DXI Capital (DXIEF) CORRESP Correspondence with SEC

Daniel M. Miller

Partner

(604) 630-5199

FAX (604) 687-8504

miller.dan@dorsey.com

January 8, 2013

Division of Corporation Finance

U.S. Securities and Exchange Commission

100 F Street N.E.

Washington, D.C. 20549

USA

Attention: H. Roger Schwall, Assistant Director

Re: Dejour Energy Inc.

Registration Statement on Form F-3

Filed August 27, 2012

File No. 333-183587

Form 20-F for Fiscal Year ended December 31, 2011

Filed April 30, 2012

File No. 001-33491

Dear Sirs and Mesdames:

On behalf of our client, Dejour Energy Inc. (the “Company”), and pursuant to the Securities Exchange Act of 1934, as amended (the “Act”), and the rules and regulations thereunder, we hereby transmit for your review a draft of Exhibit 99.2 to the Company’s Annual Report on Form 20-F for the fiscal year ended December 31, 2011, which Exhibit was inadvertently omitted from the Company’s response to the Staff’s letters of comments, dated September 14, 2012 and September 25, 2012 (the “Comment Letters”), which response was filed on January 3, 2013.

As always, should you have further comments or require further information, or if any questions should arise in connection with this submission, please call the undersigned at (604) 630-5199. You also may email or fax the undersigned at the contact information listed above.

	Yours truly,
	/s/ Daniel M. Miller
	Daniel M. Miller
cc:    Mathew Wong
Dejour Energy Inc.

October 7, 2012

Mr. Harrison Blacker

President

Dejour Energy (USA) Corp.

1401 17th Street, Suite 300

Denver, CO 80202

Subject: Reserve Estimate and Financial Forecast as to Dejour’s Interests in the KokopelliField Area, Garfield County, Colorado, and the South Rangely Field Area, RioBlanco County, Colorado-Amended in Response to SEC Comments

Dear Hal:

As you requested, Gustavson Associates has completed reserves and economics as to Dejour Energy’s interests in future oil and gas production associated with the Kokopelli Field Area located in Garfield County, Colorado and the South Rangely Field Area, Rio Blanco County, Colorado. Reserves have been estimated based on analysis of analogous well production data. Estimates and projections have been made as of January 1, 2012. Reserves have been estimated in accordance with the US Securities and Exchange Commission’s (SEC) definitions and guidelines, and was prepared for the purpose of inclusion as an exhibit in a filing made with the SEC. This report was completed on February 15, 2012, with revisions in response to SEC comments completed on the date of this letter, October 7, 2012.

In general, Proved Developed Non Producing (PDNP) reserves have been assigned to the South Rangely Federal 36-24A well, and Proved Undeveloped (PUD) reserves have been assigned to 77 total well locations. Of the PUD locations, 72 well locations are in the Kokopelli Field Area and 5 well locations are in the South Rangely Field Area. Gustavson is of the opinion that no current regulations, and no anticipated changes to regulations, would inhibit the ability of Dejour to recover the estimated reserves in the manner projected herein. It is our understanding that the reserves estimated herein represent all of Dejour’s US reserves.

The estimated net reserves volumes and associated net cash flow estimates are summarized below.

5757 Central Ave. Suite D Boulder, Co. 80301 USA 1-303-443-2209 FAX 1-303-443-3156 http://www.gustavson.com

Mr. Harrison Blacker

October 7, 2012

Page 2

Summary of Net Reserves and Projected Before Tax Cash Flow 

					Net
			Net		Heavy		Net		Net Present Value,
	Net Gas		Condensate		NGL		Ethane		thousands of US$
	Reserves		Reserves		Reserves		Reserves		Discounted at
Reserves Category	(MMCF)		(MBO)		(MBO)		(MBO)		0%		10%		15%
Proved Developed Non- Producing, Flat Pricing		158		0		6		8		577		282		218
Proved Undeveloped, Flat Pricing		41,156		287		1,617		2,232		134,689		32,621		17,151
Total Proved, Flat Pricing		41,314		287		1,623		2,240		135,266		32,903		17,369
Proved Developed Non- Producing, Forecast Pricing		158		0		6		8		868		364		271
Proved Undeveloped, Forecast Pricing		41,156		287		1,617		2,232		272,418		74,438		45,965
Total Proved, Forecast Pricing		41,314		287		1,623		2,240		273,286		74,802		46,236

The proportion of the company’s total reserves represented by the reserves included in this report is shown below.

Company Net Proved Reserves

Oil

Proportion

Location of Reserves

Gas

Condensate

NGL

Equivalent

of Oil Eq.

Country

Area

(MMCF)

(MBBL)

(MBBL)

(MBBL)

Reserves

United States

Colorado

41,314

287

3,863

11,036

96

%

Total Company

11,482

100

%

Note: Natural gas is converted to oil equivalent using a factor of 6,000 cubic feet of gas per one barrel of oil equivalent.

Kokopelli Field Area Assumptions, Garfield County, Colorado

Proved Undeveloped (PUD) reserves have been assigned to locations within the area delineated by successful wells and logged net pay, limited to the number of wells in Dejour’s five-year plan, comprising 72 locations with a drilling schedule starting with 8 wells drilled in the 4^th quarter of 2012, and 16 wells per year in 2013 through 2016. Significant upside to this amount includes an additional 21 locations that could be considered PUD but for the requirement in the latest SEC guidelines for commitment to drill within five years. The estimated ultimate recovery (EUR) for each location was based on the average performance of 65 wells in the immediate area. Many of these wells were completed in multiple zones, including Williams Fork, Rollins, Cozette, and Corcoran. The average EUR was based on the average composite performance of the total well production from each well, 978 MMCF.

Mr. Harrison Blacker

October 7, 2012

Page 3

This model includes production and revenue generated from natural gas liquids (NGLs). We have evaluated the gas sample report you provided. We have accounted for gas shrinkage and lower BTU after processing by adjusting the initial gas rate by the BTU content of the methane and 5% of the ethane as indicated in the gas sample report. We have also forecast NGL production as a ratio of gas production based on the liquids content displayed in the gas sample report, including 95% of the ethane and 100% of all heavier hydrocarbons.

Drilling was assumed to begin in May 2012, with expected drilling and completion costs of $1,637M per well. Initially, 4 wells are assumed to be drilled per month for two months in the 4^th quarter of 2012, coming on line two months after drilling. This program is followed by the drilling of 16 wells per year in 2013 through 2016.

