Exhibit 99.4

FieldPoint Petroleum Corporation

Estimates of

Proved Reserves and Revenues

As of January 1, 2012

SEC Price Guideline Case

Table of Contents

	September 30,
Discussion
Reserve Definitions
Summaries by Reserve Category
Total Proved
Proved Producing
Proved Behind Pipe
Proved Undeveloped
One-Line Summaries
Sort by Reserve Category
Sort by Field
Value Sort – by PW10%
Proved Developed Producing
Proved Behind Pipe
Proved Undeveloped

March 2, 2012

Mr. Ray Reaves

FieldPoint Petroleum Corporation

1703 Edelweiss Drive

Cedar Park, Texas 76613

Ref: FieldPoint Petroleum Corporation

Estimates of Proved Reserves and Revenues

As of January 1, 2012

SEC Guideline Case

Dear Mr. Reaves:

In accordance with your request, we have estimated total proved reserves as of January 1, 2012 to FieldPoint Petroleum Corporation’s interests in selected oil and gas properties located in Louisiana, New Mexico, Oklahoma, Texas and Wyoming.

As presented in this report, we estimate the net reserves and future net revenue to FieldPoint Petroleum Corporation’s interests as follows:

FieldPoint Petroleum Corporation

Total Proved Reserves

As of January 1, 2012

		September 30,		September 30,		September 30,		September 30,
	Proved
	Developed		Proved		Proved
SEC Price Guideline Case	Producing		Behind Pipe		Undeveloped		Total Proved
Estimated Future Net Liquids, MBbl		777.56		22.34		206.17		1,006.07
Estimated Future Net Gas, MMcf		1,087.42		146.81		336.08		1,570.31
Total Future Gross Revenue, M$		76,406.48		2,766.06		20,353.11		99,525.66
Direct Operating Costs, Transportation, and Taxes, M$		31,967.67		554.70		4,761.00		37,283.37
Capital Expenditures, M$		0.00		62.04		4,861.55		4,923.59
Estimated Future Net Revenue (“FNR”), M$		44,438.81		2,149.32		10,730.57		57,318.70
Discounted FNR at 10%, M$		24,902.78		1,301.01		5,123.26		31,327.05
Discounted FNR at 15%, M$		20,769.62		1,077.46		3,665.68		25,512.76

This report has been prepared in accordance with the Society of Petroleum Engineers (“SPE”)—Petroleum Resources Management System (“SPE-PRMS”). Risk factors have not been applied to these estimates. A copy of the SPE-PRMS oil and gas reserve definitions for “Proved” reserves (Table 3 to the SPE-PRMS) are attached hereto. This report also conforms to our understanding of the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserve Information promulgated by SPE and the Guidelines for Application of Definitions for Oil and Gas Reserves prepared by the Society of Petroleum Evaluation Engineers (“SPEE”).

The oil reserves shown are expressed in barrels where one barrel equals 42 US gallons. Gas volumes are expressed in millions of standard cubic feet (MMCF). The reserve and income quantities attributable to the different reserve classifications that are included herein have not been adjusted to reflect the varying degrees of risk associated with them and thus are not comparable.

Future reserves in this report are based on conventional decline curve analysis. The reserves are expressed as property gross and net reserves. Values for reserves are expressed in terms of future net revenue and present worth of future net revenue. Future net revenue is defined as revenue that will accrue to the appraised interests from the production and sale of the estimated net reserves after deducting production taxes, ad valorem taxes, direct lease operating expenses and capital costs. Neither plug and abandonment costs nor salvage was considered in this evaluation. No estimate of Federal Income Tax has been made in this report. Present worth is defined as the future net revenue discounted at the rate shown per year, compounded monthly. The present worth used in this case is 10% per year, compounded monthly.

Prices utilized herein are the average prices of the 12-month prior to the ending date of the period covered by this report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period. An average oil price of $96.19 per barrel based on the WTI Cushing, Oklahoma SPOT price and an average gas price of $4.12 per Mcf based on the Henry Hub Gas Cash Market Price were used. No price escalations are included in this report as per SEC regulations. Where applicable, transportation costs have been included and adjustments for heating content, premiums and basis differentials have been applied.

Lease operating expenses are used to establish the economic limit of each property in this report and were not escalated. FieldPoint Petroleum Corporation provided these expenses for the Bass Petroleum, Inc. (part of FieldPoint Petroleum Corporation) operated wells and the non-operated wells. FieldPoint removed COPAS operating charges, capital expenditures and ad valorem taxes from the monthly operating expenses. Severance and ad valorem taxes were also applied as a percentage of gross revenue. A property is considered uneconomic when expenses exceed gross revenues.

Information necessary for the preparation of these estimates was obtained from records furnished by FieldPoint Petroleum Corporation and from commercially available data sources. For purposes of this report, the individual well test and production data, as reported by the above sources, were accepted as represented together with all other factual data presented by FieldPoint Petroleum Corporation including the extent and character of the interest evaluated. No field inspection of the properties was performed.

All reserve estimates herein have been performed in accordance with sound engineering principles and generally accepted industry practice. As in all aspects of oil and gas evaluations, there are uncertainties inherent in the interpretation of engineering and geologic data and all conclusions and projections contained herein represent the informed, professional judgment of the undersigned. The reserves may or may not be recovered, and the revenues therefrom and the cost related thereto could be more or less than the estimated amounts. Estimates of reserves may increase or decrease as a result of future operations, governmental policies, product supply and demand, and also are subject to revision as additional operating history becomes available and as economic conditions change.

FIELDPOINT PETROLEUM CORPORATION March 2, 2012

The evaluation of potential environmental liability costs from the operation and abandonment of the properties evaluated was beyond the scope of this report. In addition, no evaluation was made to determine the degree of operator compliance with current environmental rules, regulations and reporting requirements. Therefore, no estimate of the potential economic liability, if any, from environmental concerns is included in the projections presented herein.

FieldPoint Petroleum Corporation provided basic well information, operating costs, initial test rates and ownership interests which we have accepted as correct. Historical production data was obtained from public sources such as state regulatory agencies, Lasser Production Data Services, Drillinginfo and IHS Energy Data Services. Digital, hard copy and other pertinent data relating to the properties evaluated will be retained in our files and will be available for review upon request. We have not inspected or performed well tests on the individual properties in this report.

We do not own an interest in the subject properties. The employment to make this study and the compensation is not contingent on our estimates of reserves and future income for the subject properties.

We appreciate the opportunity to prepare this report. If you have any questions regarding this report or if we can assist in any other way please do not hesitate to call. Thank you again for the opportunity to be of service in this matter.

Sincerely,

Wayman T. Gore, Jr., P.E.

President

PGH Petroleum & Environmental Engineers, L.L.C.

David N. Dennard, P.E.

Staff Engineer

PGH Petroleum & Environmental Engineers, L.L.C.

FIELDPOINT PETROLEUM CORPORATION March 2, 2012

Table 3: Reserves Category Definitions and Guidelines

Category	Definition	Guidelines
Proved Reserves	Proved Reserves are those quantities of petroleum, which by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be commercially recoverable, from a given date forward, from known reservoirs and under defined economic conditions, operating methods, and government regulations.	If deterministic methods are used, the term reasonable certainty is intended to express a high degree of confidence that the quantities will be recovered. If probabilistic methods are used, there should be at least a 90% probability that the quantities actually recovered will equal or exceed the estimate. The area of the reservoir considered as Proved includes (1) the area delineated by drilling and defined by fluid contacts, if any, and (2) adjacent undrilled portions of the reservoir that can reasonably be judged as continuous with it and commercially productive on the basis of available geoscience and engineering data. In the absence of data on fluid contacts, Proved quantities in a reservoir are limited by the lowest known hydrocarbon (LKH) as seen in a well penetration unless otherwise indicated by definitive geoscience, engineering, or performance data. Such definitive information may include pressure gradient analysis and seismic indicators. Seismic data alone may not be sufficient to define fluid contacts for Proved reserves (see “2001 Supplemental Guidelines, ” Chapter 8). Reserves in undeveloped locations may be classified as Proved provided that: •      The locations are in undrilled areas of the reservoir that can be judged with reasonable certainty to be commercially productive. •      Interpretations of available geoscience and engineering data indicate with reasonable certainty that the objective formation is laterally continuous with drilled Proved locations. For Proved Reserves, the recovery efficiency applied to these reservoirs should be defined based on a range of possibilities supported by analogs and sound engineering judgment considering the characteristics of the Proved area and the applied development program.
Probable Reserves	Probable Reserves are those additional Reserves which analysis of geoscience and engineering data indicate are less likely to be recovered than Proved Reserves but more certain to be recovered than Possible Reserves.	It is equally likely that actual remaining quantities recovered will be greater than or less than the sum of the estimated Proved plus Probable Reserves (2P). In this context, when probabilistic methods are used, there should be at least a 50% probability that the actual quantities recovered will equal or exceed the 2P estimate. Probable Reserves may be assigned to areas of a reservoir adjacent to Proved where data control or interpretations of available data are less certain. The interpreted reservoir continuity may not meet the reasonable certainty criteria. Probable estimates also include incremental recoveries associated with project recovery efficiencies beyond that assumed for Proved.

