Barnwell Industries (BRN) 10-K 16 Dec 15 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2015	Dec. 01, 2015	Mar. 31, 2015
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, 2015
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			$ 9,803
Entity Common Stock, Shares Outstanding		8,277,160
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2015	Sep. 30, 2014
Current assets:
Cash and cash equivalents	$ 8,471	$ 16,104
Restricted cash	7,458	0
Accounts and other receivables, net of allowance for doubtful accounts	2,300	2,910
Investment held for sale	1,192	1,139
Real estate held for sale	5,132	5,448
Other current assets	1,125	919
Total current assets	25,678	26,520
Restricted cash, net of current portion	119	0
Investments	6,288	5,900
Property and equipment, net	9,468	22,350
Total assets	41,553	54,770
Current liabilities:
Accounts payable	2,653	3,453
Accrued capital expenditures	363	519
Accrued incentive and other compensation	560	1,085
Accrued operating and other expenses	1,343	2,464
Billings in excess of costs	569	594
Payable to joint interest owners	428	915
Current portion of long-term debt	3,440	4,449
Current portion of asset retirement obligation	506	978
Other current liabilities	141	66
Total current liabilities	10,003	14,523
Long-term debt	0	6,650
Liability for retirement benefits	5,409	4,266
Asset retirement obligation	6,430	8,185
Deferred income taxes	449	1,201
Total liabilities	$ 22,291	$ 34,825
Commitments and contingencies (Note 16)
Equity:
Common stock, par value $0.50 per share; authorized, 20,000,000 shares: 8,445,060 issued at September 30, 2015 and 2014	$ 4,223	$ 4,223
Additional paid-in capital	1,335	1,315
Retained earnings	17,467	16,204
Accumulated other comprehensive loss, net	(2,122)	(258)
Treasury stock, at cost: 167,900 shares at September 30, 2015 and 2014	(2,286)	(2,286)
Total stockholders’ equity	18,617	19,198
Non-controlling interests	645	747
Total equity	19,262	19,945
Total liabilities and equity	$ 41,553	$ 54,770

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Sep. 30, 2015	Sep. 30, 2014
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, 2015	Sep. 30, 2014
Revenues:
Oil and natural gas	$ 9,008	$ 20,298
Contract drilling	4,886	6,287
Sale of interest in leasehold land, net	3,244	636
Gain on sale of investments	0	3,399
Gas processing and other	395	825
Total revenues	17,533	31,445
Costs and expenses:
Oil and natural gas operating	6,387	8,914
Contract drilling operating	3,692	5,026
General and administrative	8,551	8,026
Depletion, depreciation, and amortization	3,364	6,391
Impairment of real estate held for sale	316	0
Interest expense	315	664
Gain on sales of assets	(6,489)	0
Total costs and expenses	16,136	29,021
Earnings before equity in income (loss) of affiliates and income taxes	1,397	2,424
Equity in income (loss) of affiliates	1,580	(482)
Earnings before income taxes	2,977	1,942
Income tax provision	1,208	604
Net earnings	1,769	1,338
Less: Net earnings attributable to non-controlling interests	506	666
Net Income (Loss) Attributable to Parent	$ 1,263	$ 672
Basic net earnings per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share)	$ 0.15	$ 0.08
Diluted net earnings per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share)	$ 0.15	$ 0.08
Weighted-average number of common shares outstanding:
Basic (in shares)	8,277,160	8,277,160
Diluted (in shares)	8,277,160	8,278,292

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Statement of Comprehensive Income [Abstract]
Net earnings	$ 1,769	$ 1,338
Other comprehensive (loss) income:
Foreign currency translation adjustments, net of taxes of $0	(873)	(2,009)
Retirement plans:
Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	105	16
Net actuarial losses arising during the period, net of taxes of $0	(1,096)	(1,256)
Total other comprehensive loss	(1,864)	(3,249)
Total comprehensive loss	(95)	(1,911)
Less: Comprehensive income attributable to non-controlling interests	506	666
Comprehensive loss attributable to Barnwell Industries, Inc.	$ (601)	$ (2,577)

CONSOLIDATED STATEMENTS OF COM6

CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
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, 2015	Sep. 30, 2014
Cash flows from operating activities:
Net earnings	$ 1,769	$ 1,338
Adjustments to reconcile net earnings to net cash (used in) provided by operating activities:
Depletion, depreciation, and amortization	3,364	6,391
Equity in (income) loss of affiliates	(1,580)	482
Gain on sale of oil and natural gas properties	(6,217)	0
Gain on sale of contract drilling assets	(272)	0
Gain on sale of investments	0	(3,399)
Impairment of real estate held for sale	316	0
Foreign exchange loss (gain)	752	(271)
Imputed interest income on note receivable	(22)	0
Retirement benefits expense	408	245
Accretion of asset retirement obligation	632	624
Deferred income tax benefit	(415)	(707)
Asset retirement obligation payments	(655)	(111)
Share-based compensation benefit	(140)	(380)
Retirement plan contributions	(256)	(356)
Sale of interest in leasehold land, net	(3,244)	(636)
(Decrease) increase from changes in current assets and liabilities	(1,572)	2,349
Net cash (used in) provided by operating activities	(7,132)	5,569
Cash flows from investing activities:
Proceeds from sale of oil and natural gas assets	14,162	13,846
Proceeds from sale of contract drilling assets	368	0
Proceeds from sale of investments	1,145	3,297
Proceeds from sale of interest in leasehold land, net of fees paid	3,244	636
Proceeds from gas over bitumen royalty adjustments	0	15
Payment to acquire oil and natural gas properties	(832)	0
Payment to acquire interest in affiliates	0	(5,140)
Increase in restricted cash from investing activities	(7,300)	0
Capital expenditures	(1,710)	(3,576)
Net cash provided by investing activities	9,077	9,078
Cash flows from financing activities:
Proceeds from long-term debt borrowings	0	5,000
Repayments of long-term debt	(7,659)	(10,541)
Increase in restricted cash from financing activities	(442)	0
Contributions from non-controlling interests	120	215
Distributions to non-controlling interests	(728)	(705)
Net cash used in financing activities	(8,709)	(6,031)
Effect of exchange rate changes on cash and cash equivalents	(869)	(340)
Net (decrease) increase in cash and cash equivalents	(7,633)	8,276
Cash and cash equivalents at beginning of year	16,104	7,828
Cash and cash equivalents at end of year	$ 8,471	$ 16,104

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, 2013	$ 22,320	$ 4,223	$ 1,289	$ 15,532	$ 2,991	$ (2,286)	$ 571
Balance (in shares) at Sep. 30, 2013		8,277,160
Increase (Decrease) in Stockholders' Equity
Contributions from non-controlling interests	215						215
Distributions to non-controlling interests	(705)						(705)
Net earnings	1,338			672			666
Share-based compensation	26		26
Foreign currency translation adjustments, net of taxes of $0	(2,009)				(2,009)
Retirement plans:
Amortization of accumulated other comprehensive loss into net periodic benefit cost, net of taxes of $0	16				16
Net actuarial losses arising during the period, net of taxes of $0	(1,256)				(1,256)
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 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

CONSOLIDATED STATEMENTS OF EQU9

CONSOLIDATED STATEMENTS OF EQUITY (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
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, 2015
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 consists 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. The precise timing for the release of the Dunvegan proceeds held in escrow cannot be determined however based on historical experience we believe it to be less than one year. 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. Real Estate Held for Sale The costs of acquiring land and costs related to development and construction, including interest, property taxes and general and administrative expenses related to the development of land and home construction, are capitalized. Costs that relate to a specific lot or home are assigned to that lot or home while common costs related to multiple lots or homes will be allocated to each in proportion to their anticipated sales value. Real estate held for sale is 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. If economic conditions worsen in the future or if difficult market conditions extend beyond the Company’s expectations resulting in a decrease in the fair value of the aforementioned assets below carrying value, the Company will be required to record an impairment loss. Homebuilding revenue and related profit or loss are generally recognized at the time of the closing of a sale, when title to and possession of the property are transferred to the buyer. Investment Held for Sale Barnwell’s investment in one residential parcel is reported at the lower of the asset carrying value or fair value less costs to sell. The recorded balance is 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, changes in the use of the asset, and ongoing cost of maintenance and improvements of the asset. Changes in these and other assumptions may require impairment charges that may materially impact the Company’s future operating results. If economic conditions worsen in the future or if difficult market conditions extend beyond the Company’s expectations resulting in a decrease in the fair value of the aforementioned asset below carrying value, the Company will be required to record an impairment loss. Investment property is 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 or 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 7). 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. 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 11. 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 $33,000 based on the assets of the plan at September 30, 2015 . 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 February 2013, the FASB issued ASU No. 2013-04, “Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date.” This update provides guidance for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation within the scope of this guidance is fixed at the reporting date, except for obligations addressed within existing guidance in U.S. GAAP. Examples of obligations within this guidance are debt arrangements, other contractual obligations, and settled litigation and judicial rulings. The Company adopted the provisions of this ASU effective October 1, 2014. The adoption of this update did not have a material impact on Barnwell’s consolidated financial statements. In March 2013, the FASB issued ASU No. 2013-05, “Parent’s Accounting for the Cumulative Translation Adjustment upon Derecognition of Certain Subsidiaries or Groups of Assets within a Foreign Entity or of an Investment in a Foreign Entity.” This update provides guidance on releasing cumulative translation adjustments when a reporting entity ceases to have a controlling financial interest in a subsidiary or group of assets that is a nonprofit activity or a business within a foreign entity. In addition, these amendments provide guidance on the release of cumulative translation adjustments in partial sales of equity method investments and in step acquisitions. The Company adopted the provisions of this ASU effective October 1, 2014. The adoption of this update did not have a material impact on Barnwell’s consolidated financial statements. In April 2013, the FASB issued ASU No. 2013-07, “Liquidation Basis of Accounting,” which provides guidance on when and how to apply the liquidation basis of accounting and on what to disclose. The update requires an entity to prepare its financial statements using the liquidation basis of accounting when liquidation is imminent, as defined in the update. The Company adopted the provisions of this ASU effective October 1, 2014. The adoption of this update did not have a material impact on Barnwell’s consolidated financial statements. In July 2013, the FASB issued ASU No. 2013-11, “Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists,” which requires an entity to present an unrecognized tax benefit as a reduction of a deferred tax asset for a net operating loss (“NOL”) carryforward, or similar tax loss or tax credit carryforward, rather than as a liability when (1) the uncertain tax position would reduce the NOL or other carryforward under the tax law of the applicable jurisdiction and (2) the entity intends to use the deferred tax asset for that purpose. The Company adopted the provisions of this ASU effective October 1, 2014. The adoption of this update did not have a material impact on Barnwell’s consolidated financial statements. In November 2014, the FASB issued ASU 2014-17, “Pushdown Accounting,” which provides companies with the option to apply pushdown accounting in its separate financial statements upon occurrence of an event in which an acquirer obtains control of the acquired entity. The election to apply pushdown accounting can be made either in the period in which the change of control occurred or in a subsequent period. If the election is made in a subsequent period, it would be considered a change in accounting principle and treated in accordance with Topic 250, “Accounting Changes and Error Corrections.” The Company adopted the provisions of this ASU on November 18, 2014, as the amendments in the update were effective upon issuance. The adoption of this update did not have a material impact on Barnwell’s consolidated financial statements.

LIQUIDITY

LIQUIDITY	12 Months Ended
	Sep. 30, 2015
LIQUIDITY [Abstract]
LIQUIDITY	LIQUIDITY In September 2015, Barnwell sold its interests in its principal oil and natural gas properties located in the Dunvegan and Belloy areas of Alberta, Canada. Barnwell's net proceeds from the sale, after broker's fees and other closing costs, were $ 14,162,000 of which $ 7,135,000 was withheld in an escrow account for the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes related to the sale. Upon determination by the Canada Revenue Agency of any necessary tax deposits, the escrow agent is to release any such required amount of withheld funds to the Canada Revenue Agency and the remainder to Barnwell. Management believes all necessary Canadian income taxes related to the sale have been paid as of September 30, 2015, however the sufficiency of Canadian income taxes paid and the precise timing for and amount of the release of these funds to Barnwell cannot be determined until formal determination by the Canada Revenue Agency. The sales proceeds received upon closing were used for Canadian income tax payments and repayment of the $4,800,000 outstanding on Barnwell's Canadian revolving credit facility; repaying the credit facility in full. As a result of the sale, our Canadian revolving credit facility was amended on September 30, 2015 to decrease the amount of the borrowing capacity to $ 1,000,000 Canadian dollars, from $ 6,500,000 Canadian dollars, or U.S. $ 747,000 at the September 30, 2015 exchange rate. As of September 30, 2015 , Barnwell had $ 15,675,000 in working capital. Because of the combined impact of declines in oil and natural gas prices, declines in production due to oil and natural gas property sales, and natural declines in production and increasing costs due to the age of Barnwell's properties, Barnwell's oil and natural gas segment is projected to have negative cash flow from operations at current prices and production levels. These factors have also resulted in the significant decrease in the borrowing capacity of our Canadian revolving credit facility. Consequently, Barnwell is reliant upon the release of the Dunvegan sales proceeds held in escrow, the timing of which is uncertain, and land investment segment proceeds from percentage of sales payments and any potential future cash distributions from the Kukio Resort land development partnerships in order to provide sufficient liquidity to fund our future cash needs, including capital expenditures, asset retirement obligations, and general and administrative expenses. Furthermore, even if the release of the Dunvegan sales proceeds held in escrow and land investment segment proceeds provide sufficient liquidity, all or a portion of those proceeds may be needed to fund ongoing operating and general and administrative expenses and asset retirement obligations, in which case such proceeds would not be reinvested. The amount and timing of future land investment segment proceeds from percentage of sales payments and cash distributions from the Kukio Resort land development partnerships are not under our influence or control and are highly uncertain, and the amount of future proceeds may not provide the liquidity required. There is no assurance with regards to the amount of any such future proceeds. Our liquidity issues may force us to drastically curtail existing operations, reduce or delay capital expenditures, or sell assets on less favorable terms. There can be no assurance the Company will be able to secure the sale of any of its assets or realize enough proceeds from such sales to fund its operations or to otherwise resolve its liquidity issues. Such issues could have a material adverse impact on our business, financial condition and results of operations. If liquidity issues continue beyond one year and are such that the Company is not able to sufficiently reinvest its restricted cash, the Company's ability to continue as a going concern in the longer term will become questionable.