Operating costs are estimated at $2,000 per well per month based on our experience with similar wells in the area. Abandonment costs of $10,000 were assumed. State and local production taxes are estimated at 7% of revenue. Oil prices were based on the average of the West Texas Intermediate (WTI) pricing from the first day of each month of 2011, adjusted each month by the average differential between Colorado pricing¹ and WTI. Similarly, gas prices were calculated for the posted gas prices at Henry Hub, adjusted for gas processing, transportation, and the differential to Colorado Interstate Gas (CIG) mainline pricing. For the forecast price case, NYMEX futures strips from December 28, 2011 were used for WTI (adjusted by the average oil price differential for 2011) and Henry Hub, adjusted by the futures strip for the CIG differential. After the end of the futures strip, prices were held flat. Cost and prices were held flat for the SEC base case, and escalated at 2% for the forecast case until flat pricing is reached. Thereafter costs were held flat. The first year price for ethane of $0.72/gallon was provided by the client and was used in the flat pricing case. For the forecast pricing case, the ethane price forecast was escalated with the gas price forecast. Heavier NGL prices were assumed to be 78.7% of the oil price based on the five year average NGL to crude price ratio reported by Bentek and the fraction of NGL’s indicated on the gas analysis. Heavier NGL prices were also adjusted by a $0.14/gallon NGL processing fee.

Dejour’s interests in the Kokopelli Field Area are reported to be 71.43% working interest with a 20% royalty burden for net revenue interest of 57.14%.

The estimated net reserves volumes and associated net cash flow estimates for the Kokopelli Field Area are summarized below.

¹http://tonto.eia.doe.gov/dnav/pet/pet_pri_dfp1_k_m.htm

Mr. Harrison Blacker

October 7, 2012

Page 4

					Net
					Heavy		Net		Net Present Value,
	Net Gas		Net Oil		NGL		Ethane		thousands of US$
	Reserves		Reserves		Reserves		Reserves		Discounted at
Reserves Category	(MMCF)		(MBO)		(MBO)		(MBO)		0%		10%		15%
Proved Undeveloped,Flat Pricing		40,235		287		1,584		2,186		132,304		32,077		16,926
Proved Undeveloped,Forecast Pricing		40,235		287		1,584		2,186		267,837		73,227		45,293

South Rangely Field Area Assumptions, Rio Blanco County, Colorado

The South Rangely 36-24A well was drilled and completed in late December 2011. Colorado wildlife restrictions prevent oil and gas activity until Spring of 2012. Dejour anticipates that the production equipment, pipeline infrastructure and hook-up will be completed in May 2012. We have assumed that the well will start producing in June 2012. We have assigned Proved Developed Non Producing (PDNP) reserves to the South Rangely Federal 36-24A well. We have also assigned Proved Undeveloped reserves to 5 well locations that are direct offsets to the South Rangely 36-24A well.

The estimated ultimate recovery (EUR) for the South Rangely Federal 36-24A and each of the undeveloped well locations was based on the average decline parameters from 28 wells in the immediate area, 460 MMCF. All of the analog wells are producing from the Mancos B formation and are located within 3 miles of the South Rangely Federal 36-24A. The EUR was based on the average decline curve parameters for each well and the average composite performance of the production from each well.

This evaluation includes production and revenue generated from natural gas liquids (NGLs). We have evaluated the gas sample report you provided. We have accounted for gas shrinkage and lower BTU after processing by adjusting the initial gas rate by the BTU content of the methane indicated in the gas sample report. We have also forecast heavy NGL and ethane production as a ratio of gas production based on the liquids content displayed in the gas sample report.

It was assumed that the South Rangely Federal 36-24A well will start producing in June 2012. At your request we have included a capital cost of $175,000 for the pipeline infrastructure and production equipment. The economics presented for the South Rangely 36-24A well, represent cash flows from the effective date, and so include Dejour’s share of completion and equipment costs but not drilling costs. It was assumed that 1 undeveloped well location would be drilled in April 2013, coming on line two months after drilling. Expected drilling and completion costs of $800M per well were assumed. That would be followed by the drilling of 2 wells in April 2014 and 2 wells in April 2015. Operating costs are estimated at $1,200 per well per month as provided by you and supported by our experience with similar wells in the area.

Mr. Harrison Blacker

October 7, 2012

Page 5

Abandonment costs of $10,000 were assumed. State and local production taxes are estimated at 7% of revenue. Oil prices were based on the average of the West Texas Intermediate (WTI) pricing from the first day of each month of 2011, adjusted each month by the average differential between Colorado pricing² and WTI. Similarly, gas prices were calculated for the posted gas prices at Henry Hub, adjusted for gas processing, transportation, and CIG differential. For the forecast price case, NYMEX futures strips from December 28, 2011, were used for WTI (adjusted by the average oil price differential for 2011) and Henry Hub, adjusted by the futures strip for the CIG differential. After the end of the futures strip, prices were held flat. Cost and prices were held flat for the SEC base case, and escalated at 2% for the forecast case until flat pricing is reached. Thereafter costs were held flat. The first year price for ethane of $0.72/gallon was provided by the client and was used in the flat pricing case. For the forecast pricing case, the ethane price forecast was escalated with the gas price forecast. Heavier NGL prices were assumed to be 73.9% of the oil price based on the five year average NGL to crude price ratio reported by Bentek and the fraction of NGL’s indicated on the gas analysis. Heavier NGL prices were also adjusted by a $0.14/gallon NGL processing fee.

We understand that for the South Rangely Federal 36-24A well Dejour Energy had a before drilling and completion interest of 50.0%. This includes a carry agreement with Robert L. Bayless Producer LLC. Dejour’s interests in the South Rangely Federal 36-24A after drilling and completion are reported to be 42.5% working interest with a 20% royalty burden for net revenue interest of 34.4%. It is our understanding that the carry agreement only applies to the South Rangely Federal 36-24A well and Dejour’s interests in the South Rangely Field Area are reported to be 42.5% working interest with a 20% royalty burden for net revenue interest of 34.4%.

The estimated net reserves volumes and associated net cash flow estimates for the South Rangely Field Area are summarized below.

A summary cash flow for each pricing scenario is included in Tables 1 through 8.