	September 30,	September 30,
Category	Definition	Guidelines
Possible Reserves	Possible Reserves are those additional reserves which analysis of geoscience and engineering data indicate are less likely to be recoverable than Probable Reserves.	The total quantities ultimately recovered from the project have a low probability to exceed the sum of Proved plus Probable plus Possible (3P), which is equivalent to the high estimate scenario. When probabilistic methods are used, there should be at least a 10% probability that the actual quantities recovered will equal or exceed the 3P estimate. Possible Reserves may be assigned to areas of a reservoir adjacent to Probable where data control and interpretations of available data are progressively less certain. Frequently, this may be in areas where geoscience and engineering data are unable to clearly define the area and vertical reservoir limits of commercial production from the reservoir by a defined project. Possible estimates also include incremental quantities associated with project recovery efficiencies beyond that assumed for Probable.
Probable and Possible Reserves	(See above for separate criteria for Probable Reserves and Possible Reserves.)	The 2P and 3P estimates may be based on reasonable alternative technical and commercial interpretations within the reservoir and/or subject project that are clearly documented, including comparisons to results in successful similar projects. In conventional accumulations, Probable and/or Possible Reserves may be assigned where geoscience and engineering data identify directly adjacent portions of a reservoir within the same accumulation that may be separated from Proved areas by minor faulting or other geological discontinuities and have not been penetrated by a wellbore but are interpreted to be in communication with the known (Proved) reservoir. Probable or Possible Reserves may be assigned to areas that are structurally higher than the Proved area. Possible (and in some cases, Probable) Reserves may be assigned to areas that are structurally lower than the adjacent Proved or 2P area. Caution should be exercised in assigning Reserves to adjacent reservoirs isolated by major, potentially sealing, faults until this reservoir is penetrated and evaluated as commercially productive. Justification for assigning Reserves in such cases should be clearly documented. Reserves should not be assigned to areas that are clearly separated from a known accumulation by non-productive reservoir (i.e., absence of reservoir, structurally low reservoir, or negative test results); such areas may contain Prospective Resources. In conventional accumulations, where drilling has defined a highest known oil (HKO) elevation and there exists the potential for an associated gas cap, Proved oil Reserves should only be assigned in the structurally higher portions of the reservoir if there is reasonable certainty that such portions are initially above bubble point pressure based on documented engineering analyses. Reservoir portions that do not meet this certainty may be assigned as Probable and Possible oil and/or gas based on reservoir fluid properties and pressure gradient interpretations.

Summaries by Reserve Category

Date : 03/02/2012	9:44:28AM	ECONOMIC SUMMARY PROJECTION
			Proved Rsv Class
Project Name :	FieldPoint Petroleum Corporation	As Of Date : 01/01/2012
Partner :	All Cases	Discount Rate (%) : 10.00
Case Type :	REPORT BREAK TOTAL CASE	All Cases

Cum Oil (Mbbl) :	76,133.90
Cum Gas (MMcf) :	27,280.63
Cum NGL (Mgal) :	17.12

	Gross Oil		Gross Gas		Gross NGL		Net Oil		Net Gas		Net NGL		Oil Price		Gas Price		NGL Price		Total Revenue
Year	(Mbbl)		(MMcf)		(Mgal)		(Mbbl)		(MMcf)		(Mgal)		($/bbl)		($/Mcf)		($/gal)		(M$)
2012		344.29		1,168.12		196.09		114.01		197.51		84.81		91.04		4.21		0.92		11,289.45
2013		323.98		823.12		184.85		89.90		145.66		79.95		90.95		4.72		0.92		8,937.27
2014		327.84		741.04		174.75		87.79		138.69		75.58		91.11		4.67		0.92		8,715.27
2015		267.37		591.98		165.20		72.70		112.96		71.45		91.05		4.63		0.92		7,207.60
2016		232.78		507.13		156.58		63.36		96.87		67.72		91.00		4.59		0.92		6,272.18
2017		202.76		433.35		147.61		55.90		84.01		63.84		90.95		4.59		0.92		5,527.94
2018		179.05		380.09		139.54		48.84		74.38		60.35		90.89		4.59		0.92		4,835.88
2019		161.29		337.95		131.91		44.40		66.81		57.05		90.85		4.59		0.92		4,392.57
2020		147.03		305.22		125.03		40.70		60.72		54.08		90.82		4.59		0.92		4,024.92
2021		133.82		275.45		117.87		37.15		54.86		50.98		90.80		4.58		0.92		3,670.80
2022		107.10		247.96		111.42		31.60		49.23		48.19		90.54		4.56		0.92		3,129.35
2023		96.57		224.45		105.33		28.92		44.92		45.56		90.47		4.56		0.92		2,862.83
2024		89.03		191.26		99.84		26.81		40.15		43.18		90.44		4.60		0.92		2,648.63
2025		81.46		168.08		94.12		24.46		36.35		40.71		90.41		4.62		0.92		2,416.95
2026		75.28		154.10		88.97		22.74		33.46		38.48		90.39		4.61		0.92		2,245.45
Rem		654.77		1,487.97		1,313.35		216.78		333.74		568.02		90.08		3.89		0.92		21,348.57
Total		3,424.42		8,037.26		3,352.46		1,006.07		1,570.31		1,449.94		90.71		4.42		0.92		99,525.66
Ult		79,558.32		35,317.89		3,369.58

	Well		Net Tax Production		Net Tax AdValorem		Net Investment		Net Lease Costs		Net Well Costs		Other Costs		Net Profits		Annual Cash Flow		Cum Disc. Cash Flow
Year	Count		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)
2012		48.00		767.58		429.91		2,538.75		1,393.33		0.00		0.00		0.00		6,159.89		5,851.82
2013		50.00		600.90		301.41		2,234.84		1,375.37		0.00		0.00		0.00		4,424.74		9,689.28
2014		50.00		584.37		263.10		0.00		1,418.66		0.00		0.00		0.00		6,449.14		14,729.19
2015		51.00		478.80		211.55		150.00		1,392.93		0.00		0.00		0.00		4,974.32		18,245.85
2016		50.00		413.28		180.62		0.00		1,370.93		0.00		0.00		0.00		4,307.35		21,001.91
2017		49.00		362.94		157.18		0.00		1,360.92		0.00		0.00		0.00		3,646.89		23,113.61
2018		48.00		319.14		136.64		0.00		1,224.09		0.00		0.00		0.00		3,156.01		24,767.74
2019		45.00		289.19		123.14		0.00		1,219.34		0.00		0.00		0.00		2,760.90		26,077.62
2020		45.00		264.44		111.98		0.00		1,214.43		0.00		0.00		0.00		2,434.07		27,122.93
2021		42.00		240.94		101.40		0.00		1,196.51		0.00		0.00		0.00		2,131.95		27,951.60
2022		39.00		203.99		86.42		0.00		954.26		0.00		0.00		0.00		1,884.68		28,614.72
2023		36.00		186.12		78.53		0.00		920.73		0.00		0.00		0.00		1,677.45		29,149.00
2024		34.00		171.79		72.14		0.00		905.13		0.00		0.00		0.00		1,499.56		29,581.35
2025		31.00		157.11		65.45		0.00		863.81		0.00		0.00		0.00		1,330.58		29,928.55
2026		29.00		145.89		60.41		0.00		852.96		0.00		0.00		0.00		1,186.19		30,208.76
Rem.				1,394.62		552.31		0.00		10,106.65		0.00		0.00		0.00		9,294.99		1,118.29
Total				6,581.12		2,932.18		4,923.59		27,770.07		0.00		0.00		0.00		57,318.70		31,327.05

	September 30,		September 30,	September 30,		September 30,
		Present Worth Profile (M$)
			PW	5.00	% :	40,507.86
Disc. Initial Invest. (M$) :	2,412.632		PW	9.00	% :	32,816.73
ROInvestment (disc/undisc) :	13.98 /23.83		PW	10.00	% :	31,327.05
Years to Payout :	0.26		PW	12.00	% :	28,715.23
Internal ROR (%) :	>1000		PW	15.00	% :	25,512.76
			PW	20.00	% :	21,491.14

TRC Eco DetailedNGL.rpt Page : 1

Date : 03/02/2012	9:44:28AM	ECONOMIC SUMMARY PROJECTION
			Proved Rsv Class
Project Name :	FieldPoint Petroleum Corporation	As Of Date : 01/01/2012	Producing Rsv Category
Partner :	All Cases	Discount Rate (%) : 10.00
Case Type :	REPORT BREAK TOTAL CASE	All Cases

