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 (Bbls)		GAS (Mcf)		Total (Boe)
Proved reserves:
Balance at September 30, 2014	724,000		9,465,000		2,356,000
Revisions of previous estimates	79,000		(520,000	)	(11,000	)
Extensions, discoveries and other additions	—		3,000		1,000
Acquisitions of reserves	46,000		543,000		140,000
Less sales of reserves	(237,000	)	(4,679,000	)	(1,044,000	)
Less production	(143,000	)	(1,688,000	)	(434,000	)
Balance at September 30, 2015	469,000		3,124,000		1,008,000
Revisions of previous estimates	(23,000	)	(1,320,000	)	(251,000	)
Extensions, discoveries and other additions	54,000		95,000		70,000
Acquisitions of reserves	34,000		18,000		37,000
Less production	(84,000	)	(476,000	)	(166,000	)
Balance at September 30, 2016	450,000		1,441,000		698,000

(B) Capitalized Costs Relating to Oil and Natural Gas Producing Activities

All capitalized costs relating to oil and natural gas producing activities, which were being depleted in all years, are summarized as follows:



	September 30,
	2016		2015
Proved properties	$	66,044,000	$	62,960,000
Unproved properties	221,000		145,000
Total capitalized costs	66,265,000		63,105,000
Accumulated depletion and depreciation	61,060,000		57,460,000
Net capitalized costs	$	5,205,000	$	5,645,000



	Year ended September 30,
	2016		2015
Acquisition of properties:
Unproved	$	161,000	$	28,000
Proved	608,000		804,000
Exploration costs	—		—
Development costs	1,103,000		2,680,000
Total	$	1,872,000	$	3,512,000

Development costs incurred in the table above include additions and revisions to Barnwell’s asset retirement obligation of $99,000 and $1,234,000 for the years ended September 30, 2016 and 2015, respectively.

(D) Results of Operations for Oil and Natural Gas Producing Activities



	Year ended September 30,
	2016			2015
Net revenues	$	3,177,000		$	9,008,000
Production costs	(3,142,000		)	(6,387,000		)
Depletion	(1,236,000		)	(2,987,000		)
Impairment of assets	(1,154,000		)	—
Pre-tax results of operations (1)	(2,355,000		)	(366,000		)
Estimated income tax benefit (expense) (2)	297,000			(921,000		)
Results of operations (1)	$	(2,058,000	)	$	(1,287,000	)

_________________

(1) Before gain on sale of oil and natural gas properties, general and administrative expenses, interest expense, and foreign exchange gains and losses.

(2) Estimated income tax benefit (expense) includes charges to deferred income taxes for the valuation allowance necessary for the portion of Canadian tax law deferred tax assets that may not be realizable.

(E) Standardized Measure, Including Year-to-Year Changes Therein, of Estimated Discounted Future Net Cash Flows

The following tables utilize reserve and production data estimated by independent petroleum reserve engineers. The information may be useful for certain comparison purposes but should not be solely relied upon in evaluating Barnwell or its performance. Moreover, the projections should not be construed as realistic estimates of future cash flows, nor should the standardized measure be viewed as representing current value.

The estimated future cash flows at September 30, 2016 and 2015 were based on average sales prices in effect on the first day of the month for the preceding twelve month period in accordance with SEC Release No. 33-8995. The future production and development costs represent the estimated future expenditures that we will incur to develop and produce the proved reserves, assuming continuation of existing economic conditions. The future income tax expenses were computed by applying statutory income tax rates in existence at September 30, 2016 and 2015 to the future pre-tax net cash flows relating to proved reserves, net of the tax basis of the properties involved.

Material revisions to reserve estimates may occur in the future, development and production of the oil and natural gas reserves may not occur in the periods assumed and actual prices realized and actual costs incurred are expected to vary significantly from those used. Management does not rely upon this information in making investment and operating decisions; rather, those decisions are based upon a wide range of factors, including estimates of probable reserves as well as proved reserves and price and cost assumptions different than those reflected herein.

Standardized Measure of Discounted Future Net Cash Flows



	September 30,
	2016			2015
Future cash inflows	$	17,259,000		$	27,749,000
Future production costs	(11,951,000		)	(18,468,000		)
Future development costs	(426,000		)	(935,000		)
Future income tax expenses	(1,016,000		)	(2,361,000		)
Future net cash flows	3,866,000			5,985,000
10% annual discount for timing of cash flows	(956,000		)	(1,950,000		)
Standardized measure of discounted future net cash flows	$	2,910,000		$	4,035,000

Changes in the Standardized Measure of Discounted Future Net Cash Flows



	Year ended September 30,
	2016			2015
Beginning of year	$	4,035,000		$	24,147,000
Sales of oil and natural gas produced, net of production costs	(35,000		)	(2,621,000		)
Net changes in prices and production costs, net of royalties and wellhead taxes	(4,134,000		)	(8,042,000		)
Extensions and discoveries	1,285,000			1,000
Net change due to purchases and sales of minerals in place	470,000			(9,103,000		)
Revisions of previous quantity estimates	(343,000		)	634,000
Net change in income taxes	98,000			1,658,000
Accretion of discount	412,000			2,021,000
Other - changes in the timing of future production and other	1,018,000			(1,009,000		)
Other - net change in Canadian dollar translation rate	104,000			(3,651,000		)
Net change	(1,125,000		)	(20,112,000		)
End of year	$	2,910,000		$	4,035,000