²http://tonto.eia.doe.gov/dnav/pet/pet_pri_dfp1_k_m.htm

Mr. Harrison Blacker

October 7, 2012

Page 6

					Net Heavy		Net		Net Present Value,
	Net Gas		Net Oil		NGL		Ethane		thousands of US$
	Reserves		Reserves		Reserves		Reserves		Discounted at
Reserves Category	(MMCF)		(MBO)		(MBO)		(MBO)		0%		10%		15%
Proved Developed Non- Producing, Flat Pricing		158		0		6		8		577		282		218
Proved Undeveloped, Flat Pricing		921		0		33		46		2,385		544		225
Total, Flat Pricing		1,078		0		39		53		2,962		826		443
Proved Developed Non- Producing, Forecast Pricing		158		0		6		8		868		364		271
Proved Undeveloped, Forecast Pricing		921		0		33		46		4,582		1,211		672
Total, Forecast Pricing		1,078		0		39		53		5,450		1,575		943

Limiting Conditions and Disclaimers

The accuracy of any reserve report or resource evaluation is a function of available data and of engineering and geologic interpretation and judgment. While the evaluation presented herein is believed to be reasonable, it should be viewed with the understanding that subsequent reservoir performance or changes in pricing structure, market demand, or other economic parameters may justify its revision. The assumptions, data, methods, and procedures used are appropriate for the purpose served by the report. Gustavson has used all methods and procedures as we considered necessary under the circumstances to prepare the report.

Gustavson Associates, LLC, holds neither direct nor indirect financial interest in the subject property, the company operating the subject acreage, or in any other affiliated companies.

All data and work files utilized in the preparation of this report are available for examination in our offices. Please contact us if we can be of assistance. We appreciate the opportunity to be of service and look forward to further serving Dejour Energy (USA) Corp.

Sincerely,

GUSTAVSON ASSOCIATES, LLC.

Letha C. Lencioni, P.E.

Vice-President, Petroleum Engineering

Registered Professional Engineer, State of Colorado, # 29506

Table 1 Summary Cash Flow Forecast, Proved Developed Non-Producing Reserves, Flat Pricing

PROVED DEVELOPED NON PRODUCING RESERVES	DATE	: 02/15/2012
TO THE INTEREST OF DEJOUR ENERGY (USA) CORP	TIME	: 10:40:00
	DBS	: Dejour1-12
	SETTINGS	: Dejour
	SCENARIO	: Dejour flat

RESERVES AND ECONOMICS

AS OF DATE: 01/2012

END	GROSS OIL			GROSS GAS		OIL TO NET		GAS TO NET		GROSS		PRICES		REVENUE TO		NET OPER		NET TOTAL		NET INCOME		CUMULATIVE		CUM DISC
MO-YEAR	PRODUCTION			PRODUCTION		INTEREST		INTEREST		OIL		GAS		INTEREST		EXPENSES		INVESTMENT		BEFORE FIT		NET INCOME		NET INCOME
	MB			MMF		MB		MMF		$/B		$/M		M$		M$		M$		M$		M$		M$
12-2012		0.000	��		47.306		0.000		16.261		0.00		3.140		110.825		11.328		175.000		-75.502		-75.502		-73.319
12-2013		0.000			55.813		0.000		19.186		0.00		3.140		130.756		15.273		0.000		115.483		39.980		26.779
12-2014		0.000			39.609		0.000		13.616		0.00		3.140		92.793		12.616		0.000		80.178		120.158		89.959
12-2015		0.000			30.685		0.000		10.548		0.00		3.140		71.886		11.152		0.000		60.734		180.893		133.466
12-2016		0.000			25.030		0.000		8.604		0.00		3.140		58.640		10.225		0.000		48.415		229.308		164.995
12-2017		0.000			21.127		0.000		7.262		0.00		3.140		49.494		9.585		0.000		39.910		269.217		188.622
12-2018		0.000			18.270		0.000		6.280		0.00		3.140		42.802		9.116		0.000		33.686		302.903		206.752
12-2019		0.000			16.090		0.000		5.531		0.00		3.140		37.694		8.759		0.000		28.935		331.839		220.910
12-2020		0.000			14.371		0.000		4.940		0.00		3.140		33.667		8.477		0.000		25.190		357.029		232.114
12-2021		0.000			12.981		0.000		4.462		0.00		3.140		30.412		8.249		0.000		22.163		379.192		241.076
12-2022		0.000			11.835		0.000		4.068		0.00		3.140		27.727		8.061		0.000		19.666		398.858		248.305
12-2023		0.000			10.873		0.000		3.738		0.00		3.140		25.473		7.903		0.000		17.570		416.428		254.177
12-2024		0.000			10.055		0.000		3.456		0.00		3.140		23.556		7.769		0.000		15.787		432.215		258.973
12-2025		0.000			9.350		0.000		3.214		0.00		3.140		21.905		7.653		0.000		14.252		446.467		262.909
12-2026		0.000			8.737		0.000		3.003		0.00		3.140		20.469		7.553		0.000		12.916		459.383		266.152
S TOT		0.000			332.132		0.000		114.171		0.00		3.140		778.100		143.717		175.000		459.383		459.383		266.152
AFTER		0.000			127.388		0.000		43.789		0.00		3.140		298.436		176.441		4.250		117.745		577.128		281.808
TOTAL		0.000			459.520		0.000		157.960		0.00		3.140		1076.536		320.158		179.250		577.128		577.128		281.808

	OIL		GAS
GROSS WELLS		0.0		1.0
GROSS ULT., MB & MMF		0.000		459.520
GROSS CUM., MB & MMF		0.000		0.000
GROSS RES., MB & MMF		0.000		459.520
NET RES., MB & MMF		0.000		157.960
NET REVENUE, M$		0.000		495.995
INITIAL PRICE, $		0.000		3.140
INITIAL N.I., PCT.		0.000		34.375

		P.W. %		P.W., M$
LIFE, YRS.	40.42		5.00		384.558
DISCOUNT %	10.00		10.00		281.808
UNDISCOUNTED PAYOUT, YRS.	1.65		15.00		217.899
DISCOUNTED PAYOUT, YRS.	1.73		20.00		174.017
UNDISCOUNTED NET/INVEST.	4.22		25.00		141.868
DISCOUNTED NET/INVEST.	2.67		30.00		117.240
RATE-OF-RETURN, PCT.	100.00		40.00		81.960
INITIAL W.I., PCT.	42.500		60.00		40.657
			80.00		17.640
			100.00		3.303

Table 2 Summary Cash Flow Forecast, All Proved Undeveloped, Flat Pricing

PROVED UNDEVELOPED RESERVES	DATE	: 02/15/2012
TO THE INTEREST OF DEJOUR ENERGY (USA) CORP	TIME	: 10:39:59
	DBS	: Dejour1-12
	SETTINGS	: Dejour
	SCENARIO	: Dejour flat

