(11,951)	(18,468)
Future development costs			(426)	(935)
Future income tax expenses			(1,016)	(2,361)
Future net cash flows			3,866	5,985
10% annual discount for timing of cash flows			(956)	(1,950)
Standardized measure of discounted future net cash flows	4,035	24,147	$ 2,910	$ 4,035
Changes in the Standardized Measure of Discounted Future Net Cash Flows
Beginning of year	4,035	24,147
Sales of oil and natural gas produced, net of production costs	(35)	(2,621)
Net changes in prices and production costs, net of royalties and wellhead taxes	(4,134)	(8,042)
Extensions and discoveries	1,285	1
Net change due to purchases and sales of minerals in place	470	(9,103)
Revisions of previous quantity estimates	(343)	634
Net change in income taxes	98	1,658
Accretion of discount	412	2,021
Other - changes in the timing of future production and other	1,018	(1,009)
Other - net change in Canadian dollar translation rate	104	(3,651)
Net change	(1,125)	(20,112)
End of year	$ 2,910	$ 4,035
OIL & NGL (Bbls)
Changes in the estimates of net interests in total proved developed reserves of oil and natural gas liquids and natural gas
Balance at the beginning of the period | bbl	469	724
Revisions of previous estimates | bbl	(23)	79
Extensions, discoveries and other additions | bbl	54	0
Acquisitions of reserves | bbl	34	46
Less sales of reserves | bbl	0	(237)
Less production | bbl	(84)	(143)
Balance at the end of the period | bbl	450	469
GAS (Mcf)
Changes in the estimates of net interests in total proved developed reserves of oil and natural gas liquids and natural gas
Balance at the beginning of the period | MMcf	3,124	9,465
Revisions of previous estimates | MMcf	(1,320)	(520)
Extensions, discoveries and other additions | MMcf	95	3
Acquisitions of reserves | MMcf	18	543
Less sales of reserves | MMcf	0	(4,679)
Less production | MMcf	(476)	(1,688)
Balance at the end of the period | MMcf	1,441	3,124