Cum Oil (Mbbl) :	76,133.90
Cum Gas (MMcf) :	27,280.63
Cum NGL (Mgal) :	17.12

	Gross		Gross		Gross		Net		Net		Net		Oil		Gas		NGL		Total
	Oil		Gas		NGL		Oil		Gas		NGL		Price		Price		Price		Revenue
Year	(Mbbl)		(MMcf)		(Mgal)		(Mbbl)		(MMcf)		(Mgal)		($/bbl)		($/Mcf)		($/gal)		(M$)
2012		301.40		525.71		196.09		98.58		128.91		84.81		91.01		4.45		0.92		9,622.29
2013		207.48		351.24		184.85		66.16		87.02		79.95		90.93		4.52		0.92		6,481.93
2014		175.02		303.92		174.75		55.54		73.61		75.58		90.89		4.53		0.92		5,450.81
2015		154.80		272.80		165.20		48.97		65.62		71.45		90.85		4.54		0.92		4,812.68
2016		140.32		247.97		156.58		44.42		59.20		67.72		90.83		4.52		0.92		4,364.14
2017		128.07		226.88		147.61		40.67		54.16		63.84		90.80		4.52		0.92		3,995.79
2018		116.32		208.81		139.54		36.17		49.83		60.35		90.74		4.52		0.92		3,562.27
2019		107.32		192.18		131.91		33.62		46.15		57.05		90.72		4.52		0.92		3,311.08
2020		99.74		178.64		125.03		31.40		43.02		54.08		90.70		4.52		0.92		3,091.58
2021		92.12		164.88		117.87		29.07		39.62		50.98		90.69		4.51		0.92		2,861.19
2022		69.97		150.59		111.42		24.51		35.99		48.19		90.36		4.47		0.92		2,419.87
2023		63.37		138.41		105.33		22.67		33.36		45.56		90.30		4.46		0.92		2,237.83
2024		59.15		127.30		99.84		21.26		30.92		43.18		90.28		4.49		0.92		2,097.40
2025		54.63		118.18		94.12		19.54		28.76		40.71		90.25		4.49		0.92		1,930.40
2026		51.06		108.89		88.97		18.35		26.72		38.48		90.24		4.49		0.92		1,811.42
Rem		443.78		1,077.43		1,313.35		186.63		284.52		568.02		89.92		3.70		0.92		18,355.81
Total		2,264.56		4,393.82		3,352.46		777.56		1,087.42		1,449.94		90.55		4.29		0.92		76,406.48
Ult		78,398.46		31,674.45		3,369.58

			Net Tax		Net Tax		Net		Net		Net		Other		Net		Annual		Cum Disc.
	Well		Production		AdValorem		Investment		Lease Costs		Well Costs		Costs		Profits		Cash Flow		Cash Flow
Year	Count		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)
2012		46.00		646.53		350.27		0.00		1,377.84		0.00		0.00		0.00		7,247.66		6,940.18
2013		43.00		425.22		204.15		0.00		1,312.58		0.00		0.00		0.00		4,539.98		10,859.57
2014		41.00		354.12		161.32		0.00		1,308.09		0.00		0.00		0.00		3,627.28		13,692.09
2015		41.00		310.83		137.74		0.00		1,280.44		0.00		0.00		0.00		3,083.68		15,871.32
2016		40.00		280.80		122.30		0.00		1,254.66		0.00		0.00		0.00		2,706.38		17,602.30
2017		39.00		256.76		110.36		0.00		1,244.65		0.00		0.00		0.00		2,384.01		18,982.31
2018		38.00		231.12		97.69		0.00		1,107.82		0.00		0.00		0.00		2,125.64		20,096.13
2019		35.00		214.66		90.07		0.00		1,103.07		0.00		0.00		0.00		1,903.28		20,998.95
2020		35.00		200.31		83.50		0.00		1,098.16		0.00		0.00		0.00		1,709.60		21,733.03
2021		32.00		185.48		76.80		0.00		1,080.24		0.00		0.00		0.00		1,518.67		22,323.24
2022		29.00		155.53		64.97		0.00		837.99		0.00		0.00		0.00		1,361.37		22,802.16
2023		26.00		143.55		59.75		0.00		804.46		0.00		0.00		0.00		1,230.06		23,193.89
2024		24.00		134.40		55.68		0.00		791.93		0.00		0.00		0.00		1,115.38		23,515.43
2025		22.00		124.23		51.01		0.00		752.54		0.00		0.00		0.00		1,002.62		23,777.03
2026		20.00		116.63		47.62		0.00		741.69		0.00		0.00		0.00		905.47		23,990.90
Rem.				1,201.39		470.20		0.00		8,706.51		0.00		0.00		0.00		7,977.71		911.89
Total				4,981.57		2,183.41		0.00		24,802.69		0.00		0.00		0.00		44,438.81		24,902.78

	September 30,		September 30,	September 30,		September 30,
		Present Worth Profile (M$)
			PW	5.00	% :	31,588.92
Disc. Initial Invest. (M$) :	0.000		PW	9.00	% :	25,973.13
ROInvestment (disc/undisc) :	0.00 /0.00		PW	10.00	% :	24,902.78
Years to Payout :	0.00		PW	12.00	% :	23,038.08
Internal ROR (%) :	0.00		PW	15.00	% :	20,769.62
			PW	20.00	% :	17,940.91

TRC Eco DetailedNGL.rpt Page : 2

Date : 03/02/2012	10:11:36AM	ECONOMIC SUMMARY PROJECTION
			Proved Rsv Class
Project Name :	FieldPoint Petroleum Corporation	As Of Date : 01/01/2012	Behind Pipe Rsv Category
Partner :	All Cases	Discount Rate (%) : 10.00
Case Type :	REPORT BREAK TOTAL CASE	All Cases

Cum Oil (Mbbl) :	0.00
Cum Gas (MMcf) :	0.00
Cum NGL (Mgal) :	0.00

	Gross		Gross		Gross		Net		Net		Net		Oil		Gas		NGL		Total
	Oil		Gas		NGL		Oil		Gas		NGL		Price		Price		Price		Revenue
Year	(Mbbl)		(MMcf)		(Mgal)		(Mbbl)		(MMcf)		(Mgal)		($/bbl)		($/Mcf)		($/gal)		(M$)
2012		0.00		568.77		0.00		0.00		42.09		0.00		0.00		3.53		0.00		148.69
2013		37.87		342.69		0.00		4.17		27.19		0.00		90.83		5.03		0.00		515.12
2014		27.30		218.75		0.00		3.00		17.51		0.00		90.83		5.21		0.00		363.94
2015		19.19		152.04		0.00		2.11		12.18		0.00		90.83		5.23		0.00		255.36
2016		14.90		113.82		0.00		1.64		9.14		0.00		90.83		5.28		0.00		197.19
2017		12.16		88.90		0.00		1.34		7.17		0.00		90.83		5.35		0.00		159.83
2018		10.30		72.09		0.00		1.13		5.83		0.00		90.83		5.43		0.00		134.62
2019		8.95		60.00		0.00		0.98		4.87		0.00		90.83		5.51		0.00		116.26
2020		7.94		51.08		0.00		0.87		4.16		0.00		90.83		5.58		0.00		102.57
2021		7.10		43.77		0.00		0.78		3.58		0.00		90.83		5.66		0.00		91.19
2022		6.39		37.68		0.00		0.70		3.10		0.00		90.83		5.75		0.00		81.63
2023		5.75		32.46		0.00		0.63		2.68		0.00		90.83		5.84		0.00		73.09
2024		5.19		15.56		0.00		0.57		1.40		0.00		90.83		7.51		0.00		62.37
2025		4.66		6.25		0.00		0.51		0.69		0.00		90.83		10.81		0.00		53.96
2026		4.19		5.62		0.00		0.46		0.62		0.00		90.83		10.81		0.00		48.56
Rem		31.22		41.89		0.00		3.43		4.61		0.00		90.83		10.81		0.00		361.71
Total		203.11		1,851.38		0.00		22.34		146.81		0.00		90.83		5.02		0.00		2,766.06
Ult		203.11		1,851.38		0.00

			Net Tax		Net Tax		Net		Net		Net		Other		Net		Annual		Cum Disc.
	Well		Production		AdValorem		Investment		Lease Costs		Well Costs		Costs		Profits		Cash Flow		Cash Flow
Year	Coun		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)
2012		1.00		12.18		3.72		45.00		4.99		0.00		0.00		0.00		82.80		77.45
2013		2.00		38.03		12.88		17.04		11.00		0.00		0.00		0.00		436.18		451.59
2014		2.00		26.81		9.10		0.00		12.20		0.00		0.00		0.00		315.83		698.75
2015		2.00		18.81		6.38		0.00		12.20		0.00		0.00		0.00		217.97		853.02
2016		2.00		14.51		4.93		0.00		12.20		0.00		0.00		0.00		165.55		959.01
2017		2.00		11.75		4.00		0.00		12.20		0.00		0.00		0.00		131.88		1,035.40
2018		2.00		9.89		3.37		0.00		12.20		0.00		0.00		0.00		109.16		1,092.64
2019		2.00		8.54		2.91		0.00		12.20		0.00		0.00		0.00		92.62		1,136.59
2020		2.00		7.53		2.56		0.00		12.20		0.00		0.00		0.00		80.27		1,171.07
2021		2.00		6.69		2.28		0.00		12.20		0.00		0.00		0.00		70.02		1,198.29
2022		2.00		5.98		2.04		0.00		12.20		0.00		0.00		0.00		61.40		1,219.90
2023		2.00		5.35		1.83		0.00		12.20		0.00		0.00		0.00		53.71		1,237.01
2024		2.00		4.54		1.56		0.00		9.12		0.00		0.00		0.00		47.15		1,250.60
2025		1.00		3.91		1.35		0.00		7.20		0.00		0.00		0.00		41.50		1,261.43
2026		1.00		3.52		1.21		0.00		7.20		0.00		0.00		0.00		36.63		1,270.09
Rem.				26.19		9.04		0.00		119.83		0.00		0.00		0.00		206.65		30.92
Total				204.22		69.15		62.04		281.33		0.00		0.00		0.00		2,149.32		1,301.01