RESERVES AND ECONOMICS

AS OF DATE: 01/2012

END	GROSS OIL		GROSS GAS		OIL TO NET		GAS TO NET		GROSS		PRICES		REVENUE TO		NET OPER		NET TOTAL		NET INCOME		CUMULATIVE		CUM DISC
MO-YEAR	PRODUCTION		PRODUCTION		INTEREST		INTEREST		OIL		GAS		INTEREST		EXPENSES		INVESTMENT		BEFORE FIT		NET INCOME		NET INCOME
	MB		MMF		MB		MMF		$/B		$/M		M$		M$		M$		M$		M$		M$
12-2012		2.688		376.686		1.536		215.238		89.19		3.140		1532.264		124.402		9354.472		-7946.609		-7946.609		-7401.508
12-2013		20.678		2945.619		11.816		1672.358		89.19		3.140		11900.443		1076.606		19048.943		-8225.105		-16171.715		-14607.286
12-2014		31.517		4567.871		18.009		2575.838		89.19		3.140		18321.482		1810.059		19388.943		-2877.523		-19049.238		-16950.635
12-2015		38.857		5692.066		22.203		3209.938		89.19		3.140		22821.543		2414.653		19680.145		726.749		-18322.488		-16504.059
12-2016		44.596		6472.222		25.482		3663.674		89.19		3.140		26053.461		2922.461		18708.943		4422.062		-13900.426		-13676.339
12-2017		38.104		5506.346		21.773		3119.891		89.19		3.140		22189.555		2823.419		0.000		19366.139		5465.712		-2211.102
12-2018		26.744		3881.116		15.282		2196.222		89.19		3.140		15618.249		2363.430		0.000		13254.815		18720.527		4922.705
12-2019		21.750		3159.164		12.428		1787.094		89.19		3.140		12708.468		2159.745		0.000		10548.724		29269.252		10083.953
12-2020		18.648		2708.670		10.656		1532.145		89.19		3.140		10895.488		2032.836		0.000		8862.653		38131.902		14026.036
12-2021		16.472		2391.774		9.412		1352.942		89.19		3.140		9621.235		1943.639		0.000		7677.595		45809.500		17130.557
12-2022		14.836		2153.393		8.477		1218.203		89.19		3.140		8663.178		1876.574		0.000		6786.603		52596.105		19625.318
12-2023		13.552		1966.002		7.744		1112.315		89.19		3.140		7910.292		1823.872		0.000		6086.415		58682.520		21659.295
12-2024		12.510		1813.975		7.148		1026.425		89.19		3.140		7299.602		1781.125		0.000		5518.474		64200.992		23335.820
12-2025		11.645		1687.662		6.654		955.069		89.19		3.140		6792.248		1745.610		0.000		5046.641		69247.633		24729.621
12-2026		10.912		1580.722		6.235		894.661		89.19		3.140		6362.736		1715.544		0.000		4647.193		73894.820		25896.422
S TOT		323.510		46903.285		184.854		26532.010		89.19		3.140		188690.219		28613.975		86181.445		73894.820		73894.820		25896.422
AFTER		178.874		25809.479		102.209		14623.746		89.19		3.140		104014.812		42681.457		539.186		60794.172		134689.047		32621.184
TOTAL		502.384		72712.758		287.062		41155.758		89.19		3.140		292705.031		71295.430		86720.633		134688.984		134689.047		32621.184

	OIL		GAS
GROSS WELLS		0.0		77.0
GROSS ULT., MB & MMF		502.384		72712.750
GROSS CUM., MB & MMF		0.000		0.000
GROSS RES., MB & MMF		502.384		72712.750
NET RES., MB & MMF		287.062		41155.766
NET REVENUE, M$		25603.068		129229.172
INITIAL PRICE, $		89.190		3.140
INITIAL N.I., PCT.		57.140		57.140

		P.W. %		P.W., M$
LIFE, YRS.	44.92		5.00		62787.066
DISCOUNT %	10.00		10.00		32621.184
UNDISCOUNTED PAYOUT, YRS.	5.72		15.00		17150.938
DISCOUNTED PAYOUT, YRS.	6.31		20.00		8204.233
UNDISCOUNTED NET/INVEST.	2.55		25.00		2644.614
DISCOUNTED NET/INVEST.	1.49		30.00		-966.989
RATE-OF-RETURN, PCT.	28.66		40.00		-5016.071
INITIAL W.I., PCT.	71.104		60.00		-7748.250
			80.00		-8119.618
			100.00		-7835.503

Table 3 Summary Cash Flow Forecast, Proved Developed Non-Producing Reserves, Forecast Pricing

PROVED DEVELOPED NON PRODUCING RESERVES	DATE	: 02/15/2012
TO THE INTEREST OF DEJOUR ENERGY (USA) CORP	TIME	: 10:59:07
	DBS	: Dejour1-12
	SETTINGS	: Dejour
	SCENARIO	: Dejour

RESERVES AND ECONOMICS

AS OF DATE: 01/2012

END	GROSS OIL		GROSS GAS		OIL TO NET		GAS TO NET		GROSS		PRICES-		REVENUE TO		NET OPER		NET TOTAL		NET INCOME		CUMULATIVE		CUM DISC
MO-YEAR	PRODUCTION		PRODUCTION		INTEREST		INTEREST		OIL		GAS		INTEREST		EXPENSES		INVESTMENT		BEFORE FIT		NET INCOME		NET INCOME
	MB		MMF		MB		MMF		$/B		$/M		M$		M$		M$		M$		M$		M$
12-2012		0.000		47.306		0.000		16.261		0.00		2.500		101.799		10.714		175.000		-83.914		-83.914		-81.340
12-2013		0.000		55.813		0.000		19.186		0.00		3.170		137.382		15.864		0.000		121.518		37.604		23.990
12-2014		0.000		39.609		0.000		13.616		0.00		3.530		103.739		13.634		0.000		90.104		127.708		94.991
12-2015		0.000		30.685		0.000		10.548		0.00		3.610		81.180		12.183		0.000		68.997		196.705		144.417
12-2016		0.000		25.030		0.000		8.604		0.00		3.860		69.403		11.488		0.000		57.915		254.620		182.133
12-2017		0.000		21.127		0.000		7.262		0.00		4.130		61.580		11.073		0.000		50.507		305.127		212.034
12-2018		0.000		18.270		0.000		6.280		0.00		4.410		56.001		10.818		0.000		45.183		350.310		236.352
12-2019		0.000		16.090		0.000		5.531		0.00		4.680		51.674		10.653		0.000		41.021		391.331		256.423
12-2020		0.000		14.371		0.000		4.940		0.00		4.950		48.284		10.556		0.000		37.728		429.059		273.204
12-2021		0.000		12.981		0.000		4.462		0.00		5.220		45.459		10.502		0.000		34.957		464.016		287.339
12-2022		0.000		11.835		0.000		4.068		0.00		5.490		43.135		10.486		0.000		32.649		496.665		299.341
12-2023		0.000		10.873		0.000		3.738		0.00		5.770		41.213		10.501		0.000		30.712		527.377		309.604
12-2024		0.000		10.055		0.000		3.456		0.00		6.050		39.587		10.539		0.000		29.048		556.425		318.429
12-2025		0.000		9.350		0.000		3.214		0.00		6.050		36.812		10.492		0.000		26.320		582.745		325.699
12-2026		0.000		8.737		0.000		3.003		0.00		6.050		34.398		10.323		0.000		24.075		606.820		331.743
S TOT		0.000		332.132		0.000		114.171		0.00		3.982		951.648		169.828		175.000		606.820		606.820		331.743
AFTER		0.000		127.388		0.000		43.789		0.00		6.050		501.534		236.285		4.250		260.998		867.818		363.538
TOTAL		0.000		459.520		0.000		157.960		0.00		4.555		1453.181		406.113		179.250		867.818		867.818		363.538

