FIELDPOINT PETROLEUM CORP - FORM 10-K - EX-99.1 - EXHIBIT 99.1

Attached files

file	filename
10-K - 10-K - FIELDPOINT PETROLEUM CORP	c14756e10vk.htm
EX-32 - EXHIBIT 32 - FIELDPOINT PETROLEUM CORP	c14756exv32.htm
EX-99.2 - EXHIBIT 99.2 - FIELDPOINT PETROLEUM CORP	c14756exv99w2.htm
EX-31 - EXHIBIT 31 - FIELDPOINT PETROLEUM CORP	c14756exv31.htm

Exhibit 99.1

RESERVE AND ECONOMIC EVALUATION
FIELDPOINT PETROLEUM CORPORATION
SEC CASE ECONOMICS
AS OF JANUARY 1, 2011

PREPARED FOR

RAY REEVES

FEBRUARY 11, 2011

FLETCHER LEWIS ENGINEERING, INC.


February 11, 2011		5001 N. PENNSYLVANIA, SUITE 300 PENN PARK OFFICE CENTER OKLAHOMA CITY, OKLAHOMA 73112 (405) 840-5675

Fieldpoint Petroleum Corporation
Mr. Ray Reaves
1703 Edelweiss Dr.
Cedar Park, TX 78613


		RE:		Reserve and Economic Evaluation Fieldpoint Petroleum Corporation SEC Case Economics As of January 1, 2011

Mr. Reaves:

As requested, I have prepared the Reserve and Economic Evaluation of various oil and gas properties owned by Fieldpoint Petroleum Corporation as of January 1, 2011. These evaluations consist of sixty-four (64) properties located throughout Oklahoma and Hemphill County, Texas. Many of these properties contain numerous wells with Behind-Pipe completions, additional drilling development potential and additional waterflood reserves. This report contains seventy-five (75) evaluations consisting of sixty-four (64) Proved Developed Producing properties, nine (9) Behind-Pipe properties and two (2) Proved Undeveloped properties. The two Proved Undeveloped properties consist of three (3) increased density wells to be drilled.

FLETCHER LEWIS ENGINEERING, INC.

Fieldpoint Petroleum Corporation
SEC Case
Page 2

The Future Net Reserves and Future Net Revenue of the evaluated Fieldpoint Petroleum Corporation interests as of January 1, 2011, are as follows:


					FUTURE		DISCOUNTED
					NET		PRESENT
	NET OIL		NET GAS		REVENUE		WORTH 10%
	(BBLS)		(MCF)		$		$

Proved Developed Producing		70,529		111,742		3,532,924		2,199,304
Behind-Pipe		112,649		397,557		6,718,551		3,158,607
Proved Undeveloped		13,677		11,287		802,183		361,910

Summary Proved		196,855		520,586		11,053,658		5,719,821

Following this report is a table listing the individual well or lease locations and the evaluated Working Interest and Net Revenue Interest. Following is a table listing the individual and summary Future Net Reserves and Future Net Revenue as of January 1, 2011. Also following this report are the individual production and economic projections of each of these wells and their summaries.

RESERVE CATEGORIES

The reserves were assigned as Producing, Possible and Probable. There may be some variation on the individual reserve entity but the aggregate of the reserves were multiple entities should adhere to the required probabilities.

FLETCHER LEWIS ENGINEERING, INC.

Fieldpoint Petroleum Corporation
SEC Case
Page 3

The reserves are estimated and anticipated to be recovered from known accumulations from a given date forward. These are based on the analysis of drilling, geological, geophysical and engineering data with the use of established technology under specified economic conditions which are generally accepted as being reasonable.

Proved reserves are those reserves that can be estimated with a high degree of certainty to be recoverable. There is at least a 90% probability that the quantities actually recovered will equal or exceed the estimated Proved reserves.

Probable reserves are those additional reserves are less certain to be recovered than Proved reserves. There is at least a 50% probability that the quantity actually recovered will equal or exceed the sum of the estimated Probable reserves.

Possible reserves are those additional reserves that are less certain to be recovered than Probable reserves. There is at least 10% probability that the quantity actually recovered will equal or exceed the sum of the estimated Possible reserves.

RESERVE DETERMINATION

All of the evaluated properties are disbursed by Ram Operating Company, although only slightly more than half are operated. The Ram Operating Company properties have production histories available through August and October 2010. The outside operated properties had sales histories available through August 2010.