EARNINGS PER COMMON SHARE

EARNINGS PER COMMON SHARE	12 Months Ended
	Sep. 30, 2015
Earnings Per Share [Abstract]
EARNINGS PER COMMON SHARE	EARNINGS 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 and 807,250 shares of common stock were excluded from the computation of diluted shares for fiscal years 2015 and 2014 , respectively, 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, 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 Year ended September 30, 2014 Net Earnings Shares Per-Share (Numerator) (Denominator) Amount Basic net earnings per share $ 672,000 8,277,160 $ 0.08 Effect of dilutive securities - common stock options — 1,132 Diluted net earnings per share $ 672,000 8,278,292 $ 0.08

SHARE-BASED PAYMENTS

SHARE-BASED PAYMENTS	12 Months Ended
	Sep. 30, 2015
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, 2015 2014 Share-based compensation benefit $ (140,000 ) $ (380,000 ) Income tax effect $ — $ — Share-based compensation benefit recognized in earnings for the years ended September 30, 2015 and 2014 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, 2015 and 2014 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, 2015 , 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, 2015 , there was $24,000 of total unrecognized compensation cost related to nonvested share options. That cost is expected to be recognized over 2.2 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, 2014 through September 30, 2015 is presented below: Options Shares Weighted- Weighted- Aggregate Outstanding at October 1, 2014 90,000 $ 6.75 Granted — Exercised — Expired/Forfeited (60,000 ) 8.62 Outstanding at September 30, 2015 30,000 $ 3.01 8.2 $ — Exercisable at September 30, 2015 7,500 $ 3.01 8.2 $ — Total share-based compensation expense for equity-classified awards vested in the years ended September 30, 2015 and 2014 was $20,000 and $26,000 , 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, 2015 2014 Expected volatility range 51.5% to 61.6% 29.0% to 57.2% Weighted-average volatility 52.4% 45.4% Expected dividends None None Expected term (in years) 2.2 to 8.2 0.2 to 9.2 Risk-free interest rate 0.6% to 1.9% 0.1% to 2.5% 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, 2014 through September 30, 2015 is presented below: Options Shares Weighted- Weighted- Aggregate Outstanding at October 1, 2014 747,250 $ 8.15 Granted — Exercised — Expired/Forfeited (156,000 ) 8.80 Outstanding at September 30, 2015 591,250 $ 7.98 3.6 $ — Exercisable at September 30, 2015 568,750 $ 8.18 3.4 $ — The following table summarizes the components of the total share-based compensation for liability-classified awards: Year ended September 30, 2015 2014 Due to vesting $ 10,000 $ 21,000 Due to remeasurement (170,000 ) (427,000 ) Total share-based compensation benefit for liability-based awards $ (160,000 ) $ (406,000 )

ACCOUNTS RECEIVABLE AND CONTRAC

ACCOUNTS RECEIVABLE AND CONTRACT COSTS	12 Months Ended
	Sep. 30, 2015
Receivables [Abstract]
ACCOUNTS RECEIVABLE AND CONTRACT COSTS	ACCOUNTS RECEIVABLE AND CONTRACT COSTS Accounts receivable are net of allowances for doubtful accounts of $23,000 and $34,000 as of September 30, 2015 and 2014 , respectively. Included in accounts receivable are contract retainage balances of $257,000 and $202,000 as of September 30, 2015 and 2014 , respectively. The retainage balance as of September 30, 2015 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, 2015 2014 Costs incurred on uncompleted contracts $ 1,890,000 $ 6,049,000 Estimated earnings 226,000 472,000 2,116,000 6,521,000 Less billings to date 2,503,000 7,094,000 $ (387,000 ) $ (573,000 ) Costs and estimated earnings on uncompleted contracts are included in the Consolidated Balance Sheets as follows: September 30, 2015 2014 Costs and estimated earnings in excess of billings on uncompleted contracts (included in other current assets) $ 182,000 $ 21,000 Billings in excess of costs and estimated earnings on uncompleted contracts (569,000 ) (594,000 ) $ (387,000 ) $ (573,000 )

REAL ESTATE HELD FOR SALE

REAL ESTATE HELD FOR SALE	12 Months Ended
	Sep. 30, 2015
Real Estate [Abstract]
REAL ESTATE HELD FOR SALE	REAL ESTATE HELD FOR SALE Kaupulehu 2007 currently owns one luxury residence that is 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.

INVESTMENTS

INVESTMENTS	12 Months Ended
	Sep. 30, 2015
Investments, All Other Investments [Abstract]
INVESTMENTS	INVESTMENTS A summary of Barnwell’s non-current investments is as follows: September 30, 2015 2014 Investment in Kukio Resort land development partnerships $ 6,238,000 $ 4,658,000 Investment in residential parcel — 1,192,000 Investment in leasehold land interest – Lot 4C 50,000 50,000 Total non-current investments $ 6,288,000 $ 5,900,000 Investment in residential parcels At September 30, 2015 , Kaupulehu 2007 owned one residential parcel 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, which is classified as a current asset and included in "Investment held for sale" in the Consolidated Balance Sheet at September 30, 2015. A second residential parcel, which was included in investment held for sale at September 30, 2014, was sold in October 2014 for $ 1,250,000 for a nominal loss which is included in "General and administrative" expenses in the Consolidated Statements of Operations. 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 28 lots remain to be sold at Kaupulehu Increment I, two ocean front parcels in Kaupulehu Increment II are currently being developed for eventual sale, and one lot remains at Maniniowali, as well as from commission on real estate sales by the real estate sales office. The limited liability limited partnership agreements provide for a priority return of Barnwell’s investment prior to profit distributions, however there is no assurance as to the timing or amount of any future cash distributions from the partnerships. Net profits, losses and cash flows of the partnerships are allocated to Barnwell and the other partners at varying percentages based on whether the initial and any additional capital contributions plus any preferred returns due to contributing partners have been repaid to the investors. Barnwell’s share of the income of its equity affiliates was $1,580,000 for the year ended September 30, 2015 , and the share of the loss of its equity affiliates was $482,000 for the year ended September 30, 2014 . 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 $390,000 as of September 30, 2015 , 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 adjustment for the year ended September 30, 2015 was an $82,000 increase in equity in income of affiliates, and the basis difference adjustment for the year ended September 30, 2014 was inconsequential. 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, 2015 totaled approximately $4,144,000 and relate to certain construction contracts of KD I. If any such performance bonds are called, we may be obligated to reimburse the issuer of the performance bond as Barnwell, KD I, and certain other partners are jointly and severally liable, however we believe that it is remote that a material amount of any currently outstanding performance bonds will be called. Performance bonds do not have stated expiration dates. Rather, the performance bonds are released as the underlying performance is completed. As of September 30, 2015 , Barnwell’s maximum loss exposure as a result of its investment in the Kukio Resort land development partnerships was approximately $10,382,000 , consisting of the carrying value of the investment of $6,238,000 and $4,144,000 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 November 27, 2013 - September 30, 2015 September 30, 2014 Revenue $ 29,898,000 $ 5,114,000 Gross profit $ 13,594,000 $ 2,058,000 Net income (loss) $ 7,500,000 $ (1,614,000 ) 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 18). 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 2015 , 17 single-family lots in Increment I were sold bringing the total amount of gross proceeds from single-family lot sales through September 30, 2015 to $199,000,000 . The following table summarizes the Increment I percentage of sales payment revenues received from KD I: Year ended September 30, 2015 2014 Sale of interest in leasehold land: Proceeds $ 3,772,000 $ 740,000 Fees (528,000 ) (104,000 ) Revenues – sale of interest in leasehold land, net $ 3,244,000 $ 636,000 As of September 30, 2015 , all of the 38 single-family lots in Phase I of Increment I have been sold by KD I. Forty-two single-family lots are planned for Phase II of Increment I, for a total of 80 single-family lots planned for Increment I. A portion of the 42 single-family lots in Phase II of Increment I have been completed and 14 of the lots have been sold as of September 30, 2015 . Two residential lots approximately two to three acres in size fronting the ocean are also currently being developed within Increment II by KD II, and the remaining acreage within Increment II is not yet under development. Kaupulehu Developments is entitled to receive future payments from KD II based on a percentage of the sales prices of the residential lots or units, as well as additional payments after the members of KD II have received distributions equal to the capital they invested in the project. It is uncertain when or if KD II will develop the other areas of Increment II. 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. The lease terminates in December 2025. Investment in joint ventures On July 25, 2014, Kaupulehu Investors, LLC, an entity in which Barnwell has an 80% interest, received $3,297,000 for the sale of its 1.5% passive minority interests in the Hualalai Resort and Kona Village Resort to an independent third party, with an additional $102,000 received in fiscal 2015 relating to the sale of an interest in a related utility. Kaupulehu Investors, LLC previously wrote off its investment in the Hualalai Resort due to its other-than-temporary decline in fair value and in Kona Village Resort as a result of the March 2011 tsunami which caused the resort to shut down indefinitely. As these previous write downs reduced the carrying value of the investments to zero , Barnwell recognized a $3,399,000 gain on this transaction in the year ended September 30, 2014, which is reflected in “Gain on sale of investments” in the Consolidated Statements of Operations, of which $679,000 relates to non-controlling interests. Kaupulehu Investors, LLC’s capital and operating cash call investments in the Hualalai Resort and the Kona Village Resort prior to the sale totaled $3,193,000 .

OIL AND NATURAL GAS PROPERTIES

OIL AND NATURAL GAS PROPERTIES	12 Months Ended
	Sep. 30, 2015
Extractive Industries [Abstract]
OIL AND NATURAL GAS PROPERTIES	OIL AND NATURAL GAS PROPERTIES 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 15 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 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 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 15 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 Statements 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 final determination of the customary adjustments to the purchase price will be made by the parties approximately 180 days after the September 2015 closing date. From Barnwell's net proceeds, $7,135,000 was withheld in an escrow account for the Canada Revenue Agency for potential amounts due for Barnwell’s Canadian income taxes related to the sale which is included in “Restricted cash” on the Consolidated Balance Sheets. Upon determination by the Canada Revenue Agency of any necessary tax deposits, the escrow agent is to release any such required amount of withheld funds to the Canada Revenue Agency and the remainder to Barnwell. The relationship between capitalized costs and proved reserves of the sold property and retained properties is 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 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 ) 2014 Dispositions In February 2014, Barnwell entered into a purchase and sale agreement with an independent third party and sold its interests in oil properties located in the Mantario area of Saskatchewan, Canada. The sales price per the agreement was adjusted for customary purchase price adjustments to $2,726,000 in order to, among other things, reflect an economic effective date of January 1, 2014. In April 2014, Barnwell entered into a purchase and sale agreement with an independent third party and sold its interests in oil and natural gas properties located in the Chauvin, Cessford and Rat Creek areas of Alberta, Canada. The sales price per the agreement was adjusted for preliminary purchase price adjustments to approximately $4,581,000 in order to, among other things, reflect an economic effective date of March 1, 2014. In May 2014, Barnwell entered into a purchase and sale agreement with an independent third party and sold its interests in certain oil and natural gas properties located in the Boundary Lake area of Alberta and British Columbia, Canada. The sales price per the agreement was adjusted for preliminary purchase price adjustments to approximately $6,120,000 in order to, among other things, reflect an economic effective date of January 1, 2014. During the year ended September 30, 2014 , Barnwell also sold miscellaneous oil and natural gas properties for proceeds of $692,000 . Total proceeds received from sales of oil and natural gas properties during the year ended September 30, 2014 was $13,846,000 . No gain or loss was recognized in fiscal 2014 as these unplanned sales to multiple counterparties in unrelated transactions did not individually result in a significant alteration of the relationship between capitalized costs and proved reserves. Pro forma information is not presented for fiscal 2014 dispositions as the pro forma results, individually and in the aggregate, would not be materially different from the information presented in the Consolidated Statements of Operations.

PROPERTY AND EQUIPMENT AND ASSE

PROPERTY AND EQUIPMENT AND ASSET RETIREMENT OBLIGATION	12 Months Ended
	Sep. 30, 2015
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, 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 Estimated Gross Accumulated Net At September 30, 2014: Land $ 863,000 $ — $ 863,000 Oil and natural gas properties (full cost accounting) 209,702,000 (191,478,000 ) 18,224,000 Drilling rigs and equipment 3 – 10 years 6,759,000 (5,754,000 ) 1,005,000 Offices 40 years 2,420,000 (384,000 ) 2,036,000 Other property and equipment 3 – 17 years 3,279,000 (3,057,000 ) 222,000 Total $ 223,023,000 $ (200,673,000 ) $ 22,350,000 See Note 8 for discussion of acquisitions and divestitures of oil and natural gas properties in fiscal 2015 and 2014 . 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, 2015 2014 Asset retirement obligation as of beginning of year $ 9,163,000 $ 7,520,000 Obligations incurred on new wells drilled or acquired 316,000 105,000 Liabilities associated with properties sold (2,013,000 ) (718,000 ) Revision of estimated obligation 918,000 2,437,000 Accretion expense 632,000 624,000 Payments (655,000 ) (111,000 ) Foreign currency translation adjustment (1,425,000 ) (694,000 ) Asset retirement obligation as of end of year 6,936,000 9,163,000 Less current portion (506,000 ) (978,000 ) Asset retirement obligation, long-term $ 6,430,000 $ 8,185,000 Asset retirement obligations were reduced by $2,013,000 and $718,000 in fiscal 2015 and 2014 , respectively, for those obligations that were assumed by purchasers of Barnwell's oil and natural gas properties. Barnwell recognized an additional $918,000 and $2,437,000 of abandonment and reclamation capitalized costs and liabilities in fiscal 2015 and 2014 , respectively, 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. Additionally, in the prior year, a portion of the revision in estimate was related to the Inactive Well Compliance Program, which was introduced by the Alberta Energy Regulator in July 2014, which resulted in the acceleration of expenditures to suspend and/or abandon long-term inactive wells.