	OIL		GAS
GROSS WELLS		0.0		1.0
GROSS ULT., MB & MMF		0.000		459.520
GROSS CUM., MB & MMF		0.000		0.000
GROSS RES., MB & MMF		0.000		459.520
NET RES., MB & MMF		0.000		157.960
NET REVENUE, M$		0.000		719.501
INITIAL PRICE, $		0.000		2.500
INITIAL N.I., PCT.		0.000		34.375

		P.W. %		P.W., M$
LIFE, YRS.	40.42		5.00		525.482
DISCOUNT %	10.00		10.00		363.538
UNDISCOUNTED PAYOUT, YRS.	1.69		15.00		270.799
DISCOUNTED PAYOUT, YRS.	1.77		20.00		210.709
UNDISCOUNTED NET/INVEST.	5.84		25.00		168.507
DISCOUNTED NET/INVEST.	3.16		30.00		137.193
RATE-OF-RETURN, PCT.	100.00		40.00		93.811
INITIAL W.I., PCT.	42.500		60.00		45.110
			80.00		18.893
			100.00		2.892

Table 4 Summary Cash Flow Forecast, All Proved Undeveloped, Forecast Pricing

PROVED UNDEVELOPED RESERVES	DATE	: 03/09/2012
TO THE INTEREST OF DEJOUR ENERGY (USA) CORP	TIME	: 10:07:44
	SETTINGS	: Dejour
	SCENARIO	: Dejour

 RESERVES AND ECONOMICS

AS OF DATE: 01/2012

END	GROSS OIL		GROSS GAS		OIL TO NET		GAS TO NET		GROSS		PRICES		REVENUE TO		NET OPER		NET TOTAL		NET INCOME		CUMULATIVE		CUM DISC
MO-YEAR	PRODUCTION		PRODUCTION		INTEREST		INTEREST		OIL		GAS		INTEREST		EXPENSES		INVESTMENT		BEFORE FIT		NET INCOME		NET INCOME
	MB		MMF		MB		MMF		$/B		$/M		M$		M$		M$		M$		M$		M$
12-2012		2.688		376.686		1.536		215.238		84.66		2.500		1587.932		128.308		9354.472		-7894.848		-7894.848		-7352.157
12-2013		20.678		2945.619		11.816		1672.358		89.39		3.170		13911.364		1219.457		19048.943		-6357.034		-14251.882		-12938.718
12-2014		31.517		4567.871		18.009		2575.838		86.24		3.530		22530.258		2114.253		19388.943		1027.065		-13224.817		-12205.306
12-2015		38.857		5692.066		22.203		3209.938		84.58		3.600		28209.018		2814.730		19680.145		5714.146		-7510.671		-8186.007
12-2016		44.596		6472.222		25.482		3663.674		83.96		3.860		33632.285		3495.350		18708.943		11427.990		3917.319		-795.835
12-2017		38.104		5506.346		21.773		3119.891		84.01		4.130		29985.846		3436.386		0.000		26549.477		30466.797		14922.121
12-2018		26.744		3881.116		15.282		2196.222		84.41		4.410		22101.201		2911.208		0.000		19189.996		49656.793		25250.268
12-2019		21.750		3159.164		12.428		1787.094		85.01		4.680		18780.906		2706.071		0.000		16074.844		65731.633		33115.320
12-2020		18.648		2708.670		10.656		1532.145		85.80		4.950		16796.090		2594.961		0.000		14201.132		79932.766		39431.945
12-2021		16.472		2391.774		9.412		1352.942		85.80		5.220		15409.252		2526.267		0.000		12882.982		92815.750		44641.320
12-2022		14.836		2153.393		8.477		1218.203		85.80		5.490		14398.222		2484.447		0.000		11913.772		104729.523		49020.832
12-2023		13.552		1966.002		7.744		1112.315		85.80		5.770		13633.533		2460.450		0.000		11173.083		115902.602		52754.684
12-2024		12.510		1813.975		7.148		1026.425		85.80		6.050		13033.952		2448.603		0.000		10585.345		126487.945		55970.535
12-2025		11.645		1687.662		6.654		955.069		85.80		6.050		12128.290		2460.441		0.000		9667.858		136155.812		58640.645
12-2026		10.912		1580.722		6.235		894.661		85.80		6.050		11361.588		2406.772		0.000		8954.818		145110.625		60888.988
S TOT		323.510		46903.285		184.854		26532.010		85.28		4.399		267499.750		36207.699		86181.445		145110.625		145110.625		60888.988
AFTER		178.874		25809.479		102.209		14623.746		85.80		6.050		185763.156		57916.332		539.186		127307.625		272418.312		74438.078
TOTAL		502.384		72712.758		287.062		41155.758		85.47		4.986		453262.906		94124.031		86720.633		272418.250		272418.312		74438.078

	OIL		GAS
GROSS WELLS		0.0		77.0
GROSS ULT., MB & MMF		502.384		72712.750
GROSS CUM., MB & MMF		0.000		0.000
GROSS RES., MB & MMF		502.384		72712.750
NET RES., MB & MMF		287.062		41155.766
NET REVENUE, M$		24534.500		205191.734
INITIAL PRICE, $		85.889		3.425
INITIAL N.I., PCT.		57.140		57.140