FLETCHER LEWIS ENGINEERING, INC.

Fieldpoint Petroleum Corporation
SEC Case
Page 4

The Proved Developed Producing properties were assigned reserves by assigning the latest available production rates and then extrapolating each property’s historical production decline until its economic limit was reached.

The Mount Gilcrease Unit has significant Behind-Pipe reserves located throughout the unit. Productive Calvin, Thurman, Earlsboro and Lower Booch sands are found in numerous wells; nineteen of these wells have been completed in these sands, although it should be noted that in these wellbores, additional Behind-Pipe sands still exist. Behind-Pipe Lower Booch reserves were assigned to twenty-five (25) of the remaining forty-seven (47) wellbores on a ten acre tract basis and on ten (10) of the fifteen (15) wellbores for the Calvin, Thurman and Earlsboro sands on a 40 acre tract basis; utilizing the porosities, water saturation and feet of net pay exhibited in the well logs, a 90% gas recovery factor for the Calvin, Thurman and Earlsboro zones and a 20% recovery factor for the Booch zones. These wells were scheduled to be completed in 2014 to 2018. These Behind-Pipe reserves are presented in two evaluations.

An additional two Gilcrease zones have been found to be productive in a recent recompletion and these same two zones are Behind-Pipe on the Britt Lease. Reserves were determined volumetrically utilizing the average net pay; porosity and water saturation exhibited though the area and a 15% recovery factor with a ten acre drainage per Behind-Pipe well. It is estimated that there are two wells with Behind-Pipe Gilcrease intervals in this lease. Reserves were assigned using an average initial production rate and decline to produce the volumetric reserves of each well and the recompletions are scheduled for January 2013.

FLETCHER LEWIS ENGINEERING, INC.

Fieldpoint Petroleum Corporation
SEC Case
Page 5

The Diamond Lease is producing from the Booch formation which is currently being waterflooded and has seen its initial response in 2009. Additional Behind-Pipe Earlsboro and Thurman reserves were assigned in four wellbores as seen in the well logs with reserves based on the regional volumetric recoveries and a 40 acre drainage area per well; these Behind-Pipe reserves were scheduled for January 2013.

The Butler property has an additional well with Behind-Pipe Gilcrease, Booch, Thurman and Earlsboro reserves. Gas reserves were assigned the Thurman and Earlsboro on a 40 acre basis utilizing the exhibited net pays, porosities and water saturations and utilizing a 90% recovery factor and oil reserves for the Gilcrease and Booch on a ten acre basis utilizing a 20% recovery factor. This recompletion was scheduled for January 2013. There is also an additional drilling location to be completed in the Gilcrease, Booch and Senora formations that was assigned Proved Undeveloped reserves. Reserves were determined volumetrically and by offset analogous production.

The Nan #1-30 has Behind-Pipe Booch and Thurman and the Nan #2-30 has Behind-Pipe Thurman. The Nan #1-30 was scheduled to complete the Behind-Pipe zones in January 2012, and the Nan #2-30 was scheduled to complete the Behind-Pipe zone in April 2012.

The Provence A lease has six Behind-Pipe Cromwell zones which are scheduled to be recompleted in July 2012, 2013, 2014. There are also an additional two drilling locations which were scheduled to be drilled July 2012 and were assigned Proved Undeveloped reserves. These reserves were assigned based on analogous production.

FLETCHER LEWIS ENGINEERING, INC.

Fieldpoint Petroleum Corporation
SEC Case
Page 6

Reserve estimates are only as reliable as the amount and quality of data that is available. The reserves assigned were developed with accepted engineering and evaluation principles, and are believed to be reasonable; however, the reserves should be accepted with the understanding that additional information subsequent to the date of this report might require their revision.

ECONOMIC ANALYSIS

The SEC rules require an average oil and gas price to be used that is derived from the first of the month oil and gas spot market prices as of the first of the month beginning in January through December 2010. The average posted price used was $74.13 per barrel and $4.23 per MCF. The individual first of the month prices and average prices are as follows:


	OIL PRICE		GAS PRICE
JAN 1, 2010	$	74.44	$	5.79
FEB 1, 2010	$	69.60	$	5.43
MAR 1, 2010	$	73.64	$	4.74
APR 1, 2010	$	79.69	$	3.83

FLETCHER LEWIS ENGINEERING, INC.