LONG-TERM DEBT

LONG-TERM DEBT	12 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
LONG-TERM DEBT	LONG-TERM DEBT A summary of Barnwell’s long-term debt is as follows: September 30, 2015 2014 Canadian revolving credit facility $ — $ 7,000,000 Real estate loan 3,440,000 4,099,000 3,440,000 11,099,000 Less current portion (3,440,000 ) (4,449,000 ) Total long-term debt $ — $ 6,650,000 Canadian revolving credit facility On April 10, 2015, Barnwell’s revolving credit facility at Royal Bank of Canada was amended and renewed. The amendment, among other things, provided for a decrease in the aggregate principal amount of the credit facility to $6,500,000 Canadian dollars from $11,800,000 Canadian dollars. This reduction in the borrowing capacity was largely due to a tightening credit market for oil and natural gas companies due to the uncertainty of future oil and natural gas prices and significant declines in Royal Bank of Canada’s forecast of oil and natural gas prices. On September 30, 2015, the credit facility was further reduced by the bank to $1,000,000 Canadian dollars, or U.S. $747,000 at the September 30, 2015 exchange rate, 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. The other material terms of the credit facility remain unchanged. Borrowings under this facility were $0 at September 30, 2015 and unused credit available was $713,000 after consideration of issued letters of credit totaling $34,000 . 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. During the year ended September 30, 2014, Barnwell repaid $5,000,000 of the credit facility and realized foreign currency transaction gains of $271,000 as a result of the repayment of U.S. dollar denominated debt using Canadian dollars, which is included in "Gas processing and other" revenues on the Consolidated Statements of Operations. The Canadian revolving facility is available in U.S. dollars at LIBOR plus 2.50% , at Royal Bank of Canada’s U.S. base rate plus 1.50% , or in Canadian dollars at Royal Bank of Canada’s prime rate plus 1.50% . A standby fee of 0.625% per annum is charged on the unused facility balance. Under the financing agreement with Royal Bank of Canada, the credit facility is reviewed annually, with the next review planned for April 2016. Subject to that review, the credit facility may be renewed for one year with no required debt repayments or converted to a two-year term loan by the bank. If the credit facility is converted to a two year term loan, Barnwell has agreed to the following repayment schedule of the then outstanding loan balance: first year of the term period – 20% ( 5% per quarter), and in the second year of the term period – 80% ( 5% per quarter for the first three quarters and 65% in the final quarter). The obligations under the Canadian revolving credit facility are secured by substantially all of the assets of Barnwell of Canada, Limited. The credit facility subjects Barnwell to certain customary affirmative covenants, including the delivery of financial statements and annual appraisals of certain oil and natural gas properties. In addition, the credit facility contains customary negative covenants, including, but not limited to, restrictions on the ability of Barnwell to, among other things, merge with or acquire other entities, incur new liens, incur additional indebtedness, or sell certain oil and natural gas properties or petroleum and natural gas reserves (other than the sale of production from such oil and natural gas properties in the ordinary course of business). The credit facility also contains provisions concerning customary events of default, including, without limitation, payment defaults, breaches of representations and warranties, covenant defaults, and certain events of bankruptcy and insolvency. If an event of default occurs and is continuing, any amounts due under the credit facility may be accelerated, and the rights and remedies of Royal Bank of Canada under the credit facility may be exercised, including rights with respect to the collateral securing Barnwell’s obligations thereunder. Barnwell has the option to change the currency denomination and interest rate applicable to the loan at periodic intervals during the term of the loan. The facility is guaranteed by Barnwell and is collateralized by a general security agreement on all of the assets of Barnwell’s oil and natural gas segment. No compensating bank balances are required for this credit facility. Real estate loan Barnwell, together with its real estate joint venture, Kaupulehu 2007, has a non-revolving real estate loan with a Hawaii bank. In January 2015, the loan was amended from monthly principal and interest payments to monthly interest-only payments effective February 1, 2015. All other terms of the loan remained unchanged. The principal balance and any accrued interest will be due and payable on April 1, 2018. The interest rate adjusts each April for the remaining term of the loan to the lender’s then prevailing interest rate for similarly priced commercial mortgage loans or a floating rate equal to the lender’s base rate. The interest rate at September 30, 2015 was 3.59% . The loan is collateralized by, among other things, a first mortgage on Kaupulehu 2007’s lots together with all improvements thereon. Kaupulehu 2007 will be required to make a principal payment upon the sale of the house or the residential parcel in the amount of the net sales proceeds of the house or residential parcel; the loan agreement defines net sales proceeds as the gross sales proceeds for the house or residential parcel, less reasonable commissions and normal closing costs. In October 2014, Kaupulehu 2007 sold one of its residential parcels for net proceeds of $1,145,000 and, with approval from the bank, $473,000 was used to pay down the principal balance of the loan, $200,000 was deposited into a cost reserve account and is included in "Restricted cash" on the accompanying Consolidated Balance Sheets at September 30, 2015 , and the remaining proceeds were released to Barnwell. The loan agreement contains provisions requiring us to maintain compliance with certain covenants including a consolidated debt service coverage ratio and a consolidated total liabilities to tangible net worth ratio. However, in June 2015, the bank suspended these financial covenants in exchange for an interest reserve account which had a balance of $242,000 at September 30, 2015 and is included in "Restricted cash" on the accompanying Consolidated Balance Sheets. These financial covenants will remain suspended as long as there are sufficient funds in the interest reserve account. The home and residential lot collateralizing the loan are currently available for sale; therefore, the entire balance outstanding at September 30, 2015 under the term loan has been classified as a current liability. Combined Maturities Based on the assumption that Kaupulehu 2007’s home is sold during fiscal 2016, the Company's real estate loan is assumed to become due and payable in full in fiscal 2016.

RETIREMENT PLANS

RETIREMENT PLANS	12 Months Ended
	Sep. 30, 2015
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, 2015 2014 2015 2014 2015 2014 Change in Projected Benefit Obligation: Benefit obligation at beginning of year $ 8,299,000 $ 6,858,000 $ 1,767,000 $ 1,322,000 $ 1,227,000 $ 1,073,000 Service cost 256,000 156,000 62,000 47,000 — 12,000 Interest cost 356,000 322,000 77,000 67,000 52,000 54,000 Actuarial loss 110,000 1,186,000 — 337,000 40,000 88,000 Benefits paid (326,000 ) (213,000 ) (6,000 ) (6,000 ) — — Administrative expenses paid (12,000 ) (10,000 ) — — — — Benefit obligation at end of year 8,683,000 8,299,000 1,900,000 1,767,000 1,319,000 1,227,000 Change in Plan Assets: Fair value of plan assets at beginning of year 7,022,000 6,111,000 — — — — Actual return on plan assets (446,000 ) 784,000 — — — — Employer contributions 250,000 350,000 6,000 6,000 — — Benefits paid (326,000 ) (213,000 ) (6,000 ) (6,000 ) — — Administrative expenses paid (12,000 ) (10,000 ) — — — — Fair value of plan assets at end of year 6,488,000 7,022,000 — — — — Funded status $ (2,195,000 ) $ (1,277,000 ) $ (1,900,000 ) $ (1,767,000 ) $ (1,319,000 ) $ (1,227,000 ) Pension SERP Postretirement Medical September 30, 2015 2014 2015 2014 2015 2014 Amounts recognized in the Consolidated Balance Sheets: Current liabilities $ — $ — $ (5,000 ) $ (5,000 ) $ — $ — Noncurrent liabilities (2,195,000 ) (1,277,000 ) (1,895,000 ) (1,762,000 ) (1,319,000 ) (1,227,000 ) Net amount $ (2,195,000 ) $ (1,277,000 ) $ (1,900,000 ) $ (1,767,000 ) $ (1,319,000 ) $ (1,227,000 ) Amounts recognized in accumulated other comprehensive (loss) income: Net actuarial loss (gain) $ 3,038,000 $ 2,068,000 $ 506,000 $ 530,000 $ (110,000 ) $ (155,000 ) Prior service cost (credit) 77,000 81,000 (76,000 ) (80,000 ) — — Accumulated other comprehensive loss (income) $ 3,115,000 $ 2,149,000 $ 430,000 $ 450,000 $ (110,000 ) $ (155,000 ) Barnwell estimates that it will make approximately $750,000 in contributions to the Pension Plan during fiscal 2016 . The SERP and Postretirement Medical plans are unfunded and Barnwell will fund benefits when payments are made. Barnwell does not expect to make any benefit payments under the Postretirement Medical plan during fiscal 2016 and expected payments under the SERP for fiscal 2016 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 loss in fiscal 2015 was primarily due to actual investment returns being lower than the assumed rate of return. The change in actuarial (gain) loss for all plans in fiscal 2014 was primarily due to the adoption of new mortality tables issued by the Society of Actuaries in October 2014 which increased life expectancy assumptions and changes in the discount rates. 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, 2015 2014 2015 2014 2015 2014 Assumptions used to determine fiscal year-end benefit obligations: Discount rate 4.25% 4.25% 4.25% 4.25% 4.25% 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% 5.00% 4.25% 5.00% 4.25% 5.00% 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, 2015 2014 2015 2014 2015 2014 Net periodic benefit cost for the year: Service cost $ 256,000 $ 156,000 $ 62,000 $ 47,000 $ — $ 12,000 Interest cost 356,000 322,000 77,000 67,000 52,000 54,000 Expected return on plan assets (500,000 ) (429,000 ) — — — — Amortization of prior service cost (credit) 5,000 5,000 (5,000 ) (5,000 ) — 12,000 Amortization of net actuarial loss (gain) 86,000 20,000 24,000 5,000 (5,000 ) (21,000 ) Net periodic benefit cost $ 203,000 $ 74,000 $ 158,000 $ 114,000 $ 47,000 $ 57,000 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 (gain) 135,000 19,000 (5,000 ) $ 140,000 $ 14,000 $ (5,000 ) 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 $7,420,000 and $7,217,000 at September 30, 2015 and 2014 , respectively. The accumulated benefit obligation for the SERP was $1,458,000 and $1,349,000 at September 30, 2015 and 2014 , respectively. The benefits expected to be paid under the retirement plans as of September 30, 2015 are as follows: Pension SERP Postretirement Expected Benefit Payments: Fiscal year ending September 30, 2016 $ 207,000 $ 5,000 $ — Fiscal year ending September 30, 2017 $ 268,000 $ 4,000 $ — Fiscal year ending September 30, 2018 $ 288,000 $ 3,000 $ 25,000 Fiscal year ending September 30, 2019 $ 275,000 $ 3,000 $ 28,000 Fiscal year ending September 30, 2020 $ 383,000 $ 71,000 $ 19,000 Fiscal years ending September 30, 2021 through 2025 $ 2,380,000 $ 568,000 $ 296,000 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, 2015 2014 Health care cost trend rates assumed for next year 8.0% 7.5% Ultimate cost trend rate 5.0% 5.0% Year that the rate reaches the ultimate trend rate 2028 2020 An 8.0% annual rate of increase in the per capita cost of covered health care benefits was assumed for fiscal 2015 . 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 $ 267,000 $ (212,000 ) 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, 2015 . The Company’s year-end target allocation, by asset category, and the actual asset allocations were as follows: Target September 30, Asset Category Allocation 2015 2014 Cash and other 0% - 30% 9% 12% Fixed income securities 20% - 60% 22% 20% Equity securities 30% - 70% 69% 68% 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 $ 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 $ — $ — Fair Value Measurements Using: Carrying Quoted Significant Significant Financial Assets: Cash $ 817,000 $ 817,000 $ — $ — Corporate bonds 660,000 660,000 — — Fixed income exchange-traded funds 521,000 521,000 — — Preferred securities 232,000 232,000 — — Equity securities exchange-traded funds 758,000 758,000 — — Equities 4,034,000 4,034,000 — — Total $ 7,022,000 $ 7,022,000 $ — $ —

INCOME TAXES

INCOME TAXES	12 Months Ended
	Sep. 30, 2015
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, 2015 2014 United States $ 1,011,000 $ (629,000 ) Canada 1,460,000 1,905,000 $ 2,471,000 $ 1,276,000 The components of the income tax provision (benefit) related to the above income (loss) are as follows: Year ended September 30, 2015 2014 Current (benefit) provision: United States – Federal Before operating loss carryforwards $ — $ 886,000 Benefit of operating loss carryforwards — (886,000 ) After operating loss carryforwards — — United States – State 94,000 (1,000 ) 94,000 (1,000 ) Canadian 1,529,000 1,312,000 Total current 1,623,000 1,311,000 Deferred benefit: United States (90,000 ) — Canadian (325,000 ) (707,000 ) Total deferred (415,000 ) (707,000 ) $ 1,208,000 $ 604,000 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. As a result of significant declines in prices and limited availability of funds for oil and natural gas capital expenditures, Barnwell has determined that it is not more likely than not that all of our oil and natural gas deferred tax assets under Canadian tax law are realizable. Included in the Canadian deferred income tax benefit for the year ended September 30, 2015 was a $1,028,000 charge to deferred income taxes for the valuation allowance necessary for the portion of Canadian tax law deferred tax assets that may not be realizable. There was no such valuation allowance recorded in the prior year. 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 in the current year periods include the aforementioned valuation allowance for a portion of deferred tax assets under Canadian tax law. A reconciliation between the reported income tax provision and the amount computed by multiplying the earnings attributable to Barnwell before income taxes by the U.S. federal tax rate of 35% is as follows: Year ended September 30, 2015 2014 Tax provision computed by applying statutory rate $ 865,000 $ 447,000 Increase in the valuation allowance - U.S. federal and Canadian tax law 1,653,000 584,000 Additional effect of the foreign tax provision on the total tax provision (1,243,000 ) (467,000 ) Other (67,000 ) 40,000 $ 1,208,000 $ 604,000 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, 2015 2014 Deferred income tax assets: U.S. tax effect of deferred Canadian taxes $ 91,000 $ 248,000 Foreign tax credit carryover 4,661,000 3,023,000 Alternative minimum tax credit carryover 460,000 460,000 U.S. federal net operating loss carryover 4,440,000 4,017,000 Tax basis of investment in land and residential real estate in excess of book basis 1,115,000 1,842,000 Property and equipment accumulated tax depreciation and depletion in excess of book under U.S. tax law 4,494,000 4,069,000 Liabilities accrued for books but not for tax under U.S. tax law 4,423,000 5,112,000 Liabilities accrued for books but not for tax under Canadian tax law 2,149,000 2,731,000 Other 746,000 2,098,000 Total gross deferred tax assets 22,579,000 23,600,000 Less valuation allowance (21,387,000 ) (20,869,000 ) Net deferred income tax assets 1,192,000 2,731,000 Deferred income tax liabilities: Property and equipment accumulated tax depreciation and depletion in excess of book under Canadian tax law (1,459,000 ) (3,460,000 ) Other (4,000 ) (94,000 ) Total deferred income tax liabilities (1,463,000 ) (3,554,000 ) Net deferred income tax liability $ (271,000 ) $ (823,000 ) Net deferred income tax liability is included in the Consolidated Balance Sheets as follows: September 30, 2015 2014 Current deferred income tax asset (included in other current assets) $ 178,000 $ 378,000 Deferred income tax liability (449,000 ) (1,201,000 ) Net deferred income tax liability $ (271,000 ) $ (823,000 ) The total valuation allowance increased $518,000 for the year ended September 30, 2015 . The increase was due to the aforementioned valuation allowance necessary for the portion of Canadian tax law deferred tax assets that may not be realizable, and an increase in the valuation allowance for deferred tax assets under U.S. federal tax law primarily related to an increase in foreign tax credit carryovers and U.S. federal net operating loss carryovers that are not more likely than not to have a future tax benefit. The increase was partially offset by a decrease in the valuation allowance due to the lapsing of certain state net operating loss carryovers for which a full valuation allowance had been provided. Of the total net increase in the valuation allowance for fiscal 2015 , $307,000 was recognized as income tax expense and $211,000 was charged to accumulated other comprehensive loss. Net deferred tax assets at September 30, 2015 of $1,192,000 consists of the portion of Canadian deferred tax assets related to liabilities accrued for book purposes but not for Canadian tax purposes for which it is more likely than not that the related future Canadian income tax deductions will be realizable. At September 30, 2015 , Barnwell had foreign tax credit carryovers, alternative minimum tax credit carryovers, and U.S. federal net operating loss carryovers totaling $4,661,000 , $460,000 and $13,060,000 , respectively. All three items were fully offset by valuation allowances at September 30, 2015 . The net operating loss carryovers expire in fiscal years 2032-2035, and the foreign tax credit carryovers expire in fiscal years 2018-2025. 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, 2015 2014 Balance at beginning of year $ 660,000 $ 704,000 Effect of tax positions taken in prior years 92,000 — Accrued interest related to tax positions taken 38,000 14,000 Lapse of statute (174,000 ) — Translation adjustments (34,000 ) (58,000 ) Balance at end of year $ 582,000 $ 660,000 The total amount of unrecognized tax benefits at September 30, 2015 that, if recognized, would impact the effective tax rate was $582,000 . Included in the liability for unrecognized tax benefits at September 30, 2015 and 2014 , is accrued interest of $113,000 and $92,000 , 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, 2015 . Included below is a summary of the tax years, by jurisdiction, that remain subject to examination by taxing authorities at September 30, 2015 : Jurisdiction Fiscal Years Open U.S. federal 2012 – 2014 Various U.S. states 2012 – 2014 Canada federal 2008 – 2014 Various Canadian provinces 2008 – 2014