	September 30,		September 30,	September 30,		September 30,
		Present Worth Profile (M$)
			PW	5.00	% :	1,627.69
Disc. Initial Invest. (M$) :	15.176		PW	9.00	% :	1,356.14
ROInvestment (disc/undisc) :	86.73 /127.13		PW	10.00	% :	1,301.01
Years to Payout :	0.39		PW	12.00	% :	1,202.28
Internal ROR (%) :	417.77		PW	15.00	% :	1,077.46
			PW	20.00	% :	914.20

TRC Eco DetailedNGL.rpt Page : 75

Date : 03/02/2012	10:11:36AM	ECONOMIC SUMMARY PROJECTION
			Proved Rsv Class
Project Name :	FieldPoint Petroleum Corporation	As Of Date : 01/01/2012	Undeveloped Rsv Category
Partner :	All Cases	Discount Rate (%) : 10.00
Case Type :	REPORT BREAK TOTAL CASE	All Cases

Cum Oil (Mbbl) :	0.00
Cum Gas (MMcf) :	0.00
Cum NGL (Mgal) :	0.00

	Gross		Gross		Gross		Net		Net		Net		Oil		Gas		NGL		Total
	Oil		Gas		NGL		Oil		Gas		NGL		Price		Price		Price		Revenue
Year	(Mbbl)		(MMcf)		(Mgal)		(Mbbl)		(MMcf)		(Mgal)		($/bbl)		($/Mcf)		($/gal)		(M$)
2012		42.88		73.65		0.00		15.44		26.51		0.00		91.21		4.17		0.00		1,518.48
2013		78.63		129.19		0.00		19.58		31.45		0.00		91.05		5.01		0.00		1,940.21
2014		125.51		218.37		0.00		29.25		47.57		0.00		91.57		4.68		0.00		2,900.52
2015		93.38		167.15		0.00		21.61		35.16		0.00		91.52		4.60		0.00		2,139.56
2016		77.56		145.34		0.00		17.30		28.53		0.00		91.46		4.51		0.00		1,710.86
2017		62.53		117.56		0.00		13.89		22.68		0.00		91.41		4.51		0.00		1,372.32
2018		52.43		99.18		0.00		11.54		18.71		0.00		91.35		4.51		0.00		1,139.00
2019		45.02		85.77		0.00		9.79		15.79		0.00		91.30		4.51		0.00		965.23
2020		39.35		75.49		0.00		8.43		13.53		0.00		91.26		4.51		0.00		830.78
2021		34.60		66.80		0.00		7.30		11.65		0.00		91.21		4.52		0.00		718.42
2022		30.74		59.69		0.00		6.38		10.14		0.00		91.17		4.53		0.00		627.85
2023		27.46		53.58		0.00		5.61		8.88		0.00		91.13		4.53		0.00		551.90
2024		24.69		48.41		0.00		4.98		7.83		0.00		91.10		4.53		0.00		488.86
2025		22.17		43.65		0.00		4.41		6.90		0.00		91.07		4.53		0.00		432.60
2026		20.03		39.58		0.00		3.93		6.12		0.00		91.04		4.52		0.00		385.46
Rem		179.78		368.64		0.00		26.71		44.62		0.00		91.15		4.39		0.00		2,631.05
Total		956.76		1,792.05		0.00		206.17		336.08		0.00		91.31		4.55		0.00		20,353.11
Ult		956.76		1,792.05		0.00

			Net Tax		Net Tax		Net		Net		Net		Other		Net		Annual		Cum Disc.
	Well		Production		AdValorem		Investment		Lease Costs		Well Costs		Costs		Profits		Cash Flow		Cash Flow
Year	Count		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)		(M$)
2012		1.00		108.88		75.92		2,493.75		10.50		0.00		0.00		0.00		-1,170.57		-1,165.82
2013		5.00		137.65		84.38		2,217.80		51.79		0.00		0.00		0.00		-551.42		-1,621.88
2014		7.00		203.45		92.68		0.00		98.37		0.00		0.00		0.00		2,506.02		338.35
2015		8.00		149.17		67.43		150.00		100.29		0.00		0.00		0.00		1,672.68		1,521.52
2016		8.00		117.97		53.40		0.00		104.07		0.00		0.00		0.00		1,435.42		2,440.61
2017		8.00		94.42		42.83		0.00		104.07		0.00		0.00		0.00		1,131.00		3,095.89
2018		8.00		78.14		35.58		0.00		104.07		0.00		0.00		0.00		921.21		3,578.97
2019		8.00		65.99		30.17		0.00		104.07		0.00		0.00		0.00		765.00		3,942.08
2020		8.00		56.60		25.91		0.00		104.07		0.00		0.00		0.00		644.19		4,218.84
2021		8.00		48.77		22.32		0.00		104.07		0.00		0.00		0.00		543.26		4,430.07
2022		8.00		42.48		19.40		0.00		104.07		0.00		0.00		0.00		461.90		4,592.66
2023		8.00		37.21		16.95		0.00		104.07		0.00		0.00		0.00		393.67		4,718.10
2024		8.00		32.85		14.91		0.00		104.07		0.00		0.00		0.00		337.04		4,815.31
2025		8.00		28.97		13.09		0.00		104.07		0.00		0.00		0.00		286.46		4,890.09
2026		8.00		25.74		11.57		0.00		104.07		0.00		0.00		0.00		244.08		4,947.78
Rem.				167.04		73.07		0.00		1,280.31		0.00		0.00		0.00		1,110.63		175.48
Total				1,395.33		679.62		4,861.55		2,686.05		0.00		0.00		0.00		10,730.57		5,123.25

	September 30,		September 30,	September 30,		September 30,
		Present Worth Profile (M$)
			PW	5.00	% :	7,291.25
Disc. Initial Invest. (M$) :	2,397.457		PW	9.00	% :	5,487.46
ROInvestment (disc/undisc) :	3.14 /5.30		PW	10.00	% :	5,123.25
Years to Payout :	2.65		PW	12.00	% :	4,474.87
Internal ROR (%) :	51.22		PW	15.00	% :	3,665.68
			PW	20.00	% :	2,636.03

TRC Eco DetailedNGL.rpt Page : 78

– One-Line Summary –

Sort by

Reserve Category & Lease Name

All Cases	PGH Petroleum & Environmental Engineers, L.L.C.	Date :	3/2/2012
		Time :	9:47:35AM
	Economic Information	File :	oint Reserves 2012-01.Phd