Fieldpoint Petroleum Corporation
SEC Case
Page 7


MAY 1, 2010	$	80.92	$	3.95
JUN 1, 2010	$	67.37	$	3.96
JUL 1, 2010	$	67.66	$	4.58
AUG 1, 2009	$	73.61	$	4.29
SEP 1, 2010	$	68.22	$	3.32
OCT 1, 2010	$	75.92	$	3.57
NOV 1, 2010	$	77.30	$	3.06
DEC 1, 2010	$	81.18	$	4.18
AVERAGE	$	74.13	$	4.23

The monthly oil price actually received was $1.21 per barrel below the posted prices and an oil price of $72.92 was used for these properties. This price was held constant for the life of the evaluation.

This average posted gas price was then adjusted by the individual remittances (differential) to assign the average price for each well. Plant products were incorporated into the gas price. These gas prices were held constant for the life of this evaluation.

Operating expenses were examined and the average historical operating expenses were calculated for each property utilizing Joint Interest Billings supplied to Fieldpoint Petroleum. The Behind-Pipe and Proved Undeveloped properties were assigned operating expenses typical to the formation and area. These operating expenses were held constant throughout the life of the evaluation.

FLETCHER LEWIS ENGINEERING, INC.

Fieldpoint Petroleum Corporation
SEC Case
Page 8

The estimated costs for completing the Behind-Pipe zones in the Mount Gilcrease Unit are $15,000.00 per Lower Booch completion and $15,000.00 per well for the shallower gas completions (the shallower completions will require additional cementing costs) for a single zone completion. The estimated costs for to recomplete the Nan #1 is $18,000.00 and the Nan #2 is $55,000.00. The Butler Behind-Pipe completion is $25,000.00, with $60,000.00 to drill the additional well. The Provence A Behind-Pipe recompletion costs are $15,000.00 per well with $35,000.00 to drill and complete each of the two proposed wells.

Applicable Severance and Ad Valorum Taxes have been considered in the economic evaluations. No consideration has been given to depreciation or Federal or State Income Taxes. Also, no future value was given for salvage equipment nor future costs to plug or abandon these wells (in most cases the salvage value is equal to plugging costs), for this evaluation.

GENERAL

In evaluating the information available for this appraisal only the engineering data was evaluated with no potential legal or accounting considerations. The conclusions expressed were derived using accepted and sound engineering methods; however, inherent uncertainties in interpretations of engineering data do exist and the conclusions represent only informed professional judgment.

FLETCHER LEWIS ENGINEERING, INC.

Fieldpoint Petroleum Corporation
SEC Case
Page 9

The basic data and computations are not in this report, but are available for inspection and study by authorized parties. Should any additional information be required, please do not hesitate to call.

Sincerely,

Fletcher Lewis, P.E.