SEGMENT AND GEOGRAPHIC INFORMAT

SEGMENT AND GEOGRAPHIC INFORMATION	12 Months Ended
	Sep. 30, 2015
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, 2015 2014 Revenues: Oil and natural gas $ 9,008,000 $ 20,298,000 Land investment 3,244,000 636,000 Contract drilling 4,886,000 6,287,000 Other 341,000 796,000 Total before gain on sale of investments and interest income 17,479,000 28,017,000 Gain on sale of investments — 3,399,000 Interest income 54,000 29,000 Total revenues $ 17,533,000 $ 31,445,000 Depletion, depreciation, and amortization: Oil and natural gas $ 2,987,000 $ 5,968,000 Contract drilling 272,000 309,000 Other 105,000 114,000 Total depletion, depreciation, and amortization $ 3,364,000 $ 6,391,000 Impairment: Residential real estate $ 316,000 $ — Operating (loss) profit (before general and administrative expenses): Oil and natural gas $ (366,000 ) $ 5,416,000 Land investment 3,244,000 636,000 Contract drilling 922,000 952,000 Residential real estate (316,000 ) — Other 236,000 682,000 Gain on sales of assets 6,489,000 — Total operating profit 10,209,000 7,686,000 Equity in income (loss) of affiliates: Land investment 1,580,000 (482,000 ) General and administrative expenses (8,551,000 ) (8,026,000 ) Interest expense (315,000 ) (664,000 ) Gain on sale of investments — 3,399,000 Interest income 54,000 29,000 Earnings before income taxes $ 2,977,000 $ 1,942,000 Capital Expenditures: Year ended September 30, 2015 2014 Oil and natural gas $ 3,512,000 $ 4,824,000 Contract drilling 124,000 48,000 Other 79,000 51,000 Total $ 3,715,000 $ 4,923,000 Assets By Segment: September 30, 2015 2014 Oil and natural gas (1) $ 7,298,000 $ 20,951,000 Land investment (2) 7,480,000 7,039,000 Contract drilling (2) 2,338,000 1,849,000 Residential real estate (2) 5,132,000 5,448,000 Other: Cash and cash equivalents 8,471,000 16,104,000 Restricted cash 7,577,000 — Corporate and other 3,257,000 3,379,000 Total $ 41,553,000 $ 54,770,000 ______________ (1) Primarily located in the province of Alberta, Canada. (2) Located in Hawaii. Long-Lived Assets By Geographic Area: September 30, 2015 2014 United States $ 10,135,000 $ 9,884,000 Canada 5,740,000 18,366,000 Total $ 15,875,000 $ 28,250,000 Revenue By Geographic Area: Year ended September 30, 2015 2014 United States $ 8,237,000 $ 6,924,000 Canada 9,242,000 21,093,000 Total (excluding gain on sale of investments and interest income) $ 17,479,000 $ 28,017,000

ACCUMULATED OTHER COMPREHENSIVE

ACCUMULATED OTHER COMPREHENSIVE (LOSS) INCOME	12 Months Ended
	Sep. 30, 2015
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, 2015 2014 Foreign currency translation: Beginning accumulated foreign currency translation $ 1,692,000 $ 3,701,000 Change in cumulative translation adjustment before reclassifications (1,625,000 ) (1,738,000 ) Amounts reclassified from accumulated other comprehensive income 752,000 (271,000 ) Income taxes — — Net current period other comprehensive loss (873,000 ) (2,009,000 ) Ending accumulated foreign currency translation 819,000 1,692,000 Retirement plans: Beginning accumulated retirement plans benefit cost (1,950,000 ) (710,000 ) Amortization of net actuarial loss and prior service cost 105,000 16,000 Net actuarial loss arising during the period (1,096,000 ) (1,256,000 ) Income taxes — — Net current period other comprehensive loss (991,000 ) (1,240,000 ) Ending accumulated retirement plans benefit cost (2,941,000 ) (1,950,000 ) Accumulated other comprehensive loss, net of taxes $ (2,122,000 ) $ (258,000 ) 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 Statements of Operations. The realized foreign currency transaction gain in fiscal 2014 related to the repayment of debt was reclassified from accumulated other comprehensive income to “Gas processing and other” revenues on the accompanying Consolidated Statements 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 11 for additional details).

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	12 Months Ended
	Sep. 30, 2015
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. At September 30, 2015 the carrying value of the real estate held for sale was $5,132,000 , and a $316,000 impairment of the value of the real estate held for sale was recognized in the year ended September 30, 2015. For the year ended September 30, 2015, in determining the fair value of Barnwell’s real estate held for sale, 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 8 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 9, 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, 2015
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES Lease Commitments Barnwell has several non-cancelable operating leases for office space and leasehold land. Rental expense was $408,000 and $548,000 for the years ended September 30, 2015 and 2014 , respectively. Barnwell is committed under these leases for minimum rental payments summarized by fiscal year as follows: Fiscal year ending 2016 $ 282,000 2017 247,000 2018 136,000 2019 116,000 2020 116,000 Thereafter through 2026 245,000 Total $ 1,142,000 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. Environmental Matters In January 2015, there was an oil and salt water release from one of our operated oil pipelines in Alberta, Canada. We have estimated that the gross probable environmental remediation costs will be approximately $2,300,000 . Barnwell’s working interest in the well is 58% , and we have recovered substantially all of the monies from the other working interest owners for their share of the costs. Additionally, we have filed a claim under our insurance policy, which has a deductible of approximately $80,000 , and as of September 30, 2015, we have collected $722,000 in insurance proceeds and have recorded a receivable of $381,000 for the remaining estimated recovery amount which was collected subsequent to year-end. The total estimated net financial impact for Barnwell, which includes the insurance deductible, estimated legal fees and estimated monitoring and other costs, at September 30, 2015 was approximately $223,000 , which has been recorded as a charge to operating results in the year ended September 30, 2015. The remaining estimated liability related to Barnwell's net cost for the release of $75,000 at September 30, 2015 has not been discounted and was accrued in “Accrued operating and other expenses” on the Consolidated Balance Sheets. 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 7 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. No amounts were paid pursuant to this arrangement in fiscal years 2015 or 2014 .

INFORMATION RELATING TO THE CON

INFORMATION RELATING TO THE CONSOLIDATED STATEMENTS OF CASH FLOWS	12 Months Ended
	Sep. 30, 2015
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, 2015 2014 Increase (decrease) from changes in: Receivables $ 324,000 $ 542,000 Other current assets (447,000 ) 1,629,000 Accounts payable (439,000 ) (681,000 ) Accrued compensation (323,000 ) (117,000 ) Other current liabilities (687,000 ) 976,000 (Decrease) increase from changes in current assets and liabilities $ (1,572,000 ) $ 2,349,000 Supplemental disclosure of cash flow information: Cash paid during the year for: Interest $ 306,000 $ 646,000 Income taxes paid, net of refunds $ 1,812,000 $ 765,000 Supplemental disclosure of non-cash investing and financing activities: Receivable for proceeds on sale of investments $ — $ 102,000 Capital expenditure accruals related to oil and natural gas acquisition and development decreased $61,000 and $1,195,000 during the years ended September 30, 2015 and 2014 , respectively. Additionally, during the years ended September 30, 2015 and 2014 , capital expenditure accruals related to oil and natural gas asset retirement obligations increased $1,234,000 and $2,542,000 , respectively.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Sep. 30, 2015
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 single-family residential lots in Increment I from KD I, a land development partnership in which Barnwell holds a 19.6% non-controlling ownership interest accounted for under the equity method of investment. The percentage payments are part of a 2004 transaction where Kaupulehu Developments sold its leasehold interest in Increment I, which was prior to Barnwell’s affiliation with KD I 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, 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. From the acquisition date to September 30, 2014 , Barnwell received $600,000 in percentage of sales payments from KD I from the sale of two lots within Phase II of Increment I.

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Sep. 30, 2015
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, 2015
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, 2015
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, 2013 923,000 10,245,000 2,689,000 Revisions of previous estimates 189,000 1,798,000 499,000 Extensions, discoveries and other additions 34,000 189,000 67,000 Less sales of reserves (238,000 ) (840,000 ) (383,000 ) Less production (184,000 ) (1,927,000 ) (516,000 ) 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 (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, 2015 2014 Proved properties $ 62,960,000 $ 209,201,000 Unproved properties 145,000 501,000 Total capitalized costs 63,105,000 209,702,000 Accumulated depletion and depreciation 57,460,000 191,478,000 Net capitalized costs $ 5,645,000 $ 18,224,000 (C) Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development Year ended September 30, 2015 2014 Acquisition of properties: Unproved $ 28,000 $ 42,000 Proved 804,000 — Exploration costs — 884,000 Development costs 2,680,000 3,898,000 Total $ 3,512,000 $ 4,824,000 Development costs incurred in the table above include additions and revisions to Barnwell’s asset retirement obligation of $1,234,000 and $2,542,000 for the years ended September 30, 2015 and 2014 , respectively. (D) Results of Operations for Oil and Natural Gas Producing Activities Year ended September 30, 2015 2014 Net revenues $ 9,008,000 $ 20,298,000 Production costs (6,387,000 ) (8,914,000 ) Depletion (2,987,000 ) (5,968,000 ) Pre-tax results of operations (1) (366,000 ) 5,416,000 Estimated income tax expense (2) (921,000 ) (1,557,000 ) Results of operations (1) $ (1,287,000 ) $ 3,859,000 _________________ (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 expense for fiscal 2015 includes a charge 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, 2015 and 2014 were based on weighted average sales prices, based upon the average of the price 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, 2015 and 2014 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, 2015 2014 Future cash inflows $ 27,749,000 $ 82,912,000 Future production costs (18,468,000 ) (40,156,000 ) Future development costs (935,000 ) (1,966,000 ) Future income tax expenses (2,361,000 ) (9,671,000 ) Future net cash flows 5,985,000 31,119,000 10% annual discount for timing of cash flows (1,950,000 ) (6,972,000 ) Standardized measure of discounted future net cash flows $ 4,035,000 $ 24,147,000 Changes in the Standardized Measure of Discounted Future Net Cash Flows Year ended September 30, 2015 2014 Beginning of year $ 24,147,000 $ 31,934,000 Sales of oil and natural gas produced, net of production costs (2,621,000 ) (11,384,000 ) Net changes in prices and production costs, net of royalties and wellhead taxes (8,042,000 ) 8,670,000 Extensions and discoveries 1,000 2,199,000 Net change due to purchases and sales of minerals in place (9,103,000 ) (8,408,000 ) Revisions of previous quantity estimates 634,000 4,862,000 Net change in income taxes 1,658,000 (4,148,000 ) Accretion of discount 2,021,000 2,931,000 Other - changes in the timing of future production and other (1,009,000 ) (237,000 ) Other - net change in Canadian dollar translation rate (3,651,000 ) (2,272,000 ) Net change (20,112,000 ) (7,787,000 ) End of year $ 4,035,000 $ 24,147,000

SUMMARY OF SIGNIFICANT ACCOUN31

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Sep. 30, 2015
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 consists 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. The precise timing for the release of the Dunvegan proceeds held in escrow cannot be determined however based on historical experience we believe it to be less than one year.
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.
Real Estate Held for Sale	Real Estate Held for Sale The costs of acquiring land and costs related to development and construction, including interest, property taxes and general and administrative expenses related to the development of land and home construction, are capitalized. Costs that relate to a specific lot or home are assigned to that lot or home while common costs related to multiple lots or homes will be allocated to each in proportion to their anticipated sales value. Real estate held for sale is 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. If economic conditions worsen in the future or if difficult market conditions extend beyond the Company’s expectations resulting in a decrease in the fair value of the aforementioned assets below carrying value, the Company will be required to record an impairment loss. Homebuilding revenue and related profit or loss are generally recognized at the time of the closing of a sale, when title to and possession of the property are transferred to the buyer.
Investment Held for Sale and Investments in Real Estate	Investment Held for Sale Barnwell’s investment in one residential parcel is reported at the lower of the asset carrying value or fair value less costs to sell. The recorded balance is 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, changes in the use of the asset, and ongoing cost of maintenance and improvements of the asset. Changes in these and other assumptions may require impairment charges that may materially impact the Company’s future operating results. If economic conditions worsen in the future or if difficult market conditions extend beyond the Company’s expectations resulting in a decrease in the fair value of the aforementioned asset below carrying value, the Company will be required to record an impairment loss. Investment property is 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 or 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	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 7).
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. 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 11. 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 $33,000 based on the assets of the plan at September 30, 2015 . 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 February 2013, the FASB issued ASU No. 2013-04, “Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date.” This update provides guidance for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation within the scope of this guidance is fixed at the reporting date, except for obligations addressed within existing guidance in U.S. GAAP. Examples of obligations within this guidance are debt arrangements, other contractual obligations, and settled litigation and judicial rulings. The Company adopted the provisions of this ASU effective October 1, 2014. The adoption of this update did not have a material impact on Barnwell’s consolidated financial statements. In March 2013, the FASB issued ASU No. 2013-05, “Parent’s Accounting for the Cumulative Translation Adjustment upon Derecognition of Certain Subsidiaries or Groups of Assets within a Foreign Entity or of an Investment in a Foreign Entity.” This update provides guidance on releasing cumulative translation adjustments when a reporting entity ceases to have a controlling financial interest in a subsidiary or group of assets that is a nonprofit activity or a business within a foreign entity. In addition, these amendments provide guidance on the release of cumulative translation adjustments in partial sales of equity method investments and in step acquisitions. The Company adopted the provisions of this ASU effective October 1, 2014. The adoption of this update did not have a material impact on Barnwell’s consolidated financial statements. In April 2013, the FASB issued ASU No. 2013-07, “Liquidation Basis of Accounting,” which provides guidance on when and how to apply the liquidation basis of accounting and on what to disclose. The update requires an entity to prepare its financial statements using the liquidation basis of accounting when liquidation is imminent, as defined in the update. The Company adopted the provisions of this ASU effective October 1, 2014. The adoption of this update did not have a material impact on Barnwell’s consolidated financial statements. In July 2013, the FASB issued ASU No. 2013-11, “Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists,” which requires an entity to present an unrecognized tax benefit as a reduction of a deferred tax asset for a net operating loss (“NOL”) carryforward, or similar tax loss or tax credit carryforward, rather than as a liability when (1) the uncertain tax position would reduce the NOL or other carryforward under the tax law of the applicable jurisdiction and (2) the entity intends to use the deferred tax asset for that purpose. The Company adopted the provisions of this ASU effective October 1, 2014. The adoption of this update did not have a material impact on Barnwell’s consolidated financial statements. In November 2014, the FASB issued ASU 2014-17, “Pushdown Accounting,” which provides companies with the option to apply pushdown accounting in its separate financial statements upon occurrence of an event in which an acquirer obtains control of the acquired entity. The election to apply pushdown accounting can be made either in the period in which the change of control occurred or in a subsequent period. If the election is made in a subsequent period, it would be considered a change in accounting principle and treated in accordance with Topic 250, “Accounting Changes and Error Corrections.” The Company adopted the provisions of this ASU on November 18, 2014, as the amendments in the update were effective upon issuance. The adoption of this update did not have a material impact on Barnwell’s consolidated financial statements.