																					Disc FNR,
	Rsv		Gross Rem Resv				Net Rem Resv				Net		Sev + Adv		Oper		Capital		FNR		BTax
Lease Name	Cat		Oil Mbbl		Gas MMcf		Oil Mbbl		Gas MMcf		Rev M$		Tax M$		Exp M$		Costs M$		BTax M$		@ 10%, M$
Proved Rsv Class		Total		3,424.42		8,037.26		1,006.07		1,570.31		99,525.66		9,513.30		27,770.07		4,923.59		57,318.70		31,327.05
Proved Rsv Class
Producing Rsv Category		Total		2,264.56		4,393.82		777.56		1,087.42		76,406.48		7,164.98		24,802.69		0.00		44,438.81		24,902.78
APACHE BROMIDE SAND UNIT		PDP		755.83		354.29		145.951		68.41		13,729.85		1,317.38		6,527.65		0.00		5,884.82		3,342.66
ARROWHEAD #1-49		PDP		21.48		0.00		12.860		0.00		1,175.01		83.43		476.03		0.00		615.56		438.35
BUCHANAN -L- Lease		PDP		37.39		200.05		3.799		20.32		414.38		31.37		179.65		0.00		203.36		112.86
BUCHANAN M 1		PDP		13.70		72.60		1.392		7.38		150.93		11.43		59.57		0.00		79.93		55.44
BUCHANAN P 1		PDP		8.30		24.91		0.844		2.53		86.78		6.40		28.29		0.00		52.09		43.41
CARLESTON 1		PDP		2.17		0.00		1.235		0.00		109.64		7.78		65.77		0.00		36.08		28.13
CARLESTON, HERBERT 3		PDP		2.93		9.52		1.788		5.81		193.49		14.75		92.47		0.00		86.27		66.54
CHMELAR, EUGENE -A- 1 L		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
CLEMMONS SUNBURST FEDERAL 001		PDP		17.75		41.71		5.226		12.28		513.00		49.53		177.70		0.00		285.77		209.06
CRONOS FEE 001		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
East Lusk 1 Fed #1H		PDP		315.59		378.71		113.612		136.33		10,930.04		1,327.69		687.11		0.00		8,915.24		7,039.42
ELKHORN 14		PDP		5.00		0.00		4.374		0.00		386.33		33.07		126.55		0.00		226.71		142.82
ELKHORN A ST 015658A 15		PDP		16.60		0.00		13.696		0.00		1,209.62		103.54		411.30		0.00		694.78		299.61
FIELDS 4-1		PDP		0.00		119.44		0.000		4.48		13.09		1.26		4.21		0.00		7.63		3.65
FISCHER #02		PDP		7.28		13.94		1.074		2.06		107.64		8.00		14.65		0.00		84.99		63.21
HERMES FEE 001		PDP		0.00		75.74		0.000		8.33		28.07		3.00		9.37		0.00		15.71		11.72
HERN 1		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
HOSS 7800 RA SUA;CUSHMAN 001		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
HOSS RA SUH;CUSHMAN 002		PDP		6.47		1,078.67		0.593		98.91		468.43		39.42		134.50		0.00		294.50		167.00
JENNINGS FEDERAL 001		PDP		142.57		47.80		103.365		34.65		9,571.82		919.53		1,863.75		0.00		6,788.55		2,729.46
KASPER 1		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
KINNEY ST #38		PDP		99.15		0.00		86.755		0.00		7,608.18		651.26		1,500.00		0.00		5,456.92		1,821.78
KINNEY ST #38		PDP		9.59		0.00		8.387		0.00		735.53		62.96		160.97		0.00		511.60		291.68
KORCZAK FED. #01		PDP		131.70		176.74		14.487		19.44		1,525.93		148.65		204.14		0.00		1,173.14		707.43
LORENZ 1		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
MARQUIS #7 7		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
MCCLINTIC -A- 1		PDP		105.50		126.60		6.003		7.20		581.27		41.93		184.75		0.00		354.59		130.90
MENZEL 1		PDP		7.87		0.00		4.582		0.00		406.67		28.87		158.74		0.00		219.06		126.37
MERCURY FEE 001		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
MERSIOVSKY 2		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
MERSLOVSKY #01		PDP		1.96		0.00		1.282		0.00		113.81		8.08		66.42		0.00		39.30		25.01

All Estimates Herein are Part of the PGH Petroleum & Environmental Engineers, L.L.C. Report and are Subject to its Conditions.

All Cases	PGH Petroleum & Environmental Engineers, L.L.C.	Date :	3/2/2012
		Time :	9:47:35AM
	Economic Information	File :	oint Reserves 2012-01.Phd

	Rsv		Gross Rem Resv				Net Rem Resv				Net		Sev + Adv		Oper		Capital		FNR		Disc FNR, BTax
Lease Name	Cat		Oil Mbbl		Gas MMcf		Oil Mbbl		Gas MMcf		Rev M$		Tax M$		Exp M$		Costs M$		BTax M$		@ 10%, M$
MILROSE-LORENZ 4		PDP		1.85		5.10		0.348		0.96		36.58		2.76		9.73		0.00		24.09		17.17
MILROSE-MARQUIS A 3		PDP		2.39		7.40		0.373		1.16		40.02		3.04		13.41		0.00		23.57		16.33
MILROSE-MARQUIS B 4		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
MILROSE-VAHRENKAMP 1		PDP		1.11		2.83		0.162		0.41		16.88		1.27		7.62		0.00		7.99		6.21
MOERBE 5		PDP		2.69		0.00		1.147		0.00		101.83		7.23		51.74		0.00		42.86		30.39
MOERBE, VICTOR 3		PDP		0.13		1.19		0.097		0.87		13.86		1.14		11.81		0.00		0.92		0.88
NITSCHE, R.J. 1		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
NORTH AMERICAN WEISE 1		PDP		0.13		0.39		0.074		0.22		7.84		0.60		6.08		0.00		1.17		1.12
NORTH BILBREY 7 FEDERAL 001		PDP		0.00		1,352.89		0.000		490.33		2,681.69		302.74		442.34		0.00		1,936.60		826.22
NORTH BLOCK 12 UNIT		PDP		112.62		0.00		94.216		0.00		8,448.87		599.87		4,058.13		0.00		3,790.87		2,133.27
PETERS #5		PDP		1.45		6.94		0.828		3.97		97.28		7.60		66.36		0.00		23.32		17.50
PETERS ‘C’ 9		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
PETERS 8		PDP		2.04		5.66		1.534		4.24		161.51		12.20		66.07		0.00		83.23		65.69
QUINOCO SULIMAR 001		PDP		60.20		0.00		51.473		0.00		4,591.23		440.30		1,343.76		0.00		2,807.18		1,366.15
RUSH SPRINGS MEDRANO UNIT		PDP		310.20		26.27		50.221		4.25		4,738.36		454.65		2,549.97		0.00		1,733.74		1,306.34
S & M ENERGY-LORENZ 3		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S & M ENERGY-MARQUIS 6		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S & M ENERGY-MOERBE 2		PDP		0.74		3.40		0.409		1.88		47.54		3.70		25.16		0.00		18.67		15.68
S & M ENERGY-PETERS B 7		PDP		6.63		11.11		3.535		5.92		349.19		25.82		172.52		0.00		150.85		88.27
S&M ENERGY-DEAN STUESSY -E- 7		PDP		0.00		7.64		0.000		4.07		24.41		2.44		16.70		0.00		5.26		4.57
S&M ENERGY-DEAN STUESSY A 1		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-DEAN STUESSY B 2		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-DEAN STUESSY C 4		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-DEAN STUESSY D 5		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-HERBERT STUESSY -A- 6		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-HERBERT STUESSY 3		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-PETERS A		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-SPRETZ 1		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-SPRETZ A 2		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
SCOTT PETROLEUM-PETERS A 6		PDP		0.08		0.46		0.058		0.35		7.22		0.57		6.32		0.00		0.33		0.32
SHADE 0		PDP		29.89		164.40		22.972		124.70		3,178.59		259.88		1,627.32		0.00		1,291.39		758.61
SHEARN FEDERAL 003		PDP		4.88		0.00		4.028		0.00		365.51		35.05		172.36		0.00		158.10		143.04
STATE OF TEXAS -Z- 0		PDP		13.82		0.00		12.096		0.00		1,109.09		78.75		830.59		0.00		199.75		166.70
STAUSS 1		PDP		0.00		51.28		0.000		1.77		6.57		0.66		5.45		0.00		0.46		0.46
STEINBACH 2		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
STEINBACH ET AL 1		PDP		2.16		12.35		0.994		5.68		122.30		9.67		55.78		0.00		56.85		39.60

All Estimates Herein are Part of the PGH Petroleum & Environmental Engineers, L.L.C. Report and are Subject to its Conditions.

All Cases	PGH Petroleum & Environmental Engineers, L.L.C.	Date :	3/2/2012
		Time :	9:47:35AM
	Economic Information	File :	oint Reserves 2012-01.Phd

	Rsv	Gross Rem Resv				Net Rem Resv				Net		Sev + Adv		Oper		Capital		FNR		Disc FNR, BTax
Lease Name	Cat	Oil Mbbl		Gas MMcf		Oil Mbbl		Gas MMcf		Rev M$		Tax M$		Exp M$		Costs M$		BTax M$		@ 10%, M$
SUNBURST SPENCE FEDERAL 002	PDP		0.02		0.15		0.006		0.04		0.67		0.06		0.59		0.00		0.01		0.01
URBAN #2 2	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
URBAN #3 3	PDP		2.11		10.31		1.455		7.10		171.66		13.42		112.04		0.00		46.20		34.46
URBAN 1	PDP		0.58		3.36		0.230		1.32		28.28		2.24		17.23		0.00		8.81		7.34
WACHSMANN 1	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
Proved Rsv Class
Behind Pipe Rsv Category	Total		203.11		1,851.38		22.34		146.81		2,766.06		273.37		281.33		62.04		2,149.32		1,301.01
KORCZAK FED. #01	PBP		203.11		272.57		22.342		29.98		2,353.34		229.25		219.42		17.04		1,887.63		1,093.00
MERCURY FEE #01	PBP		0.00		1,578.81		0.000		116.83		412.73		44.12		61.91		45.00		261.70		208.01
Proved Rsv Class
Undeveloped Rsv Category	Total		956.76		1,792.05		206.17		336.08		20,353.11		2,074.95		2,686.05		4,861.55		10,730.57		5,123.25
BUCHANAN -L- PUD #01	PUD		75.05		222.89		7.625		22.65		771.79		56.96		276.93		150.00		287.90		117.79
BUCHANAN -M- PUD #01	PUD		69.01		204.96		7.012		20.82		706.09		52.14		160.85		150.00		343.10		110.58
BUCHANAN -M- PUD #02	PUD		69.01		204.96		7.012		20.82		706.09		52.14		160.86		150.00		343.09		93.72
East Lusk 1 Fed #2H	PUD		192.93		331.33		69.455		119.28		6,831.59		831.41		445.57		2,493.75		3,060.86		1,631.89
FLYING M SOUTH (ABO) PUD #01	PUD		215.94		360.61		63.572		106.16		6,303.81		609.35		432.35		1,099.00		4,163.11		2,131.42
KORCZAK FED. PUD #1	PUD		203.41		272.98		22.375		30.03		2,356.90		229.60		211.30		340.80		1,575.20		782.72
MCCLINTIC -A- PUD #01	PUD		104.30		187.73		5.934		10.68		585.90		42.58		143.01		78.00		322.31		77.47
QUINOCO SULIMAR PUD #01	PUD		27.11		6.59		23.182		5.63		2,090.94		200.78		855.18		400.00		634.99		177.66

All Estimates Herein are Part of the PGH Petroleum & Environmental Engineers, L.L.C. Report and are Subject to its Conditions.