		P.W. %		P.W., M$
LIFE, YRS.	44.92		5.00		131137.016
DISCOUNT %	10.00		10.00		74438.109
UNDISCOUNTED PAYOUT, YRS.	4.66		15.00		45965.465
DISCOUNTED PAYOUT, YRS.	5.05		20.00		29533.023
UNDISCOUNTED NET/INVEST.	4.14		25.00		19194.354
DISCOUNTED NET/INVEST.	2.11		30.00		12312.014
RATE-OF-RETURN, PCT.	49.68		40.00		4154.675
INITIAL W.I., PCT.	71.133		60.00		-2535.021
			80.00		-4714.718
			100.00		-5414.064

Table 5 Summary Cash Flow Forecast, Proved Undeveloped, Kokopelli Field Area, Flat Pricing

PROVED UNDEVELOPED RESERVES	DATE	: 02/10/2012
TO THE INTEREST OF DEJOUR ENERGY (USA) CORP	DATE	: 02/10/2012
KOKOPELLI FIELD AREA	TIME	: 15:32:21
	DBS	: Dejour1-12
	SETTINGS	: SETDATA
	SCENARIO	: Dejour flat

RESERVES AND ECONOMICS

AS OF DATE: 01/2012

END	GROSS OIL		GROSS GAS		OIL TO NET		GAS TO NET		GROSS		PRICES		REVENUE TO		NET OPER		NET TOTAL		NET INCOME		CUMULATIVE		CUM DISC
MO-YEAR	PRODUCTION		PRODUCTION		INTEREST		INTEREST		OIL		GAS		INTEREST		EXPENSES		INVESTMENT		BEFORE FIT		NET INCOME		NET INCOME
	MB		MMF		MB		MMF		$/B		$/M		M$		M$		M$		M$		M$		M$
12-2012		2.688		376.686		1.536		215.238		89.19		3.140		1532.264		124.402		9354.472		-7946.609		-7946.609		-7401.508
12-2013		20.678		2898.314		11.816		1656.097		89.19		3.140		11789.618		1065.278		18708.943		-7984.603		-15931.212		-14391.715
12-2014		31.517		4417.446		18.009		2524.129		89.19		3.140		17969.078		1772.131		18708.943		-2512.001		-18443.215		-16434.115
12-2015		38.857		5446.219		22.203		3111.969		89.19		3.140		22153.863		2339.357		18708.943		1105.565		-17337.648		-15699.398
12-2016		44.596		6250.693		25.482		3571.644		89.19		3.140		25426.256		2842.715		18708.943		3874.603		-13463.045		-13228.198
12-2017		38.104		5340.729		21.773		3051.691		89.19		3.140		21724.756		2755.042		0.000		18969.715		5506.669		-1997.652
12-2018		26.744		3748.559		15.282		2141.926		89.19		3.140		15248.208		2301.685		0.000		12946.518		18453.188		4970.227
12-2019		21.750		3048.580		12.428		1741.959		89.19		3.140		12400.867		2102.371		0.000		10298.496		28751.684		10009.044
12-2020		18.648		2613.787		10.656		1493.518		89.19		3.140		10632.238		1978.567		0.000		8653.671		37405.355		13858.174
12-2021		16.472		2308.683		9.412		1319.181		89.19		3.140		9391.151		1891.691		0.000		7499.458		44904.816		16890.664
12-2022		14.836		2079.490		8.477		1188.221		89.19		3.140		8458.848		1826.430		0.000		6632.417		51537.230		19328.748
12-2023		13.552		1899.463		7.744		1085.353		89.19		3.140		7726.542		1775.168		0.000		5951.370		57488.602		21317.594
12-2024		12.510		1753.469		7.148		1001.932		89.19		3.140		7132.682		1733.598		0.000		5399.080		62887.680		22957.848
12-2025		11.645		1632.190		6.654		932.633		89.19		3.140		6639.345		1699.065		0.000		4940.282		67827.961		24322.275
12-2026		10.912		1529.515		6.235		873.965		89.19		3.140		6221.689		1669.829		0.000		4551.861		72379.820		25465.141
S TOT		323.510		45343.824		184.854		25909.455		89.19		3.140		184447.422		27877.332		84190.250		72379.820		72379.820		25465.141
AFTER		178.874		25071.340		102.209		14325.764		89.19		3.140		101983.992		41545.281		514.296		59924.426		132304.250		32076.682
TOTAL		502.384		70415.172		287.062		40235.219		89.19		3.140		286431.438		69422.609		84704.547		132304.250		132304.250		32076.682

	OIL		GAS
GROSS WELLS		0.0		72.0
GROSS ULT., MB & MMF		502.384		70415.172
GROSS CUM., MB & MMF		0.000		0.000
GROSS RES., MB & MMF		502.384		70415.172
NET RES., MB & MMF		287.062		40235.230
NET REVENUE, M$		25603.068		126338.680
INITIAL PRICE, $		89.190		3.140
INITIAL N.I., PCT.		57.140		57.140

		P.W. %		P.W., M$
LIFE, YRS.	44.92		5.00		61651.262
DISCOUNT %	10.00		10.00		32076.684
UNDISCOUNTED PAYOUT, YRS.	5.71		15.00		16926.072
DISCOUNTED PAYOUT, YRS.	6.29		20.00		8166.321
UNDISCOUNTED NET/INVEST.	2.56		25.00		2721.069
DISCOUNTED NET/INVEST.	1.49		30.00		-819.025
RATE-OF-RETURN, PCT.	28.84		40.00		-4795.549
INITIAL W.I., PCT.	71.430		60.00		-7499.122
			80.00		-7887.855
			100.00		-7629.401

Table 6 Summary Cash Flow Forecast, Proved Undeveloped, Kokopelli Field Area, Forecast Pricing

PROVED UNDEVELOPED RESERVES	DATE	: 05/23/2012
TO THE INTEREST OF DEJOUR ENERGY (USA) CORP	TIME	: 13:31:23
KOKOPELLI FIELD AREA	DBS	: Dejour1-12
	SETTINGS	: Dejour
	SCENARIO	: Dejour