EARNINGS PER COMMON SHARE (Tabl

EARNINGS PER COMMON SHARE (Tables)	12 Months Ended
	Sep. 30, 2015
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, 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 Year ended September 30, 2014 Net Earnings Shares Per-Share (Numerator) (Denominator) Amount Basic net earnings per share $ 672,000 8,277,160 $ 0.08 Effect of dilutive securities - common stock options — 1,132 Diluted net earnings per share $ 672,000 8,278,292 $ 0.08

SHARE-BASED PAYMENTS (Tables)

SHARE-BASED PAYMENTS (Tables)	12 Months Ended
	Sep. 30, 2015
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, 2015 2014 Share-based compensation benefit $ (140,000 ) $ (380,000 ) 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, 2014 through September 30, 2015 is presented below: Options Shares Weighted- Weighted- Aggregate Outstanding at October 1, 2014 90,000 $ 6.75 Granted — Exercised — Expired/Forfeited (60,000 ) 8.62 Outstanding at September 30, 2015 30,000 $ 3.01 8.2 $ — Exercisable at September 30, 2015 7,500 $ 3.01 8.2 $ —
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, 2015 2014 Due to vesting $ 10,000 $ 21,000 Due to remeasurement (170,000 ) (427,000 ) Total share-based compensation benefit for liability-based awards $ (160,000 ) $ (406,000 )
Summary of the activity in share options	A summary of the activity in Barnwell’s liability-classified share options from October 1, 2014 through September 30, 2015 is presented below: Options Shares Weighted- Weighted- Aggregate Outstanding at October 1, 2014 747,250 $ 8.15 Granted — Exercised — Expired/Forfeited (156,000 ) 8.80 Outstanding at September 30, 2015 591,250 $ 7.98 3.6 $ — Exercisable at September 30, 2015 568,750 $ 8.18 3.4 $ —
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, 2015 2014 Expected volatility range 51.5% to 61.6% 29.0% to 57.2% Weighted-average volatility 52.4% 45.4% Expected dividends None None Expected term (in years) 2.2 to 8.2 0.2 to 9.2 Risk-free interest rate 0.6% to 1.9% 0.1% to 2.5% Expected forfeitures None None

ACCOUNTS RECEIVABLE AND CONTR34

ACCOUNTS RECEIVABLE AND CONTRACT COSTS (Tables)	12 Months Ended
	Sep. 30, 2015
Receivables [Abstract]
Schedule of costs and estimated earnings (loss) on uncompleted contracts	Costs and estimated earnings on uncompleted contracts are as follows: September 30, 2015 2014 Costs incurred on uncompleted contracts $ 1,890,000 $ 6,049,000 Estimated earnings 226,000 472,000 2,116,000 6,521,000 Less billings to date 2,503,000 7,094,000 $ (387,000 ) $ (573,000 )
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, 2015 2014 Costs and estimated earnings in excess of billings on uncompleted contracts (included in other current assets) $ 182,000 $ 21,000 Billings in excess of costs and estimated earnings on uncompleted contracts (569,000 ) (594,000 ) $ (387,000 ) $ (573,000 )

INVESTMENTS (Tables)

INVESTMENTS (Tables)	12 Months Ended
	Sep. 30, 2015
Investments, All Other Investments [Abstract]
Summary of investments	A summary of Barnwell’s non-current investments is as follows: September 30, 2015 2014 Investment in Kukio Resort land development partnerships $ 6,238,000 $ 4,658,000 Investment in residential parcel — 1,192,000 Investment in leasehold land interest – Lot 4C 50,000 50,000 Total non-current investments $ 6,288,000 $ 5,900,000
Summarized financial information for the land development partnerships	Summarized financial information for the Kukio Resort land development partnerships is as follows: Year ended November 27, 2013 - September 30, 2015 September 30, 2014 Revenue $ 29,898,000 $ 5,114,000 Gross profit $ 13,594,000 $ 2,058,000 Net income (loss) $ 7,500,000 $ (1,614,000 )
Summary of Increment I percentage of sales payment revenues received	The following table summarizes the Increment I percentage of sales payment revenues received from KD I: Year ended September 30, 2015 2014 Sale of interest in leasehold land: Proceeds $ 3,772,000 $ 740,000 Fees (528,000 ) (104,000 ) Revenues – sale of interest in leasehold land, net $ 3,244,000 $ 636,000

OIL AND NATURAL GAS PROPERTIES

OIL AND NATURAL GAS PROPERTIES (Tables)	12 Months Ended
	Sep. 30, 2015
Extractive Industries [Abstract]
Summary of allocation of purchase price to the assets acquired and liabilities assumed	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 15 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 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 15 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 AS37

PROPERTY AND EQUIPMENT AND ASSET RETIREMENT OBLIGATION (Tables)	12 Months Ended
	Sep. 30, 2015
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, 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 Estimated Gross Accumulated Net At September 30, 2014: Land $ 863,000 $ — $ 863,000 Oil and natural gas properties (full cost accounting) 209,702,000 (191,478,000 ) 18,224,000 Drilling rigs and equipment 3 – 10 years 6,759,000 (5,754,000 ) 1,005,000 Offices 40 years 2,420,000 (384,000 ) 2,036,000 Other property and equipment 3 – 17 years 3,279,000 (3,057,000 ) 222,000 Total $ 223,023,000 $ (200,673,000 ) $ 22,350,000
Schedule of reconciliation of the asset retirement obligation	The following is a reconciliation of the asset retirement obligation: Year ended September 30, 2015 2014 Asset retirement obligation as of beginning of year $ 9,163,000 $ 7,520,000 Obligations incurred on new wells drilled or acquired 316,000 105,000 Liabilities associated with properties sold (2,013,000 ) (718,000 ) Revision of estimated obligation 918,000 2,437,000 Accretion expense 632,000 624,000 Payments (655,000 ) (111,000 ) Foreign currency translation adjustment (1,425,000 ) (694,000 ) Asset retirement obligation as of end of year 6,936,000 9,163,000 Less current portion (506,000 ) (978,000 ) Asset retirement obligation, long-term $ 6,430,000 $ 8,185,000

LONG-TERM DEBT (Tables)

LONG-TERM DEBT (Tables)	12 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
Schedule of long-term debt	A summary of Barnwell’s long-term debt is as follows: September 30, 2015 2014 Canadian revolving credit facility $ — $ 7,000,000 Real estate loan 3,440,000 4,099,000 3,440,000 11,099,000 Less current portion (3,440,000 ) (4,449,000 ) Total long-term debt $ — $ 6,650,000

RETIREMENT PLANS (Tables)

RETIREMENT PLANS (Tables)	12 Months Ended
	Sep. 30, 2015
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, 2015 2014 2015 2014 2015 2014 Change in Projected Benefit Obligation: Benefit obligation at beginning of year $ 8,299,000 $ 6,858,000 $ 1,767,000 $ 1,322,000 $ 1,227,000 $ 1,073,000 Service cost 256,000 156,000 62,000 47,000 — 12,000 Interest cost 356,000 322,000 77,000 67,000 52,000 54,000 Actuarial loss 110,000 1,186,000 — 337,000 40,000 88,000 Benefits paid (326,000 ) (213,000 ) (6,000 ) (6,000 ) — — Administrative expenses paid (12,000 ) (10,000 ) — — — — Benefit obligation at end of year 8,683,000 8,299,000 1,900,000 1,767,000 1,319,000 1,227,000 Change in Plan Assets: Fair value of plan assets at beginning of year 7,022,000 6,111,000 — — — — Actual return on plan assets (446,000 ) 784,000 — — — — Employer contributions 250,000 350,000 6,000 6,000 — — Benefits paid (326,000 ) (213,000 ) (6,000 ) (6,000 ) — — Administrative expenses paid (12,000 ) (10,000 ) — — — — Fair value of plan assets at end of year 6,488,000 7,022,000 — — — — Funded status $ (2,195,000 ) $ (1,277,000 ) $ (1,900,000 ) $ (1,767,000 ) $ (1,319,000 ) $ (1,227,000 )
Schedule of amounts recognized in the consolidated balance sheets	Pension SERP Postretirement Medical September 30, 2015 2014 2015 2014 2015 2014 Amounts recognized in the Consolidated Balance Sheets: Current liabilities $ — $ — $ (5,000 ) $ (5,000 ) $ — $ — Noncurrent liabilities (2,195,000 ) (1,277,000 ) (1,895,000 ) (1,762,000 ) (1,319,000 ) (1,227,000 ) Net amount $ (2,195,000 ) $ (1,277,000 ) $ (1,900,000 ) $ (1,767,000 ) $ (1,319,000 ) $ (1,227,000 ) Amounts recognized in accumulated other comprehensive (loss) income: Net actuarial loss (gain) $ 3,038,000 $ 2,068,000 $ 506,000 $ 530,000 $ (110,000 ) $ (155,000 ) Prior service cost (credit) 77,000 81,000 (76,000 ) (80,000 ) — — Accumulated other comprehensive loss (income) $ 3,115,000 $ 2,149,000 $ 430,000 $ 450,000 $ (110,000 ) $ (155,000 )
Schedule of amounts recognized in accumulated other comprehensive (loss) income	Pension SERP Postretirement Medical September 30, 2015 2014 2015 2014 2015 2014 Amounts recognized in the Consolidated Balance Sheets: Current liabilities $ — $ — $ (5,000 ) $ (5,000 ) $ — $ — Noncurrent liabilities (2,195,000 ) (1,277,000 ) (1,895,000 ) (1,762,000 ) (1,319,000 ) (1,227,000 ) Net amount $ (2,195,000 ) $ (1,277,000 ) $ (1,900,000 ) $ (1,767,000 ) $ (1,319,000 ) $ (1,227,000 ) Amounts recognized in accumulated other comprehensive (loss) income: Net actuarial loss (gain) $ 3,038,000 $ 2,068,000 $ 506,000 $ 530,000 $ (110,000 ) $ (155,000 ) Prior service cost (credit) 77,000 81,000 (76,000 ) (80,000 ) — — Accumulated other comprehensive loss (income) $ 3,115,000 $ 2,149,000 $ 430,000 $ 450,000 $ (110,000 ) $ (155,000 )
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, 2015 2014 2015 2014 2015 2014 Assumptions used to determine fiscal year-end benefit obligations: Discount rate 4.25% 4.25% 4.25% 4.25% 4.25% 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% 5.00% 4.25% 5.00% 4.25% 5.00% 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, 2015 2014 2015 2014 2015 2014 Net periodic benefit cost for the year: Service cost $ 256,000 $ 156,000 $ 62,000 $ 47,000 $ — $ 12,000 Interest cost 356,000 322,000 77,000 67,000 52,000 54,000 Expected return on plan assets (500,000 ) (429,000 ) — — — — Amortization of prior service cost (credit) 5,000 5,000 (5,000 ) (5,000 ) — 12,000 Amortization of net actuarial loss (gain) 86,000 20,000 24,000 5,000 (5,000 ) (21,000 ) Net periodic benefit cost $ 203,000 $ 74,000 $ 158,000 $ 114,000 $ 47,000 $ 57,000
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 (gain) 135,000 19,000 (5,000 ) $ 140,000 $ 14,000 $ (5,000 )
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, 2015 are as follows: Pension SERP Postretirement Expected Benefit Payments: Fiscal year ending September 30, 2016 $ 207,000 $ 5,000 $ — Fiscal year ending September 30, 2017 $ 268,000 $ 4,000 $ — Fiscal year ending September 30, 2018 $ 288,000 $ 3,000 $ 25,000 Fiscal year ending September 30, 2019 $ 275,000 $ 3,000 $ 28,000 Fiscal year ending September 30, 2020 $ 383,000 $ 71,000 $ 19,000 Fiscal years ending September 30, 2021 through 2025 $ 2,380,000 $ 568,000 $ 296,000
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, 2015 2014 Health care cost trend rates assumed for next year 8.0% 7.5% Ultimate cost trend rate 5.0% 5.0% Year that the rate reaches the ultimate trend rate 2028 2020
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 $ 267,000 $ (212,000 )
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 2015 2014 Cash and other 0% - 30% 9% 12% Fixed income securities 20% - 60% 22% 20% Equity securities 30% - 70% 69% 68%
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 $ 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 $ — $ — Fair Value Measurements Using: Carrying Quoted Significant Significant Financial Assets: Cash $ 817,000 $ 817,000 $ — $ — Corporate bonds 660,000 660,000 — — Fixed income exchange-traded funds 521,000 521,000 — — Preferred securities 232,000 232,000 — — Equity securities exchange-traded funds 758,000 758,000 — — Equities 4,034,000 4,034,000 — — Total $ 7,022,000 $ 7,022,000 $ — $ —

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Sep. 30, 2015
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, 2015 2014 United States $ 1,011,000 $ (629,000 ) Canada 1,460,000 1,905,000 $ 2,471,000 $ 1,276,000
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, 2015 2014 Current (benefit) provision: United States – Federal Before operating loss carryforwards $ — $ 886,000 Benefit of operating loss carryforwards — (886,000 ) After operating loss carryforwards — — United States – State 94,000 (1,000 ) 94,000 (1,000 ) Canadian 1,529,000 1,312,000 Total current 1,623,000 1,311,000 Deferred benefit: United States (90,000 ) — Canadian (325,000 ) (707,000 ) Total deferred (415,000 ) (707,000 ) $ 1,208,000 $ 604,000
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 provision and the amount computed by multiplying the earnings attributable to Barnwell before income taxes by the U.S. federal tax rate of 35% is as follows: Year ended September 30, 2015 2014 Tax provision computed by applying statutory rate $ 865,000 $ 447,000 Increase in the valuation allowance - U.S. federal and Canadian tax law 1,653,000 584,000 Additional effect of the foreign tax provision on the total tax provision (1,243,000 ) (467,000 ) Other (67,000 ) 40,000 $ 1,208,000 $ 604,000
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, 2015 2014 Deferred income tax assets: U.S. tax effect of deferred Canadian taxes $ 91,000 $ 248,000 Foreign tax credit carryover 4,661,000 3,023,000 Alternative minimum tax credit carryover 460,000 460,000 U.S. federal net operating loss carryover 4,440,000 4,017,000 Tax basis of investment in land and residential real estate in excess of book basis 1,115,000 1,842,000 Property and equipment accumulated tax depreciation and depletion in excess of book under U.S. tax law 4,494,000 4,069,000 Liabilities accrued for books but not for tax under U.S. tax law 4,423,000 5,112,000 Liabilities accrued for books but not for tax under Canadian tax law 2,149,000 2,731,000 Other 746,000 2,098,000 Total gross deferred tax assets 22,579,000 23,600,000 Less valuation allowance (21,387,000 ) (20,869,000 ) Net deferred income tax assets 1,192,000 2,731,000 Deferred income tax liabilities: Property and equipment accumulated tax depreciation and depletion in excess of book under Canadian tax law (1,459,000 ) (3,460,000 ) Other (4,000 ) (94,000 ) Total deferred income tax liabilities (1,463,000 ) (3,554,000 ) Net deferred income tax liability $ (271,000 ) $ (823,000 ) Net deferred income tax liability is included in the Consolidated Balance Sheets as follows: September 30, 2015 2014 Current deferred income tax asset (included in other current assets) $ 178,000 $ 378,000 Deferred income tax liability (449,000 ) (1,201,000 ) Net deferred income tax liability $ (271,000 ) $ (823,000 )
Schedule of changes in unrecognized tax benefits	Below are the changes in unrecognized tax benefits. Year ended September 30, 2015 2014 Balance at beginning of year $ 660,000 $ 704,000 Effect of tax positions taken in prior years 92,000 — Accrued interest related to tax positions taken 38,000 14,000 Lapse of statute (174,000 ) — Translation adjustments (34,000 ) (58,000 ) Balance at end of year $ 582,000 $ 660,000
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, 2015 : Jurisdiction Fiscal Years Open U.S. federal 2012 – 2014 Various U.S. states 2012 – 2014 Canada federal 2008 – 2014 Various Canadian provinces 2008 – 2014