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All Cases	PGH Petroleum & Environmental Engineers, L.L.C.	Date :	3/2/2012
		Time :	9:49:01AM
	Economic Information	File :	oint Reserves 2012-01.Phd

	Rsv		Gross Rem Resv				Net Rem Resv				Net		Sev + Adv		Oper		Capital		FNR		Disc FNR, BTax
Lease Name	Cat		Oil Mbbl		Gas MMcf		Oil Mbbl		Gas MMcf		Rev M$		Tax M$		Exp M$		Costs M$		BTax M$		@ 10%, M$
Grand Total		Total		3,424.42		8,037.26		1,006.07		1,570.31		99,525.66		9,513.30		27,770.07		4,923.59		57,318.70		31,327.05
APACHE Field
APACHE BROMIDE SAND UNIT		PDP		755.83		354.29		145.951		68.41		13,729.85		1,317.38		6,527.65		0.00		5,884.82		3,342.66
BIG MUDDY Field		Total		21.60		0.00		18.07		0.00		1,595.95		136.61		537.85		0.00		921.49		442.42
ELKHORN 14		PDP		5.00		0.00		4.374		0.00		386.33		33.07		126.55		0.00		226.71		142.82
ELKHORN A ST 015658A 15		PDP		16.60		0.00		13.696		0.00		1,209.62		103.54		411.30		0.00		694.78		299.61
BIG MUDDY (DAKOTA) Field
KINNEY ST #38		PDP		99.15		0.00		86.755		0.00		7,608.18		651.26		1,500.00		0.00		5,456.92		1,821.78
BIG MUDDY (WALL CREEK) Field
KINNEY ST #38		PDP		9.59		0.00		8.387		0.00		735.53		62.96		160.97		0.00		511.60		291.68
BILBREY Field
NORTH BILBREY 7 FEDERAL 001		PDP		0.00		1,352.89		0.000		490.33		2,681.69		302.74		442.34		0.00		1,936.60		826.22
BLOCK 6 Field
STATE OF TEXAS -Z- 0		PDP		13.82		0.00		12.096		0.00		1,109.09		78.75		830.59		0.00		199.75		166.70
BLOCK A-49 Field		Total		134.10		0.00		107.08		0.00		9,623.88		683.30		4,534.16		0.00		4,406.43		2,571.61
ARROWHEAD #1-49		PDP		21.48		0.00		12.860		0.00		1,175.01		83.43		476.03		0.00		615.56		438.35
NORTH BLOCK 12 UNIT		PDP		112.62		0.00		94.216		0.00		8,448.87		599.87		4,058.13		0.00		3,790.87		2,133.27
CHICKASHA Field
RUSH SPRINGS MEDRANO UNIT		PDP		310.20		26.27		50.221		4.25		4,738.36		454.65		2,549.97		0.00		1,733.74		1,306.34
FLYING M Field		Total		17.77		41.86		5.23		12.32		513.67		49.60		178.29		0.00		285.78		209.07
CLEMMONS SUNBURST FEDERAL 001		PDP		17.75		41.71		5.226		12.28		513.00		49.53		177.70		0.00		285.77		209.06
SUNBURST SPENCE FEDERAL 002		PDP		0.02		0.15		0.006		0.04		0.67		0.06		0.59		0.00		0.01		0.01
FLYING M SOUTH (ABO) Field
FLYING M SOUTH (ABO) PUD #01		PUD		215.94		360.61		63.572		106.16		6,303.81		609.35		432.35		1,099.00		4,163.11		2,131.42
GIDDINGS Field		Total		29.89		164.40		22.97		124.70		3,178.59		259.88		1,627.32		0.00		1,291.39		758.61
CHMELAR, EUGENE -A- 1 L		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
SHADE 0		PDP		29.89		164.40		22.972		124.70		3,178.59		259.88		1,627.32		0.00		1,291.39		758.61
LONGWOOD Field		Total		6.47		1,078.67		0.59		98.91		468.43		39.42		134.50		0.00		294.50		167.00
HOSS 7800 RA SUA;CUSHMAN 001		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
HOSS RA SUH;CUSHMAN 002		PDP		6.47		1,078.67		0.593		98.91		468.43		39.42		134.50		0.00		294.50		167.00
LOVING Field		Total		0.00		1,654.55		0.00		125.16		440.80		47.12		71.28		45.00		277.40		219.73

All Estimates Herein are Part of the PGH Petroleum & Environmental Engineers, L.L.C. Report and are Subject to its Conditions.

All Cases	PGH Petroleum & Environmental Engineers, L.L.C.	Date :	3/2/2012
		Time :	9:49:01AM
	Economic Information	File :	oint Reserves 2012-01.Phd

	Rsv	Gross Rem Resv				Net Rem Resv				Net		Sev + Adv		Oper		Capital		FNR		Disc FNR, BTax
Lease Name	Cat	Oil Mbbl		Gas MMcf		Oil Mbbl		Gas MMcf		Rev M$		Tax M$		Exp M$		Costs M$		BTax M$		@ 10%, M$
CRONOS FEE 001	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
HERMES FEE 001	PDP		0.00		75.74		0.000		8.33		28.07		3.00		9.37		0.00		15.71		11.72
MERCURY FEE 001	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
MERCURY FEE #01	PBP		0.00		1,578.81		0.000		116.83		412.73		44.12		61.91		45.00		261.70		208.01
LUSK Field	Total		1,194.19		1,480.12		349.66		369.72		33,935.12		3,721.17		3,803.65		2,851.59		23,558.72		14,126.95
East Lusk 1 Fed #1H	PDP		315.59		378.71		113.612		136.33		10,930.04		1,327.69		687.11		0.00		8,915.24		7,039.42
JENNINGS FEDERAL 001	PDP		142.57		47.80		103.365		34.65		9,571.82		919.53		1,863.75		0.00		6,788.55		2,729.46
KORCZAK FED. #01	PDP		131.70		176.74		14.487		19.44		1,525.93		148.65		204.14		0.00		1,173.14		707.43
SHEARN FEDERAL 003	PDP		4.88		0.00		4.028		0.00		365.51		35.05		172.36		0.00		158.10		143.04
KORCZAK FED. #01	PBP		203.11		272.57		22.342		29.98		2,353.34		229.25		219.42		17.04		1,887.63		1,093.00
East Lusk 1 Fed #2H	PUD		192.93		331.33		69.455		119.28		6,831.59		831.41		445.57		2,493.75		3,060.86		1,631.89
KORCZAK FED. PUD #1	PUD		203.41		272.98		22.375		30.03		2,356.90		229.60		211.30		340.80		1,575.20		782.72
PUTNAM Field
FIELDS 4-1	PDP		0.00		119.44		0.000		4.48		13.09		1.26		4.21		0.00		7.63		3.65
SERBIN Field	Total		37.07		87.65		18.85		43.98		1,936.19		145.11		955.56		0.00		835.52		566.55
CARLESTON 1	PDP		2.17		0.00		1.235		0.00		109.64		7.78		65.77		0.00		36.08		28.13
CARLESTON, HERBERT 3	PDP		2.93		9.52		1.788		5.81		193.49		14.75		92.47		0.00		86.27		66.54
HERN 1	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
KASPER 1	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
LORENZ 1	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
MARQUIS #7 7	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
MENZEL 1	PDP		7.87		0.00		4.582		0.00		406.67		28.87		158.74		0.00		219.06		126.37
MERSIOVSKY 2	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
MILROSE-LORENZ 4	PDP		1.85		5.10		0.348		0.96		36.58		2.76		9.73		0.00		24.09		17.17
MILROSE-MARQUIS A 3	PDP		2.39		7.40		0.373		1.16		40.02		3.04		13.41		0.00		23.57		16.33
MILROSE-MARQUIS B 4	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
MILROSE-VAHRENKAMP 1	PDP		1.11		2.83		0.162		0.41		16.88		1.27		7.62		0.00		7.99		6.21
MOERBE 5	PDP		2.69		0.00		1.147		0.00		101.83		7.23		51.74		0.00		42.86		30.39
MOERBE, VICTOR 3	PDP		0.13		1.19		0.097		0.87		13.86		1.14		11.81		0.00		0.92		0.88
NITSCHE, R.J. 1	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
NORTH AMERICAN WEISE 1	PDP		0.13		0.39		0.074		0.22		7.84		0.60		6.08		0.00		1.17		1.12
PETERS #5	PDP		1.45		6.94		0.828		3.97		97.28		7.60		66.36		0.00		23.32		17.50
PETERS ‘C’ 9	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
PETERS 8	PDP		2.04		5.66		1.534		4.24		161.51		12.20		66.07		0.00		83.23		65.69

All Estimates Herein are Part of the PGH Petroleum & Environmental Engineers, L.L.C. Report and are Subject to its Conditions.