RESERVES AND ECONOMICS

 AS OF DATE: 01/2012

END	GROSS OIL		GROSS GAS		OIL TO NET		GAS TO NET		GROSS		PRICES		REVENUE TO		NET OPER		NET TOTAL		NET INCOME		CUMULATIVE		CUM DISC
MO-YEAR	PRODUCTION		PRODUCTION		INTEREST		INTEREST		OIL		GAS		INTEREST		EXPENSES		INVESTMENT		BEFORE FIT		NET INCOME		NET INCOME
	MB		MMF		MB		MMF		$/B		$/M		M$		M$		M$		M$		M$		M$
12-2012		2.688		376.686		1.536		215.238		84.66		2.500		1587.932		128.308		9354.472		-7894.848		-7894.848		-7352.157
12-2013		20.678		2898.314		11.816		1656.097		89.39		3.170		13794.922		1207.718		18708.943		-6121.738		-14016.586		-12727.660
12-2014		31.517		4417.446		18.009		2524.129		86.24		3.530		22136.281		2073.252		18708.943		1354.092		-12662.494		-11723.636
12-2015		38.857		5446.219		22.203		3111.969		84.58		3.600		27455.020		2732.834		18708.943		6013.244		-6649.250		-7473.300
12-2016		44.596		6250.693		25.482		3571.644		83.96		3.860		32889.949		3406.295		18708.943		10774.714		4125.464		-508.562
12-2017		38.104		5340.729		21.773		3051.691		84.01		4.130		29407.553		3358.072		0.000		26049.498		30174.963		14913.393
12-2018		26.744		3748.559		15.282		2141.926		84.41		4.410		21617.051		2838.728		0.000		18778.326		48953.289		25019.979
12-2019		21.750		3048.580		12.428		1741.959		85.01		4.680		18359.217		2637.190		0.000		15722.034		64675.320		32712.408
12-2020		18.648		2613.787		10.656		1493.518		85.80		4.950		16418.547		2528.385		0.000		13890.166		78565.484		38890.715
12-2021		16.472		2308.683		9.412		1319.181		85.80		5.220		15065.331		2461.240		0.000		12604.086		91169.578		43987.320
12-2022		14.836		2079.490		8.477		1188.221		85.80		5.490		14080.335		2420.424		0.000		11659.911		102829.484		48273.512
12-2023		13.552		1899.463		7.744		1085.353		85.80		5.770		13336.248		2397.034		0.000		10939.214		113768.703		51929.207
12-2024		12.510		1753.469		7.148		1001.932		85.80		6.050		12753.436		2385.508		0.000		10367.924		124136.625		55079.008
12-2025		11.645		1632.190		6.654		932.633		85.80		6.050		11871.330		2396.099		0.000		9475.239		133611.859		57695.914
12-2026		10.912		1529.515		6.235		873.965		85.80		6.050		11124.554		2343.824		0.000		8780.731		142392.594		59900.551
S TOT		323.510		45343.824		184.854		25909.455		85.28		4.398		261897.719		35314.906		84190.250		142392.594		142392.594		59900.551
AFTER		178.874		25071.340		102.209		14325.764		85.80		6.050		182350.266		56391.832		514.296		125444.133		267836.750		73226.742
TOTAL		502.384		70415.172		287.062		40235.219		85.47		4.986		444248.000		91706.734		84704.547		267836.750		267836.750		73226.742

	OIL		GAS
GROSS WELLS		0.0		72.0
GROSS ULT., MB & MMF		502.384		70415.172
GROSS CUM., MB & MMF		0.000		0.000
GROSS RES., MB & MMF		502.384		70415.172
NET RES., MB & MMF		287.062		40235.230
NET REVENUE, M$		24534.500		200616.906
INITIAL PRICE, $		85.889		3.424
INITIAL N.I., PCT.		57.140		57.140

		P.W. %		P.W., M$
LIFE, YRS.	44.92		5.00		128895.672
DISCOUNT %	10.00		10.00		73226.773
UNDISCOUNTED PAYOUT, YRS.	4.62		15.00		45293.055
DISCOUNTED PAYOUT, YRS.	5.03		20.00		29173.762
UNDISCOUNTED NET/INVEST.	4.16		25.00		19029.072
DISCOUNTED NET/INVEST.	2.12		30.00		12271.802
RATE-OF-RETURN, PCT.	50.09		40.00		4252.437
INITIAL W.I., PCT.	71.430		60.00		-2349.031
			80.00		-4520.785
			100.00		-5232.880

Table 7 Summary Cash Flow Forecast, Proved Undeveloped, South Rangely Field Area, Flat Pricing

PROVED UNDEVELOPED RESERVES	DATE	: 02/15/2012
TO THE INTEREST OF DEJOUR ENERGY (USA) CORP	TIME	: 15:32:17
SOUTH RANGELY FIELD AREA	DBS	: Dejour1-12
	SETTINGS	: Dejour
	SCENARIO	: Dejour flat

RESERVES AND ECONOMICS

AS OF DATE: 01/2012

END	GROSS OIL		GROSS GAS		OIL TO NET		GAS TO NET		GROSS		PRICES		REVENUE TO		NET OPER		NET TOTAL		NET INCOME		CUMULATIVE		CUM DISC
MO-YEAR	PRODUCTION		PRODUCTION		INTEREST		INTEREST		OIL		GAS		INTEREST		EXPENSES		INVESTMENT		BEFORE FIT		NET INCOME		NET INCOME
	MB		MMF		MB		MMF		$/B		$/M		M$		M$		M$		M$		M$		M$
12-2012		0.000		0.000		0.000		0.000		0.00		0.000		0.000		0.000		0.000		0.000		0.000		0.000
12-2013		0.000		47.306		0.000		16.261		0.00		3.140		110.825		11.328		340.000		-240.502		-240.502		-215.570
12-2014		0.000		150.425		0.000		51.709		0.00		3.140		352.407		37.928		680.000		-365.522		-606.024		-516.517
12-2015		0.000		245.847		0.000		97.968		0.00		3.140		667.679		75.295		971.200		-378.816		-984.841		-804.659
12-2016		0.000		221.529		0.000		92.029		0.00		3.140		627.203		79.746		0.000		547.458		-437.383		-448.139
12-2017		0.000		165.618		0.000		68.200		0.00		3.140		464.798		68.377		0.000		396.421		-40.962		-213.448
12-2018		0.000		132.557		0.000		54.296		0.00		3.140		370.042		61.745		0.000		308.298		267.335		-47.521
12-2019		0.000		110.584		0.000		45.134		0.00		3.140		307.602		57.374		0.000		250.228		517.564		74.910
12-2020		0.000		94.883		0.000		38.627		0.00		3.140		263.250		54.269		0.000		208.981		726.545		167.865
12-2021		0.000		83.090		0.000		33.760		0.00		3.140		230.084		51.947		0.000		178.137		904.682		239.896
12-2022		0.000		73.902		0.000		29.981		0.00		3.140		204.331		50.145		0.000		154.186		1058.868		296.575
12-2023		0.000		66.540		0.000		26.962		0.00		3.140		183.749		48.704		0.000		135.045		1193.913		341.705
12-2024		0.000		60.506		0.000		24.492		0.00		3.140		166.921		47.526		0.000		119.395		1313.308		377.977
12-2025		0.000		55.472		0.000		22.435		0.00		3.140		152.903		46.545		0.000		106.358		1419.666		407.352
12-2026		0.000		51.207		0.000		20.696		0.00		3.140		141.047		45.715		0.000		95.332		1514.998		431.287
S TOT		0.000		1559.467		0.000		622.552		0.00		3.140		4242.842		736.644		1991.200		1514.998		1514.998		431.287
AFTER		0.000		738.134		0.000		297.982		0.00		3.140		2030.817		1136.176		24.890		869.751		2384.749		544.499
TOTAL		0.000		2297.600		0.000		920.534		0.00		3.140		6273.659		1872.820		2016.090		2384.749		2384.749		544.499