SEGMENT AND GEOGRAPHICAL INFORM

SEGMENT AND GEOGRAPHICAL INFORMATION (Tables)	12 Months Ended
	Sep. 30, 2015
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, 2015 2014 Revenues: Oil and natural gas $ 9,008,000 $ 20,298,000 Land investment 3,244,000 636,000 Contract drilling 4,886,000 6,287,000 Other 341,000 796,000 Total before gain on sale of investments and interest income 17,479,000 28,017,000 Gain on sale of investments — 3,399,000 Interest income 54,000 29,000 Total revenues $ 17,533,000 $ 31,445,000 Depletion, depreciation, and amortization: Oil and natural gas $ 2,987,000 $ 5,968,000 Contract drilling 272,000 309,000 Other 105,000 114,000 Total depletion, depreciation, and amortization $ 3,364,000 $ 6,391,000 Impairment: Residential real estate $ 316,000 $ — Operating (loss) profit (before general and administrative expenses): Oil and natural gas $ (366,000 ) $ 5,416,000 Land investment 3,244,000 636,000 Contract drilling 922,000 952,000 Residential real estate (316,000 ) — Other 236,000 682,000 Gain on sales of assets 6,489,000 — Total operating profit 10,209,000 7,686,000 Equity in income (loss) of affiliates: Land investment 1,580,000 (482,000 ) General and administrative expenses (8,551,000 ) (8,026,000 ) Interest expense (315,000 ) (664,000 ) Gain on sale of investments — 3,399,000 Interest income 54,000 29,000 Earnings before income taxes $ 2,977,000 $ 1,942,000 Capital Expenditures: Year ended September 30, 2015 2014 Oil and natural gas $ 3,512,000 $ 4,824,000 Contract drilling 124,000 48,000 Other 79,000 51,000 Total $ 3,715,000 $ 4,923,000 Assets By Segment: September 30, 2015 2014 Oil and natural gas (1) $ 7,298,000 $ 20,951,000 Land investment (2) 7,480,000 7,039,000 Contract drilling (2) 2,338,000 1,849,000 Residential real estate (2) 5,132,000 5,448,000 Other: Cash and cash equivalents 8,471,000 16,104,000 Restricted cash 7,577,000 — Corporate and other 3,257,000 3,379,000 Total $ 41,553,000 $ 54,770,000 ______________ (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, 2015 2014 United States $ 10,135,000 $ 9,884,000 Canada 5,740,000 18,366,000 Total $ 15,875,000 $ 28,250,000 Revenue By Geographic Area: Year ended September 30, 2015 2014 United States $ 8,237,000 $ 6,924,000 Canada 9,242,000 21,093,000 Total (excluding gain on sale of investments and interest income) $ 17,479,000 $ 28,017,000

ACCUMULATED OTHER COMPREHENSI42

ACCUMULATED OTHER COMPREHENSIVE (LOSS) INCOME (Tables)	12 Months Ended
	Sep. 30, 2015
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, 2015 2014 Foreign currency translation: Beginning accumulated foreign currency translation $ 1,692,000 $ 3,701,000 Change in cumulative translation adjustment before reclassifications (1,625,000 ) (1,738,000 ) Amounts reclassified from accumulated other comprehensive income 752,000 (271,000 ) Income taxes — — Net current period other comprehensive loss (873,000 ) (2,009,000 ) Ending accumulated foreign currency translation 819,000 1,692,000 Retirement plans: Beginning accumulated retirement plans benefit cost (1,950,000 ) (710,000 ) Amortization of net actuarial loss and prior service cost 105,000 16,000 Net actuarial loss arising during the period (1,096,000 ) (1,256,000 ) Income taxes — — Net current period other comprehensive loss (991,000 ) (1,240,000 ) Ending accumulated retirement plans benefit cost (2,941,000 ) (1,950,000 ) Accumulated other comprehensive loss, net of taxes $ (2,122,000 ) $ (258,000 )

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Sep. 30, 2015
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 2016 $ 282,000 2017 247,000 2018 136,000 2019 116,000 2020 116,000 Thereafter through 2026 245,000 Total $ 1,142,000

INFORMATION RELATING TO THE C44

INFORMATION RELATING TO THE CONSOLIDATED STATEMENTS OF CASH FLOWS (Tables)	12 Months Ended
	Sep. 30, 2015
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, 2015 2014 Increase (decrease) from changes in: Receivables $ 324,000 $ 542,000 Other current assets (447,000 ) 1,629,000 Accounts payable (439,000 ) (681,000 ) Accrued compensation (323,000 ) (117,000 ) Other current liabilities (687,000 ) 976,000 (Decrease) increase from changes in current assets and liabilities $ (1,572,000 ) $ 2,349,000 Supplemental disclosure of cash flow information: Cash paid during the year for: Interest $ 306,000 $ 646,000 Income taxes paid, net of refunds $ 1,812,000 $ 765,000 Supplemental disclosure of non-cash investing and financing activities: Receivable for proceeds on sale of investments $ — $ 102,000

SUPPLEMENTARY OIL AND NATURAL45

SUPPLEMENTARY OIL AND NATURAL GAS INFORMATION (UNAUDITED) (Tables)	12 Months Ended
	Sep. 30, 2015
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, 2013 923,000 10,245,000 2,689,000 Revisions of previous estimates 189,000 1,798,000 499,000 Extensions, discoveries and other additions 34,000 189,000 67,000 Less sales of reserves (238,000 ) (840,000 ) (383,000 ) Less production (184,000 ) (1,927,000 ) (516,000 ) 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
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, 2015 2014 Proved properties $ 62,960,000 $ 209,201,000 Unproved properties 145,000 501,000 Total capitalized costs 63,105,000 209,702,000 Accumulated depletion and depreciation 57,460,000 191,478,000 Net capitalized costs $ 5,645,000 $ 18,224,000
Schedule of costs incurred in oil and natural gas property acquisition, exploration and development	Year ended September 30, 2015 2014 Acquisition of properties: Unproved $ 28,000 $ 42,000 Proved 804,000 — Exploration costs — 884,000 Development costs 2,680,000 3,898,000 Total $ 3,512,000 $ 4,824,000
Schedule of results of operations for oil and natural gas producing activities	Year ended September 30, 2015 2014 Net revenues $ 9,008,000 $ 20,298,000 Production costs (6,387,000 ) (8,914,000 ) Depletion (2,987,000 ) (5,968,000 ) Pre-tax results of operations (1) (366,000 ) 5,416,000 Estimated income tax expense (2) (921,000 ) (1,557,000 ) Results of operations (1) $ (1,287,000 ) $ 3,859,000 _________________ (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 expense for fiscal 2015 includes a charge 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, 2015 2014 Future cash inflows $ 27,749,000 $ 82,912,000 Future production costs (18,468,000 ) (40,156,000 ) Future development costs (935,000 ) (1,966,000 ) Future income tax expenses (2,361,000 ) (9,671,000 ) Future net cash flows 5,985,000 31,119,000 10% annual discount for timing of cash flows (1,950,000 ) (6,972,000 ) Standardized measure of discounted future net cash flows $ 4,035,000 $ 24,147,000
Schedule of changes in standardized measure of discounted future net cash flows	Year ended September 30, 2015 2014 Beginning of year $ 24,147,000 $ 31,934,000 Sales of oil and natural gas produced, net of production costs (2,621,000 ) (11,384,000 ) Net changes in prices and production costs, net of royalties and wellhead taxes (8,042,000 ) 8,670,000 Extensions and discoveries 1,000 2,199,000 Net change due to purchases and sales of minerals in place (9,103,000 ) (8,408,000 ) Revisions of previous quantity estimates 634,000 4,862,000 Net change in income taxes 1,658,000 (4,148,000 ) Accretion of discount 2,021,000 2,931,000 Other - changes in the timing of future production and other (1,009,000 ) (237,000 ) Other - net change in Canadian dollar translation rate (3,651,000 ) (2,272,000 ) Net change (20,112,000 ) (7,787,000 ) End of year $ 4,035,000 $ 24,147,000

SUMMARY OF SIGNIFICANT ACCOUN46

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) $ in Thousands	12 Months Ended
	Sep. 30, 2015USD ($)homeventure
Principles of Consolidation
Number of 80%-owned joint ventures | venture	2
Investments Held for Sale [Abstract]
Number of residential parcels owned | home	1
Retirement Plans
Increase (decrease) pension expense | $	$ 33
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)	1 Months Ended	12 Months Ended
	Sep. 30, 2015USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2014USD ($)	Sep. 30, 2015CAD	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)
Line of Credit Facility [Line Items]
Restricted cash			$ 0		$ 7,458,000
Working capital					15,675,000
Credit Agreement
Line of Credit Facility [Line Items]
Repayments of long-term debt		$ 4,800,000
Maximum borrowing capacity				CAD 1,000,000	747,000	$ 6,500,000
Oil and natural gas properties
Line of Credit Facility [Line Items]
Proceeds from sale of oil and natural gas properties, net of broker's fees and other closing costs			$ 13,846,000
Dunvegan and Belloy areas of Alberta | Oil and natural gas properties
Line of Credit Facility [Line Items]
Proceeds from sale of oil and natural gas properties, net of broker's fees and other closing costs	$ 14,162,000
Restricted cash					$ 7,135,000

EARNINGS PER COMMON SHARE (Deta

EARNINGS PER COMMON SHARE (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Net Earnings (Numerator)
Basic	$ 1,263	$ 672
Diluted	$ 1,263	$ 672
Shares (Denominator)
Basic (in shares)	8,277,160	8,277,160
Effect of dilutive securities-common stock options (in shares)	0	1,132
Diluted (in shares)	8,277,160	8,278,292
Per-Share Amount
Basic net earnings per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share)	$ 0.15	$ 0.08
Diluted net earnings per share (in dollars per share)	$ 0.15	$ 0.08
Options
Antidilutive shares of common stock excluded from the computation of diluted shares
Antidilutive shares excluded from computation of earnings per share (in shares)	621,250	807,250

SHARE-BASED PAYMENTS (Details)

SHARE-BASED PAYMENTS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Share-based payments
Share-based compensation (benefit) expense	$ (140)	$ (380)
Income tax effect related to share-based compensation benefit	0	0
Total unrecognized compensation cost	$ 24
Period over which unrecognized compensation cost is expected to be recognized	2 years 2 months 12 days
Equity-classified share options
Share-based payments
Share-based compensation (benefit) expense	$ 20	$ 26
2008 Equity Incentive Plan
Share-based payments
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, 2015	Sep. 30, 2014
Components of the total share-based compensation
Total share-based compensation (benefit) expense for awards	$ (140,000)	$ (380,000)
Equity-classified share options
Shares
Outstanding at the beginning of the period (in shares)	90,000
Granted (in shares)	0
Expired/Forfeited (in shares)	(60,000)
Outstanding at the end of the period (in shares)	30,000	90,000
Exercisable at the end of period (in shares)	7,500
Weighted-Average Exercise Price
Outstanding at the beginning of the period (in dollars per share)	$ 6.75
Granted (in dollars per share)
Expired/Forfeited (in dollars per share)	$ 8.62
Outstanding at the end of the period (in dollars per share)	3.01	$ 6.75
Exercisable at the end of period (in dollars per share)	$ 3.01
Weighted-Average Remaining Contractual Term
Options outstanding, weighted average contractual life	8 years 2 months 12 days
Options exercisable, weighted average contractual life	8 years 2 months 12 days
Aggregate Intrinsic Value
Options outstanding, aggregate intrinsic value	$ 0
Options exercisable, aggregate intrinsic value	0
Components of the total share-based compensation
Total share-based compensation (benefit) expense for awards	$ 20,000	$ 26,000
Liability-classified share options
Shares
Outstanding at the beginning of the period (in shares)	747,250
Granted (in shares)	0
Expired/Forfeited (in shares)	(156,000)
Outstanding at the end of the period (in shares)	591,250	747,250
Exercisable at the end of period (in shares)	568,750
Weighted-Average Exercise Price
Outstanding at the beginning of the period (in dollars per share)	$ 8.15
Granted (in dollars per share)
Expired/Forfeited (in dollars per share)	$ 8.80
Outstanding at the end of the period (in dollars per share)	7.98	$ 8.15
Exercisable at the end of period (in dollars per share)	$ 8.18
Weighted-Average Remaining Contractual Term
Options outstanding, weighted average contractual life	3 years 7 months 6 days
Options exercisable, weighted average contractual life	3 years 4 months 24 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	51.50%	29.00%
Expected volatility range, maximum	61.60%	57.20%
Weighted-average volatility	52.40%	45.40%
Expected dividends	0.00%	0.00%
Risk-free interest rate, minimum	0.60%	0.10%
Risk-free interest rate, maximum	1.90%	2.50%
Expected forfeitures	0.00%	0.00%
Components of the total share-based compensation
Due to vesting	$ 10,000	$ 21,000
Due to remeasurement	(170,000)	(427,000)
Total share-based compensation (benefit) expense for awards	$ (160,000)	$ (406,000)
Liability-classified share options | Minimum
Assumptions used in estimating fair value
Expected term	2 years 2 months 12 days	2 months 12 days
Liability-classified share options | Maximum
Assumptions used in estimating fair value
Expected term	8 years 2 months 12 days	9 years 2 months 12 days

ACCOUNTS RECEIVABLE AND CONTR51

ACCOUNTS RECEIVABLE AND CONTRACT COSTS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Receivables [Abstract]
Allowances for doubtful accounts	$ 23	$ 34
Contract retainage balance included in accounts receivable	$ 257	202
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	$ 1,890	6,049
Estimated earnings	226	472
Costs and estimated earnings (loss) on uncompleted contracts	2,116	6,521
Less billings to date	2,503	7,094
Net costs and estimated earnings (loss) in excess of (less than) billings	(387)	(573)
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)	182	21
Billings in excess of costs and estimated earnings on uncompleted contracts	(569)	(594)
Net costs and estimated earnings (loss) in excess of (less than) billings	$ (387)	$ (573)

REAL ESTATE HELD FOR SALE (Deta

REAL ESTATE HELD FOR SALE (Details)	Sep. 30, 2015home
Kaupulehu 2007, LLLP
Real estate held for sale
Number of luxury residences owned	1

INVESTMENTS (Details)