All Cases	PGH Petroleum & Environmental Engineers, L.L.C.	Date :	3/2/2012
		Time :	9:49:01AM
	Economic Information	File :	oint Reserves 2012-01.Phd

	0000		0000		0000		0000		0000		0000		0000		0000		0000		0000		0000
	Rsv	Gross Rem Resv				Net Rem Resv				Net		Sev + Adv		Oper		Capital		FNR		Disc FNR, BTax
Lease Name	Cat	Oil Mbbl		Gas MMcf		Oil Mbbl		Gas MMcf		Rev M$		Tax M$		Exp M$		Costs M$		BTax M$		@ 10%, M$
S & M ENERGY-LORENZ 3	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S & M ENERGY-MARQUIS 6	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S & M ENERGY-MOERBE 2	PDP		0.74		3.40		0.409		1.88		47.54		3.70		25.16		0.00		18.67		15.68
S & M ENERGY-PETERS B 7	PDP		6.63		11.11		3.535		5.92		349.19		25.82		172.52		0.00		150.85		88.27
S&M ENERGY-DEAN STUESSY -E- 7	PDP		0.00		7.64		0.000		4.07		24.41		2.44		16.70		0.00		5.26		4.57
S&M ENERGY-DEAN STUESSY A 1	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-DEAN STUESSY B 2	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-DEAN STUESSY C 4	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-DEAN STUESSY D 5	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-HERBERT STUESSY -A- 6	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-HERBERT STUESSY 3	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-PETERS A	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-SPRETZ 1	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-SPRETZ A 2	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
SCOTT PETROLEUM-PETERS A 6	PDP		0.08		0.46		0.058		0.35		7.22		0.57		6.32		0.00		0.33		0.32
STEINBACH 2	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
STEINBACH ET AL 1	PDP		2.16		12.35		0.994		5.68		122.30		9.67		55.78		0.00		56.85		39.60
URBAN #2 2	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
URBAN #3 3	PDP		2.11		10.31		1.455		7.10		171.66		13.42		112.04		0.00		46.20		34.46
URBAN 1	PDP		0.58		3.36		0.230		1.32		28.28		2.24		17.23		0.00		8.81		7.34
WACHSMANN 1	PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
SERBIN (TAYLOR SAND) Field	Total		9.24		13.94		2.36		2.06		221.44		16.08		81.07		0.00		124.29		88.23
FISCHER #02	PDP		7.28		13.94		1.074		2.06		107.64		8.00		14.65		0.00		84.99		63.21
MERSLOVSKY #01	PDP		1.96		0.00		1.282		0.00		113.81		8.08		66.42		0.00		39.30		25.01
SPRABERRY Field	Total		164.89		424.15		12.04		37.44		1,233.35		91.12		452.26		0.00		689.97		342.60
BUCHANAN -L- Lease	PDP		37.39		200.05		3.799		20.32		414.38		31.37		179.65		0.00		203.36		112.86
BUCHANAN M 1	PDP		13.70		72.60		1.392		7.38		150.93		11.43		59.57		0.00		79.93		55.44
BUCHANAN P 1	PDP		8.30		24.91		0.844		2.53		86.78		6.40		28.29		0.00		52.09		43.41
MCCLINTIC -A- 1	PDP		105.50		126.60		6.003		7.20		581.27		41.93		184.75		0.00		354.59		130.90
SPRABERRY (TREND AREA) Field	Total		317.36		820.54		27.58		74.98		2,769.88		203.82		741.65		528.00		1,296.41		399.56
BUCHANAN -L- PUD #01	PUD		75.05		222.89		7.625		22.65		771.79		56.96		276.93		150.00		287.90		117.79
BUCHANAN -M- PUD #01	PUD		69.01		204.96		7.012		20.82		706.09		52.14		160.85		150.00		343.10		110.58
BUCHANAN -M- PUD #02	PUD		69.01		204.96		7.012		20.82		706.09		52.14		160.86		150.00		343.09		93.72
MCCLINTIC -A- PUD #01	PUD		104.30		187.73		5.934		10.68		585.90		42.58		143.01		78.00		322.31		77.47

All Estimates Herein are Part of the PGH Petroleum & Environmental Engineers, L.L.C. Report and are Subject to its Conditions.

All Cases	PGH Petroleum & Environmental Engineers, L.L.C.	Date :	3/2/2012
		Time :	9:49:01AM
	Economic Information	File :	oint Reserves 2012-01.Phd

	Rsv	Gross Rem Resv				Net Rem Resv				Net		Sev + Adv		Oper		Capital		FNR		Disc FNR, BTax
Lease Name	Cat	Oil Mbbl		Gas MMcf		Oil Mbbl		Gas MMcf		Rev M$		Tax M$		Exp M$		Costs M$		BTax M$		@ 10%, M$
SULIMAR Field
QUINOCO SULIMAR 001	PDP		60.20		0.00		51.473		0.00		4,591.23		440.30		1,343.76		0.00		2,807.18		1,366.15
SULIMAR (QUEEN) Field
QUINOCO SULIMAR PUD #01	PUD		27.11		6.59		23.182		5.63		2,090.94		200.78		855.18		400.00		634.99		177.66
TULETA, W. Field
STAUSS 1	PDP		0.00		51.28		0.000		1.77		6.57		0.66		5.45		0.00		0.46		0.46

All Estimates Herein are Part of the PGH Petroleum & Environmental Engineers, L.L.C. Report and are Subject to its Conditions.

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All Cases	PGH Petroleum & Environmental Engineers, L.L.C.	Date :	3/2/2012
		Time :	9:57:51AM
	Economic Information	File :	oint Reserves 2012-01.Phd