	OIL		GAS
GROSS WELLS		0.0		5.0
GROSS ULT., MB & MMF		0.000		2297.601
GROSS CUM., MB & MMF		0.000		0.000
GROSS RES., MB & MMF		0.000		2297.601
NET RES., MB & MMF		0.000		920.533
NET REVENUE, M$		0.000		2890.476
INITIAL PRICE, $		0.000		3.140
INITIAL N.I., PCT.		0.000		34.375

		P.W. %		P.W., M$
LIFE, YRS.	43.42		5.00		1135.811
DISCOUNT %	10.00		10.00		544.499
UNDISCOUNTED PAYOUT, YRS.	6.13		15.00		224.870
DISCOUNTED PAYOUT, YRS.	7.39		20.00		37.912
UNDISCOUNTED NET/INVEST.	2.18		25.00		-76.455
DISCOUNTED NET/INVEST.	1.35		30.00		-147.964
RATE-OF-RETURN, PCT.	21.66		40.00		-220.523
INITIAL W.I., PCT.	49.780		60.00		-249.129
			80.00		-231.762
			100.00		-206.103

Table 8 Summary Cash Flow Forecast, Proved Undeveloped, South Rangely Field Area, Forecast Pricing

PROVED UNDEVELOPED RESERVES	DATE	: 02/15/2012
TO THE INTEREST OF DEJOUR ENERGY (USA) CORP	TIME	: 15:40:09
SOUTH RANGELY FIELD AREA	DBS	: Dejour1-12
	SETTINGS	: Dejour
	SCENARIO	: Dejour

RESERVES AND ECONOMICS

AS OF DATE: 01/2012

END	GROSS OIL		GROSS GAS		OIL TO NET		GAS TO NET		GROSS		PRICES		REVENUE TO		NET OPER		NET TOTAL		NET INCOME		CUMULATIVE		CUM DISC
MO-YEAR	PRODUCTION		PRODUCTION		INTEREST		INTEREST		OIL		GAS		INTEREST		EXPENSES		INVESTMENT		BEFORE FIT		NET INCOME		NET INCOME
	MB		MMF		MB		MMF		$/B		$/M		M$		M$		M$		M$		M$		M$
12-2012		0.000		0.000		0.000		0.000		0.00		0.000		0.000		0.000		0.000		0.000		0.000		0.000
12-2013		0.000		47.306		0.000		16.261		0.00		3.170		116.442		11.739		340.000		-235.297		-235.297		-211.058
12-2014		0.000		150.425		0.000		51.709		0.00		3.530		393.974		41.001		680.000		-327.027		-562.324		-481.672
12-2015		0.000		245.847		0.000		97.968		0.00		3.610		753.997		81.896		971.200		-299.099		-861.423		-712.708
12-2016		0.000		221.529		0.000		92.029		0.00		3.860		742.333		89.055		0.000		653.278		-208.145		-287.275
12-2017		0.000		165.618		0.000		68.200		0.00		4.130		578.294		78.314		0.000		499.980		291.835		8.726
12-2018		0.000		132.557		0.000		54.296		0.00		4.410		484.149		72.480		0.000		411.669		703.503		230.288
12-2019		0.000		110.584		0.000		45.134		0.00		4.680		421.691		68.880		0.000		352.811		1056.314		402.910
12-2020		0.000		94.883		0.000		38.627		0.00		4.950		377.543		66.577		0.000		310.966		1367.280		541.227
12-2021		0.000		83.090		0.000		33.760		0.00		5.220		343.922		65.027		0.000		278.895		1646.175		654.001
12-2022		0.000		73.902		0.000		29.981		0.00		5.490		317.885		64.023		0.000		253.862		1900.037		747.321
12-2023		0.000		66.540		0.000		26.962		0.00		5.770		297.285		63.416		0.000		233.869		2133.906		825.476
12-2024		0.000		60.506		0.000		24.492		0.00		6.050		280.517		63.095		0.000		217.422		2351.328		891.529
12-2025		0.000		55.472		0.000		22.435		0.00		6.050		256.960		64.342		0.000		192.618		2543.946		944.727
12-2026		0.000		51.207		0.000		20.696		0.00		6.050		237.035		62.948		0.000		174.087		2718.032		988.437
S TOT		0.000		1559.467		0.000		622.552		0.00		4.453		5602.025		892.793		1991.200		2718.032		2718.032		988.437
AFTER		0.000		738.134		0.000		297.982		0.00		6.050		3412.869		1524.499		24.890		1863.481		4581.514		1211.344
TOTAL		0.000		2297.600		0.000		920.534		0.00		4.970		9014.895		2417.292		2016.090		4581.514		4581.514		1211.344

	OIL		GAS
GROSS WELLS		0.0		5.0
GROSS ULT., MB & MMF		0.000		2297.601
GROSS CUM., MB & MMF		0.000		0.000
GROSS RES., MB & MMF		0.000		2297.601
NET RES., MB & MMF		0.000		920.533
NET REVENUE, M$		0.000		4574.829
INITIAL PRICE, $		0.000		3.490
INITIAL N.I., PCT.		0.000		34.375

		P.W. %		P.W., M$
LIFE, YRS.	43.42		5.00		2241.331
DISCOUNT %	10.00		10.00		1211.344
UNDISCOUNTED PAYOUT, YRS.	5.42		15.00		672.404
DISCOUNTED PAYOUT, YRS.	5.97		20.00		359.263
UNDISCOUNTED NET/INVEST.	3.27		25.00		165.282
DISCOUNTED NET/INVEST.	1.77		30.00		40.212
RATE-OF-RETURN, PCT.	32.43		40.00		-97.761
INITIAL W.I., PCT.	49.913		60.00		-185.990
			80.00		-193.932
			100.00		-181.184