INVESTMENTS (Details)	Jul. 25, 2014USD ($)	Nov. 27, 2013USD ($)partnership	Oct. 31, 2014USD ($)	Sep. 30, 2014USD ($)	Sep. 30, 2015USD ($)ahomeincrementparcellot	Sep. 30, 2014USD ($)
Summary of investments
Total investments				$ 5,900,000	$ 6,288,000	$ 5,900,000
Number of residential parcels owned | home					1
Proceeds from Sale of Land Held-for-investment			$ 1,250,000
Equity in income (loss) of affiliates					$ 1,580,000	(482,000)
Revenues sale of interest in leasehold land, net					3,244,000	636,000
Additional payment received				102,000	0	102,000
Gain on sale of investments					0	3,399,000
Gain on sale of investments relating to Non-Controlling Interest					$ 506,000	666,000
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					$ 3,772,000	740,000
Sale of interest in leasehold land: Fees					(528,000)	(104,000)
Revenues sale of interest in leasehold land, net					$ 3,244,000	636,000
Ownership interest in subsidiaries					77.60%
Kaupulehu Investors, LLC
Summary of investments
Ownership interest in subsidiaries					80.00%
Kaupulehu Investors, LLC | Haulalai Resort and Kona Village Resort
Summary of investments
Total investments	$ 0
Ownership interest in subsidiaries	80.00%
Cash proceeds received	$ 3,297,000
Gain on sale of investments	3,399,000
Gain on sale of investments relating to Non-Controlling Interest	679,000
Capital and operating cash call investments	$ 3,193,000
Kaupulehu Investors, LLC | Haulalai Resort
Summary of investments
Passive minority interests in various joint ventures	1.50%
Kaupulehu Investors, LLC | Kona Village Resort
Summary of investments
Passive minority interests in various joint ventures	1.50%
Kaupulehu Investors, LLC | Sale of an interest in a related utility
Summary of investments
Additional payment received	$ 102,000
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					$ 199,000,000
Number of lots sold in Increment I | lot					17
Number of single-family lots planned in Increment I | lot					80
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | Phase I
Summary of investments
Number of lots sold in Increment I | lot					38
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | Phase II
Summary of investments
Number of lots sold in Increment I | lot					14
Number of single-family lots planned in Increment I | lot					42
KD Kaupulehu LLLP Increment I | Kaupulehu Developments | Aggregate gross proceeds up to $100,000,000
Summary of investments
Payments entitled to be received from KD I as percentage of gross receipts from KD I's sales of single-family residential lots in Increment I					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 from KD I as percentage of gross receipts from KD I's sales of single-family residential lots in Increment I					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 from KD I as percentage of gross receipts from KD I's sales of single-family residential lots in Increment I					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 | Minimum
Summary of investments
Area of land (in acres) | a					2
KD Kaupulehu LLLP Increment II | Kaupulehu Developments | Maximum
Summary of investments
Area of land (in acres) | a					3
Investment in land development partnerships
Summary of investments
Total investments				4,658,000	$ 6,238,000	4,658,000
Number of limited liability limited partnerships formed | partnership		2
Equity in income (loss) of affiliates					1,580,000	(482,000)
Basis difference between the underlying equity in net assets of the investee and the carrying value of the entity's investment					390,000
Basis difference adjustment					82,000
Bonds issued by the surety					4,144,000
Maximum loss exposure					10,382,000
Summarized financial information
Revenue				5,114,000	29,898,000
Gross profit				2,058,000	13,594,000
Net income (loss)				(1,614,000)	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
Summary of investments
Total investments				1,192,000	$ 0	1,192,000
Number of residential parcels owned | parcel					1
Investment in land | KD Maniniowali, LLLP
Summary of investments
Number of residential parcels held by equity method investment | lot					1
Investment in land | KD Kaupulehu LLLP Increment I
Summary of investments
Number of residential parcels held by equity method investment | lot					28
Investment in land | KD Kaupulehu LLLP Increment II
Summary of investments
Number of residential parcels held by equity method investment | lot					2
Investment in leasehold land interest - Lot 4C
Summary of investments
Total investments				$ 50,000	$ 50,000	$ 50,000
Area of land (in acres) | a					1,000

OIL AND NATURAL GAS PROPERTIE54

OIL AND NATURAL GAS PROPERTIES (Details) - USD ($)	1 Months Ended				12 Months Ended
	Sep. 30, 2015	May. 31, 2014	Apr. 30, 2014	Feb. 28, 2014	Sep. 30, 2015	Sep. 30, 2014	Aug. 27, 2015	Nov. 13, 2014
Oil and natural gas properties
Restricted cash	$ 7,458,000				$ 7,458,000	$ 0
Gain (loss) recognized from property sales						0
Liabilities associated with properties sold					2,013,000	718,000
Revenues					17,533,000	31,445,000
Net earnings (loss)					1,769,000	1,338,000
Net earnings (loss) attributable to Barnwell Industries, Inc. stockholders					$ 1,263,000	$ 672,000
Net earnings (loss) per common share attributable to Barnwell Industries, Inc. stockholders (in dollars per share)					$ 0.15	$ 0.08
Oil and natural gas properties
Oil and natural gas properties
Property and equipment							$ 397,000	$ 751,000
Asset retirement obligation							(91,000)	(225,000)
Net identifiable assets acquired							$ 306,000	$ 526,000
Proceeds from divestiture of businesses						$ 13,846,000
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
Period after closing of agreement for final determination of the customary adjustments to the purchase price	180 days
Restricted cash	$ 7,135,000				7,135,000
Percent difference in capitalized costs divided by proved reserves	220.00%
Gain (loss) recognized from property sales					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
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 | 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)
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
Oil and natural gas properties | Chauvin, Cessford and Rat Creek areas of Alberta
Oil and natural gas properties
Proceeds from divestiture of businesses			$ 4,581,000
Oil and natural gas properties | Boundary Lake area of Alberta and British Columbia
Oil and natural gas properties
Proceeds from divestiture of businesses		$ 6,120,000
Oil leaseholds | Mantario area of Saskatchewan
Oil and natural gas properties
Proceeds from divestiture of businesses				$ 2,726,000
Miscellaneous oil and natural gas properties
Oil and natural gas properties
Proceeds from divestiture of businesses						$ 692,000

PROPERTY AND EQUIPMENT AND AS55

PROPERTY AND EQUIPMENT AND ASSET RETIREMENT OBLIGATION (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Property and equipment
Gross Property and Equipment	$ 75,953	$ 223,023
Accumulated Depletion, Depreciation, and Amortization	(66,485)	(200,673)
Net Property and Equipment	9,468	22,350
Change in the asset retirement obligation
Balance at the beginning of the year	9,163	7,520
Obligations incurred on new wells drilled or acquired	316	105
Liabilities associated with properties sold	(2,013)	(718)
Revision of estimated obligation	918	2,437
Accretion expense	632	624
Payments	(655)	(111)
Foreign currency translation adjustment	(1,425)	(694)
Balance at the end of the year	6,936	9,163
Less current portion	(506)	(978)
Asset retirement obligation, long-term	6,430	8,185
Land
Property and equipment
Gross Property and Equipment	863	863
Net Property and Equipment	863	863
Oil and natural gas properties
Property and equipment
Gross Property and Equipment	63,105	209,702
Accumulated Depletion, Depreciation, and Amortization	(57,460)	(191,478)
Net Property and Equipment	5,645	18,224
Drilling rigs and equipment
Property and equipment
Gross Property and Equipment	6,598	6,759
Accumulated Depletion, Depreciation, and Amortization	(5,825)	(5,754)
Net Property and Equipment	$ 773	$ 1,005
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	$ 2,420	$ 2,420
Accumulated Depletion, Depreciation, and Amortization	(445)	(384)
Net Property and Equipment	1,975	2,036
Other property and equipment
Property and equipment
Gross Property and Equipment	2,967	3,279
Accumulated Depletion, Depreciation, and Amortization	(2,755)	(3,057)
Net Property and Equipment	$ 212	$ 222
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)	1 Months Ended	12 Months Ended
	Oct. 31, 2014USD ($)parcel	Sep. 30, 2015USD ($)	Sep. 30, 2014USD ($)	Sep. 30, 2015CAD	Sep. 30, 2015USD ($)	Apr. 10, 2015CAD	Mar. 31, 2015CAD
Long-term debt
Long-term debt			$ 11,099,000		$ 3,440,000
Less: current portion			(4,449,000)		(3,440,000)
Long-term debt			6,650,000		0
Canadian revolving credit facility
Long-term debt
Long-term debt			7,000,000		0
Long-term debt, additional disclosures
Maximum borrowing capacity				CAD 1,000,000	747,000	CAD 6,500,000	CAD 11,800,000
Unused credit available under the facility					713,000
Repayment of the credit facility		$ 7,000,000	5,000,000
Realized foreign currency transaction (gain) loss		$ 752,000	(271,000)
Standby fee charged on unused facility balance		0.625%
Renewal period with no required debt repayments		1 year
Required debt repayments on renewal of facility for one year		$ 0
Period of term loan if credit facility term date is not extended		2 years
Required compensating bank balances					0
Repayment schedule if the facility is converted to a two-year term loan
Percentage of outstanding loan balance to be repaid in first year of the term period		20.00%
Percentage of outstanding loan balance to be repaid per quarter in first year of the term period		5.00%
Percentage of outstanding loan balance to be repaid in second year of the term period		80.00%
Percentage of outstanding loan balance to be repaid per quarter for first three quarters in second year of the term period		5.00%
Percentage of outstanding loan balance to be repaid in the final quarter of the second year of the term period		65.00%
Canadian revolving credit facility | London Interbank Offer Rate
Long-term debt, additional disclosures
Interest rate base		LIBOR
Interest rate margin		2.50%
Canadian revolving credit facility | Base rate
Long-term debt, additional disclosures
Interest rate base		Royal Bank of Canada’s U.S. base rate
Interest rate margin		1.50%
Canadian revolving credit facility | Royal Bank of Canada's prime rate
Long-term debt, additional disclosures
Interest rate base		Royal Bank of Canada’s prime rate
Interest rate margin		1.50%
Letters of credit
Long-term debt, additional disclosures
Issued letters of credit					34,000
Real estate loan
Long-term debt
Long-term debt			$ 4,099,000		$ 3,440,000
Real estate loan, additional dislosures [Abstract]
Interest rate				3.59%	3.59%
Real estate loan | Investment in land
Real estate loan, additional dislosures [Abstract]
Number of residential parcels sold | parcel	1
Proceeds from sale of real estate	$ 1,145,000
Debt repaid as a result of the sale of one of the restricted parcels	473,000
Restricted cash and investments	$ 200,000				$ 242,000

RETIREMENT PLANS (Details)

RETIREMENT PLANS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Change in Plan Assets:
Fair value of plan assets at beginning of year	$ 7,022
Fair value of plan assets at end of year	6,488	$ 7,022
Amounts recognized in the Consolidated Balance Sheets:
Noncurrent liabilities	$ (5,409)	(4,266)
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	$ 8,299	6,858
Service cost	256	156
Interest cost	356	322
Actuarial loss	110	1,186
Benefits paid	(326)	(213)
Administrative expenses paid	(12)	(10)
Benefit obligation at end of year	8,683	8,299
Change in Plan Assets:
Fair value of plan assets at beginning of year	7,022	6,111
Actual return on plan assets	(446)	784
Employer contributions	250	350
Benefits paid	(326)	(213)
Administrative expenses paid	(12)	(10)
Fair value of plan assets at end of year	6,488	7,022
Funded status	(2,195)	(1,277)
Amounts recognized in the Consolidated Balance Sheets:
Noncurrent liabilities	(2,195)	(1,277)
Net amount	(2,195)	(1,277)
Amounts recognized in accumulated other comprehensive (loss) income:
Net actuarial loss (gain)	3,038	2,068
Prior service cost (credit)	77	81
Accumulated other comprehensive loss (income)	3,115	$ 2,149
Other disclosures
Expected contributions	$ 750
Assumptions used to determine fiscal year-end benefit obligations:
Discount rate	4.25%	4.25%
Rate of compensation increase	4.00%	4.00%
Assumptions used to determine net benefit costs (years ended):
Discount rate	4.25%	5.00%
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	$ 256	$ 156
Interest cost	356	322
Expected return on plan assets	(500)	(429)
Amortization of prior service cost (credit)	5	5
Amortization of net actuarial loss (gain)	86	20
Net periodic benefit cost	203	74
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
Net actuarial loss (gain)	135
Total amount	140
Accumulated benefit obligation	7,420	7,217
Expected Benefit Payments:
Fiscal year ending September 30, 2016	207
Fiscal year ending September 30, 2017	268
Fiscal year ending September 30, 2018	288
Fiscal year ending September 30, 2019	275
Fiscal year ending September 30, 2020	383
Fiscal years ending September 30, 2021 through 2025	2,380
SERP
Change in Projected Benefit Obligation:
Benefit obligation at beginning of year	1,767	1,322
Service cost	62	47
Interest cost	77	67
Actuarial loss	0	337
Benefits paid	(6)	(6)
Benefit obligation at end of year	1,900	1,767
Change in Plan Assets:
Employer contributions	6	6
Benefits paid	(6)	(6)
Funded status	(1,900)	(1,767)
Amounts recognized in the Consolidated Balance Sheets:
Current liabilities	(5)	(5)
Noncurrent liabilities	(1,895)	(1,762)
Net amount	(1,900)	(1,767)
Amounts recognized in accumulated other comprehensive (loss) income:
Net actuarial loss (gain)	506	530
Prior service cost (credit)	(76)	(80)
Accumulated other comprehensive loss (income)	$ 430	$ 450
Assumptions used to determine fiscal year-end benefit obligations:
Discount rate	4.25%	4.25%
Rate of compensation increase	4.00%	4.00%
Assumptions used to determine net benefit costs (years ended):
Discount rate	4.25%	5.00%
Rate of compensation increase	4.00%	4.00%
Net periodic benefit cost for the year:
Service cost	$ 62	$ 47
Interest cost	77	67
Amortization of prior service cost (credit)	(5)	(5)
Amortization of net actuarial loss (gain)	24	5
Net periodic benefit cost	158	114
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)
Net actuarial loss (gain)	19
Total amount	14
Accumulated benefit obligation	1,458	1,349
Expected Benefit Payments:
Fiscal year ending September 30, 2016	5
Fiscal year ending September 30, 2017	4
Fiscal year ending September 30, 2018	3
Fiscal year ending September 30, 2019	3
Fiscal year ending September 30, 2020	71
Fiscal years ending September 30, 2021 through 2025	$ 568
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	$ 1,227	1,073
Service cost	0	12
Interest cost	52	54
Actuarial loss	40	88
Benefit obligation at end of year	1,319	1,227
Change in Plan Assets:
Funded status	(1,319)	(1,227)
Amounts recognized in the Consolidated Balance Sheets:
Noncurrent liabilities	(1,319)	(1,227)
Net amount	(1,319)	(1,227)
Amounts recognized in accumulated other comprehensive (loss) income:
Net actuarial loss (gain)	(110)	(155)
Prior service cost (credit)		0
Accumulated other comprehensive loss (income)	$ (110)	$ (155)
Assumptions used to determine fiscal year-end benefit obligations:
Discount rate	4.25%	4.25%
Assumptions used to determine net benefit costs (years ended):
Discount rate	4.25%	5.00%
Net periodic benefit cost for the year:
Service cost	$ 0	$ 12
Interest cost	52	54
Amortization of prior service cost (credit)	0	12
Amortization of net actuarial loss (gain)	(5)	(21)
Net periodic benefit cost	47	$ 57
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)	(5)
Total amount	(5)
Expected Benefit Payments:
Fiscal year ending September 30, 2018	25
Fiscal year ending September 30, 2019	28
Fiscal year ending September 30, 2020	19
Fiscal years ending September 30, 2021 through 2025	$ 296
Assumed health care cost trend rates related to the measurement of entity's postretirement medical obligations
Health care cost trend rates assumed for next year	8.00%	7.50%
Ultimate cost trend rate	5.00%	5.00%
Year that the rate reaches the ultimate trend rate	2,028	2,020
Effects of one-percentage-point change in the assumed health care cost trend rates
Effect on total service and interest cost components, increase	$ 11
Effect on accumulated postretirement benefit obligations, increase	267
Effect on total service and interest cost components, decrease	(9)
Effect on accumulated postretirement benefit obligations, decrease	$ (212)

RETIREMENT PLANS - FAIR VALUE (

RETIREMENT PLANS - FAIR VALUE (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Plan assets
Entity's stock included in plan assets	$ 4
Pension plan assets at the fair value
Fair value measurements	6,488	$ 7,022
Quoted Prices in Active Markets (Level 1)
Pension plan assets at the fair value
Fair value measurements	$ 6,488	$ 7,022
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	9.00%	12.00%
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	22.00%	20.00%
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	69.00%	68.00%
Cash
Pension plan assets at the fair value
Fair value measurements	$ 621	$ 817
Cash | Quoted Prices in Active Markets (Level 1)
Pension plan assets at the fair value
Fair value measurements	621	817
Corporate bonds
Pension plan assets at the fair value
Fair value measurements	354	660
Corporate bonds | Quoted Prices in Active Markets (Level 1)
Pension plan assets at the fair value
Fair value measurements	354	660
Fixed income exchange-traded funds
Pension plan assets at the fair value
Fair value measurements	819	521
Fixed income exchange-traded funds | Quoted Prices in Active Markets (Level 1)
Pension plan assets at the fair value
Fair value measurements	819	521
Preferred securities
Pension plan assets at the fair value
Fair value measurements	230	232
Preferred securities | Quoted Prices in Active Markets (Level 1)
Pension plan assets at the fair value
Fair value measurements	230	232
Equity securities exchange- traded funds
Pension plan assets at the fair value
Fair value measurements	764	758
Equity securities exchange- traded funds | Quoted Prices in Active Markets (Level 1)
Pension plan assets at the fair value
Fair value measurements	764	758
Equities
Pension plan assets at the fair value
Fair value measurements	3,700	4,034
Equities | Quoted Prices in Active Markets (Level 1)
Pension plan assets at the fair value
Fair value measurements	$ 3,700	$ 4,034