		Septe		Septe		Septe		Septe		Septe		Septe		Septe		Septe		Septe		Septe		Septe
																					Disc FNR,
	Rsv		Gross Rem Resv				Net Rem Resv				Net		Sev + Adv		Oper		Capital		FNR		BTax
Lease Name	Cat		Oil Mbbl		Gas MMcf		Oil Mbbl		Gas MMcf		Rev M$		Tax M$		Exp M$		Costs M$		BTax M$		@ 10%, M$
Proved Rsv Class		Total		3,424.42		8,037.26		1,006.07		1,570.31		99,525.66		9,513.30		27,770.07		4,923.59		57,318.70		31,327.05
East Lusk 1 Fed #1H		PDP		315.59		378.71		113.612		136.33		10,930.04		1,327.69		687.11		0.00		8,915.24		7,039.42
APACHE BROMIDE SAND UNIT		PDP		755.83		354.29		145.951		68.41		13,729.85		1,317.38		6,527.65		0.00		5,884.82		3,342.66
JENNINGS FEDERAL 001		PDP		142.57		47.80		103.365		34.65		9,571.82		919.53		1,863.75		0.00		6,788.55		2,729.46
NORTH BLOCK 12 UNIT		PDP		112.62		0.00		94.216		0.00		8,448.87		599.87		4,058.13		0.00		3,790.87		2,133.27
FLYING M SOUTH (ABO) PUD #01		PUD		215.94		360.61		63.572		106.16		6,303.81		609.35		432.35		1,099.00		4,163.11		2,131.42
KINNEY ST #38		PDP		99.15		0.00		86.755		0.00		7,608.18		651.26		1,500.00		0.00		5,456.92		1,821.78
East Lusk 1 Fed #2H		PUD		192.93		331.33		69.455		119.28		6,831.59		831.41		445.57		2,493.75		3,060.86		1,631.89
QUINOCO SULIMAR 001		PDP		60.20		0.00		51.473		0.00		4,591.23		440.30		1,343.76		0.00		2,807.18		1,366.15
RUSH SPRINGS MEDRANO UNIT		PDP		310.20		26.27		50.221		4.25		4,738.36		454.65		2,549.97		0.00		1,733.74		1,306.34
KORCZAK FED. #01		PBP		203.11		272.57		22.342		29.98		2,353.34		229.25		219.42		17.04		1,887.63		1,093.00
NORTH BILBREY 7 FEDERAL 001		PDP		0.00		1,352.89		0.000		490.33		2,681.69		302.74		442.34		0.00		1,936.60		826.22
KORCZAK FED. PUD #1		PUD		203.41		272.98		22.375		30.03		2,356.90		229.60		211.30		340.80		1,575.20		782.72
SHADE 0		PDP		29.89		164.40		22.972		124.70		3,178.59		259.88		1,627.32		0.00		1,291.39		758.61
KORCZAK FED. #01		PDP		131.70		176.74		14.487		19.44		1,525.93		148.65		204.14		0.00		1,173.14		707.43
ARROWHEAD #1-49		PDP		21.48		0.00		12.860		0.00		1,175.01		83.43		476.03		0.00		615.56		438.35
ELKHORN A ST 015658A 15		PDP		16.60		0.00		13.696		0.00		1,209.62		103.54		411.30		0.00		694.78		299.61
KINNEY ST #38		PDP		9.59		0.00		8.387		0.00		735.53		62.96		160.97		0.00		511.60		291.68
CLEMMONS SUNBURST FEDERAL 001		PDP		17.75		41.71		5.226		12.28		513.00		49.53		177.70		0.00		285.77		209.06
MERCURY FEE #01		PBP		0.00		1,578.81		0.000		116.83		412.73		44.12		61.91		45.00		261.70		208.01
QUINOCO SULIMAR PUD #01		PUD		27.11		6.59		23.182		5.63		2,090.94		200.78		855.18		400.00		634.99		177.66
HOSS RA SUH;CUSHMAN 002		PDP		6.47		1,078.67		0.593		98.91		468.43		39.42		134.50		0.00		294.50		167.00
STATE OF TEXAS -Z- 0		PDP		13.82		0.00		12.096		0.00		1,109.09		78.75		830.59		0.00		199.75		166.70
SHEARN FEDERAL 003		PDP		4.88		0.00		4.028		0.00		365.51		35.05		172.36		0.00		158.10		143.04
ELKHORN 14		PDP		5.00		0.00		4.374		0.00		386.33		33.07		126.55		0.00		226.71		142.82
MCCLINTIC -A- 1		PDP		105.50		126.60		6.003		7.20		581.27		41.93		184.75		0.00		354.59		130.90
MENZEL 1		PDP		7.87		0.00		4.582		0.00		406.67		28.87		158.74		0.00		219.06		126.37
BUCHANAN -L- PUD #01		PUD		75.05		222.89		7.625		22.65		771.79		56.96		276.93		150.00		287.90		117.79
BUCHANAN -L- Lease		PDP		37.39		200.05		3.799		20.32		414.38		31.37		179.65		0.00		203.36		112.86
BUCHANAN -M- PUD #01		PUD		69.01		204.96		7.012		20.82		706.09		52.14		160.85		150.00		343.10		110.58
BUCHANAN -M- PUD #02		PUD		69.01		204.96		7.012		20.82		706.09		52.14		160.86		150.00		343.09		93.72
S & M ENERGY-PETERS B 7		PDP		6.63		11.11		3.535		5.92		349.19		25.82		172.52		0.00		150.85		88.27
MCCLINTIC -A- PUD #01		PUD		104.30		187.73		5.934		10.68		585.90		42.58		143.01		78.00		322.31		77.47
CARLESTON, HERBERT 3		PDP		2.93		9.52		1.788		5.81		193.49		14.75		92.47		0.00		86.27		66.54
PETERS 8		PDP		2.04		5.66		1.534		4.24		161.51		12.20		66.07		0.00		83.23		65.69

All Estimates Herein are Part of the PGH Petroleum & Environmental Engineers, L.L.C. Report and are Subject to its Conditions.

All Cases	PGH Petroleum & Environmental Engineers, L.L.C.	Date :	3/2/2012
		Time :	9:57:51AM
	Economic Information	File :	oint Reserves 2012-01.Phd

		Septe		Septe		Septe		Septe		Septe		Septe		Septe		Septe		Septe		Septe		Septe
																					Disc FNR,
	Rsv		Gross Rem Resv				Net Rem Resv				Net		Sev + Adv		Oper		Capital		FNR		BTax
Lease Name	Cat		Oil Mbbl		Gas MMcf		Oil Mbbl		Gas MMcf		Rev M$		Tax M$		Exp M$		Costs M$		BTax M$		@ 10%, M$
FISCHER #02		PDP		7.28		13.94		1.074		2.06		107.64		8.00		14.65		0.00		84.99		63.21
BUCHANAN M 1		PDP		13.70		72.60		1.392		7.38		150.93		11.43		59.57		0.00		79.93		55.44
BUCHANAN P 1		PDP		8.30		24.91		0.844		2.53		86.78		6.40		28.29		0.00		52.09		43.41
STEINBACH ET AL 1		PDP		2.16		12.35		0.994		5.68		122.30		9.67		55.78		0.00		56.85		39.60
URBAN #3 3		PDP		2.11		10.31		1.455		7.10		171.66		13.42		112.04		0.00		46.20		34.46
MOERBE 5		PDP		2.69		0.00		1.147		0.00		101.83		7.23		51.74		0.00		42.86		30.39
CARLESTON 1		PDP		2.17		0.00		1.235		0.00		109.64		7.78		65.77		0.00		36.08		28.13
MERSLOVSKY #01		PDP		1.96		0.00		1.282		0.00		113.81		8.08		66.42		0.00		39.30		25.01
PETERS #5		PDP		1.45		6.94		0.828		3.97		97.28		7.60		66.36		0.00		23.32		17.50
MILROSE-LORENZ 4		PDP		1.85		5.10		0.348		0.96		36.58		2.76		9.73		0.00		24.09		17.17
MILROSE-MARQUIS A 3		PDP		2.39		7.40		0.373		1.16		40.02		3.04		13.41		0.00		23.57		16.33
S & M ENERGY-MOERBE 2		PDP		0.74		3.40		0.409		1.88		47.54		3.70		25.16		0.00		18.67		15.68
HERMES FEE 001		PDP		0.00		75.74		0.000		8.33		28.07		3.00		9.37		0.00		15.71		11.72
URBAN 1		PDP		0.58		3.36		0.230		1.32		28.28		2.24		17.23		0.00		8.81		7.34
MILROSE-VAHRENKAMP 1		PDP		1.11		2.83		0.162		0.41		16.88		1.27		7.62		0.00		7.99		6.21
S&M ENERGY-DEAN STUESSY -E- 7		PDP		0.00		7.64		0.000		4.07		24.41		2.44		16.70		0.00		5.26		4.57
FIELDS 4-1		PDP		0.00		119.44		0.000		4.48		13.09		1.26		4.21		0.00		7.63		3.65
NORTH AMERICAN WEISE 1		PDP		0.13		0.39		0.074		0.22		7.84		0.60		6.08		0.00		1.17		1.12
MOERBE, VICTOR 3		PDP		0.13		1.19		0.097		0.87		13.86		1.14		11.81		0.00		0.92		0.88
STAUSS 1		PDP		0.00		51.28		0.000		1.77		6.57		0.66		5.45		0.00		0.46		0.46
SCOTT PETROLEUM-PETERS A 6		PDP		0.08		0.46		0.058		0.35		7.22		0.57		6.32		0.00		0.33		0.32
SUNBURST SPENCE FEDERAL 002		PDP		0.02		0.15		0.006		0.04		0.67		0.06		0.59		0.00		0.01		0.01
CHMELAR, EUGENE -A- 1 L		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
CRONOS FEE 001		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
HERN 1		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
HOSS 7800 RA SUA;CUSHMAN 001		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
KASPER 1		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
LORENZ 1		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
MARQUIS #7 7		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
MERCURY FEE 001		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
MERSIOVSKY 2		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
MILROSE-MARQUIS B 4		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
NITSCHE, R.J. 1		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
PETERS ‘C’ 9		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S & M ENERGY-LORENZ 3		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S & M ENERGY-MARQUIS 6		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00

All Estimates Herein are Part of the PGH Petroleum & Environmental Engineers, L.L.C. Report and are Subject to its Conditions.

All Cases	PGH Petroleum & Environmental Engineers, L.L.C.	Date :	3/2/2012
		Time :	9:57:51AM
	Economic Information	File :	oint Reserves 2012-01.Phd

		Septem		Septem		Septem		Septem		Septem		Septem		Septem		Septem		Septem		Septem		Septem
																					Disc FNR,
	Rsv		Gross Rem Resv				Net Rem Resv				Net		Sev + Adv		Oper		Capital		FNR		BTax
Lease Name	Cat		Oil Mbbl		Gas MMcf		Oil Mbbl		Gas MMcf		Rev M$		Tax M$		Exp M$		Costs M$		BTax M$		@ 10%, M$
S&M ENERGY-DEAN STUESSY A 1		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-DEAN STUESSY B 2		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-DEAN STUESSY C 4		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-DEAN STUESSY D 5		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-HERBERT STUESSY -A- 6		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-HERBERT STUESSY 3		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-PETERS A		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-SPRETZ 1		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
S&M ENERGY-SPRETZ A 2		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
STEINBACH 2		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
URBAN #2 2		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00
WACHSMANN 1		PDP		0.00		0.00		0.000		0.00		0.00		0.00		0.00		0.00		0.00		0.00

All Estimates Herein are Part of the PGH Petroleum & Environmental Engineers, L.L.C. Report and are Subject to its Conditions.