INCOME TAXES (Details)

INCOME TAXES (Details) - USD ($) $ in Thousands	Jun. 29, 2015	Jun. 28, 2015	Sep. 30, 2015	Sep. 30, 2014
Components of income (loss) before income taxes, after adjusting the income (loss) for non-controlling interests
United States			$ 1,011	$ (629)
Canada			1,460	1,905
Total			2,471	1,276
Current (benefit) provision :
US Federal - Before operating loss carryforwards			0	886
US Federal - Benefit of operating loss carryforwards			0	(886)
After operating loss carryforwards			0	0
United States - State			94	(1)
Total United States			94	(1)
Canadian			1,529	1,312
Total current			1,623	1,311
Deferred benefit:
United States			(90)	0
Canadian			(325)	(707)
Total deferred			(415)	(707)
Total			$ 1,208	604
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 provision computed by applying statutory rate			$ 865	447
Increase in the valuation allowance - U.S. federal and Canadian tax law			1,653	584
Additional effect of the foreign tax provision on the total tax provision			(1,243)	(467)
Other			(67)	40
Total			1,208	604
Deferred income tax assets:
U.S. tax effect of deferred Canadian taxes			91	248
Foreign tax credit carryover			4,661	3,023
Alternative minimum tax credit carryover			460	460
U.S. federal net operating loss carryover			4,440	4,017
Tax basis of investment in land and residential real estate in excess of book basis			1,115	1,842
Property and equipment accumulated tax depreciation and depletion in excess of book under U.S. tax law			4,494	4,069
Liabilities accrued for books but not for tax under U.S. tax law			4,423	5,112
Liabilities accrued for books but not for tax under Canadian tax law			2,149	2,731
Other			746	2,098
Total gross deferred tax assets			22,579	23,600
Less valuation allowance			(21,387)	(20,869)
Net deferred income tax assets			1,192	2,731
Deferred income tax liabilities:
Property and equipment accumulated tax depreciation and depletion in excess of book under Canadian tax law			(1,459)	(3,460)
Other			(4)	(94)
Total deferred income tax liabilities			(1,463)	(3,554)
Net deferred income tax liability			(271)	(823)
Net deferred income tax liability included in Consolidated Balance Sheets:
Current deferred income tax asset (included in other current assets)			178	378
Deferred income tax liability			(449)	(1,201)
Net deferred income tax liability			(271)	(823)
Valuation allowance, other disclosures
Valuation allowance			21,387	$ 20,869
Increase in valuation allowance			518
Increase in valuation allowance recognized as income tax expense			307
Increase in valuation allowance charged to accumulated other comprehensive loss			211
Alternative minimum tax credit
Tax credit carryforward
Tax credit carryovers			460
Foreign
Tax credit carryforward
Tax credit carryovers			4,661
Valuation allowance, other disclosures
Alberta corporate tax rate	12.00%	10.00%
Canadian statutory tax rate	30.65%	28.75%
Foreign | Canada Revenue Agency
Deferred income tax assets:
Less valuation allowance			(1,028)
Valuation allowance, other disclosures
Valuation allowance			1,028
Federal
Tax credit carryforward
Operating loss carryovers			$ 13,060

INCOME TAXES - Unrecognized Tax

INCOME TAXES - Unrecognized Tax Benefits (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Changes in uncertain tax positions
Balance at the beginning of the period	$ 660	$ 704
Effect of tax positions taken in prior years	92	0
Accrued interest related to tax positions taken	38	14
Lapse of statute	(174)	0
Translation adjustments	(34)	(58)
Balance at the end of the period	582	660
Amount of unrecognized tax benefits that if recognized, would impact effective tax rate	582
Accrued interest	$ 113	$ 92

SEGMENT AND GEOGRAPHIC INFORM61

SEGMENT AND GEOGRAPHIC INFORMATION (Details) - USD ($)	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Revenues:
Total before gain on sale of investments and interest income	$ 17,479,000	$ 28,017,000
Gain on sale of investments	0	3,399,000
Interest income	54,000	29,000
Total revenues	17,533,000	31,445,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	3,364,000	6,391,000
Impairment:
Impairment of real estate held for sale	316,000	0
Operating (loss) profit (before general and administrative expenses):
Total operating profit (loss)	10,209,000	7,686,000
Equity in income (loss) of affiliates:
Equity in income (loss) of affiliates	1,580,000	(482,000)
General and administrative expenses	(8,551,000)	(8,026,000)
Interest expense	(315,000)	(664,000)
Gain on sale of investments	0	3,399,000
Interest income	54,000	29,000
Earnings before income taxes	2,977,000	1,942,000
Capital Expenditures:
Capital Expenditure	3,715,000	4,923,000
Assets By Segment:
Total assets	41,553,000	54,770,000
Land investment
Equity in income (loss) of affiliates:
Equity in income (loss) of affiliates	1,580,000	(482,000)
Intersegment elimination
Revenues:
Total revenues	0	0
Operating Segments | Oil and natural gas
Revenues:
Total before gain on sale of investments and interest income	9,008,000	20,298,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	2,987,000	5,968,000
Operating (loss) profit (before general and administrative expenses):
Total operating profit (loss)	(366,000)	5,416,000
Capital Expenditures:
Capital Expenditure	3,512,000	4,824,000
Assets By Segment:
Total assets	7,298,000	20,951,000
Operating Segments | Land investment
Revenues:
Total before gain on sale of investments and interest income	3,244,000	636,000
Operating (loss) profit (before general and administrative expenses):
Total operating profit (loss)	3,244,000	636,000
Assets By Segment:
Total assets	7,480,000	7,039,000
Operating Segments | Contract drilling
Revenues:
Total before gain on sale of investments and interest income	4,886,000	6,287,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	272,000	309,000
Operating (loss) profit (before general and administrative expenses):
Total operating profit (loss)	922,000	952,000
Capital Expenditures:
Capital Expenditure	124,000	48,000
Assets By Segment:
Total assets	2,338,000	1,849,000
Operating Segments | Residential real estate
Impairment:
Impairment of real estate held for sale	316,000	0
Operating (loss) profit (before general and administrative expenses):
Total operating profit (loss)	(316,000)	0
Assets By Segment:
Total assets	5,132,000	5,448,000
Corporate and Other
Revenues:
Total before gain on sale of investments and interest income	341,000	796,000
Depletion, depreciation, and amortization:
Depletion, depreciation, and amortization	105,000	114,000
Capital Expenditures:
Capital Expenditure	79,000	51,000
Assets By Segment:
Total assets	3,257,000	3,379,000
Corporate and Other | Cash and cash equivalents
Assets By Segment:
Total assets	8,471,000	16,104,000
Corporate and Other | Restricted cash
Assets By Segment:
Total assets	7,577,000	0
Other operating (loss) profit | Corporate and Other
Operating (loss) profit (before general and administrative expenses):
Total operating profit (loss)	236,000	682,000
Gain on sale of assets | Corporate and Other
Operating (loss) profit (before general and administrative expenses):
Total operating profit (loss)	$ 6,489,000	$ 0

SEGMENT AND GEOGRAPHIC INFORM62

SEGMENT AND GEOGRAPHIC INFORMATION - GEOGRAPHIC AREAS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Geographic information
Long-lived assets	$ 15,875	$ 28,250
Total revenue (excluding gain on sale of investments and interest income)	17,479	28,017
United States
Geographic information
Long-lived assets	10,135	9,884
Total revenue (excluding gain on sale of investments and interest income)	8,237	6,924
Canada
Geographic information
Long-lived assets	5,740	18,366
Total revenue (excluding gain on sale of investments and interest income)	$ 9,242	$ 21,093

ACCUMULATED OTHER COMPREHENSI63

ACCUMULATED OTHER COMPREHENSIVE (LOSS) INCOME (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Foreign currency translation:
Balance at beginning of period	$ 1,692	$ 3,701
Change in cumulative translation adjustment before reclassifications	(1,625)	(1,738)
Amounts reclassified from accumulated other comprehensive income	752	(271)
Income taxes	0	0
Net current period other comprehensive loss	(873)	(2,009)
Balance at end of the period	819	1,692
Retirement plans:
Balance at beginning of period	(1,950)	(710)
Amortization of net actuarial loss and prior service cost	105	16
Net actuarial loss arising during the period	(1,096)	(1,256)
Income taxes	0	0
Net current period other comprehensive loss	(991)	(1,240)
Balance at end of the period	(2,941)	(1,950)
Accumulated other comprehensive loss, net of taxes	$ (2,122)	$ (258)

FAIR VALUE MEASUREMENTS (Detail

FAIR VALUE MEASUREMENTS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Real estate held for sale	$ 5,132	$ 5,448
Impairment of real estate held for sale	316	$ 0
Fair Value, Inputs, Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Real estate held for sale	5,132
Impairment of real estate held for sale	$ 316

COMMITMENTS AND CONTINGENCIES65

COMMITMENTS AND CONTINGENCIES (Detail) - USD ($)	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Operating leases
Rental expense	$ 408,000	$ 548,000
Minimum rental payments
2,016	282,000
2,017	247,000
2,018	136,000
2,019	116,000
2,020	116,000
Thereafter through 2026	245,000
Total	1,142,000
Commitments and contingencies
Probable environmental remediation costs	$ 2,300,000
Percentage of working interest	58.00%
Insurance deductible	$ 80,000
Insurance recoveries	722,000
Estimated recovery from insurance	381,000
Environmental remediation expense	223,000
Accrual for environmental remediation costs	$ 75,000
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%
Amounts paid pursuant to the arrangement	$ 0	$ 0

INFORMATION RELATING TO THE C66

INFORMATION RELATING TO THE CONSOLIDATED STATEMENTS OF CASH FLOWS (Details) - USD ($) $ in Thousands	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Increase (decrease) from changes in:
Receivables	$ 324	$ 542
Other current assets	(447)	1,629
Accounts payable	(439)	(681)
Accrued compensation	(323)	(117)
Other current liabilities	(687)	976
(Decrease) increase from changes in current assets and liabilities	(1,572)	2,349
Supplemental disclosure of cash flow information:
Interest	306	646
Income taxes paid, net of refunds	1,812	765
Supplemental disclosure of non-cash investing and financing activities:
Receivable for proceeds on sale of investments	0	102
Supplemental disclosures of cash flow information:
Increase in capital expenditure accruals related to oil and natural gas asset retirement obligations	1,234	2,542
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	(61)	(1,195)
Increase in capital expenditure accruals related to oil and natural gas asset retirement obligations	$ 1,234	$ 2,542

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details) - Kaupulehu Developments $ in Thousands	10 Months Ended	12 Months Ended
	Sep. 30, 2014USD ($)lot	Sep. 30, 2015USD ($)lot	Sep. 30, 2014USD ($)
Related party transactions
Proceeds received from percentage of sales payments | $		$ 3,772	$ 740
KD Kaupulehu, LLLP | Investment in land development partnerships
Related party transactions
Ownership interest acquired		19.60%
Proceeds received from percentage of sales payments | $	$ 600	$ 3,772
Phase I | KD Kaupulehu, LLLP | Investment in land development partnerships
Related party transactions
Number of lots sold in Increment I | lot		6
Phase II | KD Kaupulehu, LLLP | Investment in land development partnerships
Related party transactions
Number of lots sold in Increment I | lot	2	11

SUPPLEMENTARY OIL AND NATURAL68

SUPPLEMENTARY OIL AND NATURAL GAS INFORMATION (UNAUDITED) (Details) bbl in Thousands, MMcf in Thousands, $ in Thousands	12 Months Ended
	Sep. 30, 2015USD ($)BoeMMcfbbl	Sep. 30, 2014USD ($)BoeMMcfbbl	Sep. 30, 2015USD ($)Boe	Sep. 30, 2014USD ($)
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	2,356,000	2,689,000
Revisions of previous estimates | Boe	(11,000)	499,000
Extensions, discoveries and other additions | Boe	1,000	67,000
Acquisitions of reserves | Boe	140,000
Less sales of reserves | Boe	(1,044,000)	(383,000)
Less production | Boe	(434,000)	(516,000)
Balance at the end of the period | Boe	1,008,000	2,356,000
Capitalized Costs Relating to Oil and Natural Gas Producing Activities
Proved properties			$ 62,960	$ 209,201
Unproved properties			145	501
Total capitalized costs			63,105	209,702
Accumulated depletion and depreciation			57,460	191,478
Net capitalized costs			5,645	18,224
Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development
Acquisition of unproved properties	$ 28	$ 42
Acquisition of proved properties	804	0
Exploration costs	0	884
Development costs	2,680	3,898
Total	3,512	4,824
Additions and revisions to asset retirement obligation included in development costs	1,234	2,542
Results of Operations for Oil and Natural Gas Producing Activities
Net revenues	9,008	20,298
Production costs	(6,387)	(8,914)
Depletion	(2,987)	(5,968)
Pre-tax results of operations	(366)	5,416
Estimated income tax expense	(921)	(1,557)
Results of operations	(1,287)	3,859
Standardized Measure of Discounted Future Net Cash Flows
Future cash inflows			27,749	82,912
Future production costs			(18,468)	(40,156)
Future development costs			(935)	(1,966)
Future income tax expenses			(2,361)	(9,671)
Future net cash flows			5,985	31,119
10% annual discount for timing of cash flows			(1,950)	(6,972)
Standardized measure of discounted future net cash flows	24,147	31,934	$ 4,035	$ 24,147
Changes in the Standardized Measure of Discounted Future Net Cash Flows
Beginning of year	24,147	31,934
Sales of oil and natural gas produced, net of production costs	(2,621)	(11,384)
Net changes in prices and production costs, net of royalties and wellhead taxes	(8,042)	8,670
Extensions and discoveries	1	2,199
Net change due to purchases and sales of minerals in place	(9,103)	(8,408)
Revisions of previous quantity estimates	634	4,862
Net change in income taxes	1,658	(4,148)
Accretion of discount	2,021	2,931
Other - changes in the timing of future production and other	(1,009)	(237)
Other - net change in Canadian dollar translation rate	(3,651)	(2,272)
Net change	(20,112)	(7,787)
End of year	$ 4,035	$ 24,147
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	724	923
Revisions of previous estimates | bbl	79	189
Extensions, discoveries and other additions | bbl	0	34
Acquisitions of reserves | bbl	46
Less sales of reserves | bbl	(237)	(238)
Less production | bbl	(143)	(184)
Balance at the end of the period | bbl	469	724
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	9,465	10,245
Revisions of previous estimates | MMcf	(520)	1,798
Extensions, discoveries and other additions | MMcf	3	189
Acquisitions of reserves | MMcf	543
Less sales of reserves | MMcf	(4,679)	(840)
Less production | MMcf	(1,688)	(1,927)
Balance at the end of the period | MMcf	3,124	9,465