Fieldpoint- report 2011 sec

GENERAL INFORMATION
FIELDPOINT PETROLEUM CORPORATION PROPERTIES

NET

WORKING

REVENUE

INTEREST

WELL NAME

LOCATION

COUNTY

ALEXANDER #1-3

3 B&B SUR

HEMPHILL

0.0585

0.0180

BARGER #1-11

11-9N-11W

CADDO

0.1953

0.1587

BARGER #2-11

11-9N-11W

CADDO

0.1953

0.1485

BARROW #1-31

31-10N-11W

CADDO

0.0974

0.0842

BARROW #2-31

31-10N-11W

CADDO

0.3896

0.3367

BRITT LEASE

20-4N-7E

PONTOTOC

25.0000

18.5797

BRITT 10 LEASE

20-4N-7E

PONTOTOC

25.0000

20.3125

LOWINDA BROWN #6-8

7-1N-8E

COAL

21.8750

9.5703

OIL

19.5703

GAS

BUTLER LEASE

30-5N-8E

PONTOTOC

25.0000

20.9003

CHANUTE LEASE

36-5N-7E

PONTOTOC

25.0000

21.8750

CITY OF ARDMORE #1-3

3-5S-2E

CARTER

0.8536

0.6651

DEVAUGHAN #1-31

31-10N-11W

CADDO

0.3896

0.3367

DIAMOND LEASE

30-5N-8E

PONTOTOC

25.0000

20.8840

ECKROAT #1-15

OKLAHOMA

16.7637

13.4109

FRANK EDGE #1-11

11-9N-11W

CADDO

0.1953

0.1587

IDA EDGE #1-11

11-9N-11W

CADDO

0.1953

0.1587

FOLMAR #1-27

27-12N-2W

OKLAHOMA

17.1875

14.9274

DORA HELMS #3-2

2-1N-7E

OKLAHOMA

18.8423

15.7478

DORA HELMS #4-2

2-1N-7E

PONTOTOC

18.8423

17.1831

HENDRICKS #1-15

15-6N-9W

CADDO

0.1094

0.0634

HENDRICKS TRUST #1-27

27-12N-2W

OKLAHOMA

25.0000

20.3125

IDA HOLLIE #1-20

20-7N-23E

LEFLORE

0.5207

0.4232

IDA HOLLIE #2-20

20-7N-23E

LEFLORE

0.5207

0.4232

E E HOUSE #1-12

12-1N-7E

PONTOTOC

21.8750

9.5704

OIL

19.1407

GAS

E E HOUSE #10-12

12-1N-7E

PONTOTOC

21.8750

9.5704

OIL

21.8750

GAS

JESSIE #1-24

24-12N-13W

CADDO

0.4035

0.3531

JESSIE TOWNSITE #1-2

2-1N-7E

PONTOTOC

18.8064

17.0021

KOLB #1-15

15-12N-2W

OKLAHOMA

21.8750

17.7734

fieldpoint 2011 — TABLESGENERAL

GENERAL INFORMATION
FIELDPOINT PETROLEUM CORPORATION PROPERTIES

NET

WORKING

REVENUE

INTEREST

WELL NAME

LOCATION

COUNTY

LEWIS #1-11

11-5N-2W

MCCLAIN

11.2386

9.6085

LIVELY #1-6

6-5N-20E

LATIMER

0.3906

0.2930

MCBRIDE #1-8

8-9N-11W

CADDO

0.0977

0.0794

MCCURTAIN #1-1

1-1N-7E

PONTOTOC

20.5625

17.9922

MCDONALD LEASE

19-5N-8E

PONTOTOC

25.0000

21.8750

MCINTOSH #1-11

11-4N-9W

COMANCHE

0.1297

0.0979

MOONEY #1-29

29-6N-2W

MCCLAIN

17.1875

13.6211

MOUNT GILCREASE #3-12

36-5N-7E

PONTOTOC

25.0000

21.8750

MOUNT GILCREASE #8-6

36-5N-7E

PONTOTOC

25.0000

21.8750

MOUNT GILCREASE #8-9

36-5N-7E

PONTOTOC

25.0000

21.8750

MOUNT GILCREASE UNIT

25,26&35-5N-7E

PONTOTOC

25.0000

21.7707

MUSE #1-33

33-2N-7E

PONTOTOC

6.2500

5.4688

NAN #1-30

30-5N-8E

PONTOTOC

25.0000

19.8242

NAN #2-30

30-5N-8E

PONTOTOC

25.0000

19.8242

NORTHEAST FITTS UNIT

22 & 23-2N-7E

PONTOTOC

0.0009

.00075

PARMENTER #2-4

4-18N-15W

DEWEY

2.8438

2.2395

K O PAYNE #1-10

10-17N-12W

BLAINE

1.1349

0.9431

PETTYJOHN B

1-1N-7E

PONTOTOC

25.0000

20.5078

CE PETTYJOHN

1-1N-7E

PONTOTOC

25.0000

20.5078

GLADYS PETTYJOHN

1-1N-7E

PONTOTOC

25.0000

21.0937

POLLARD #2-31

31-19N-4W

LOGAN

4.5921

3.7411

POWELL D #1-22

22-7N-8W

GRADY

3.1250

2.5000

PROVENCE #1-2

2-1N-7E

PONTOTOC

25.0000

20.8733

PROVENCE A LEASE

2-1N-7E

PONTOTOC

25.0000

20.8733

ROSSER #1-31

31-10N-11W

CADDO

0.0974

0.0842

ROZIE #1-31

31-10N-11W

CADDO

0.0974

0.0760

SANDY A #1-8

8-1N-8E

COAL

4.9781

4.0771

SHAW #1-11

11-9N-11W

CADDO

0.1953

0.1587

R W SIMPSON #1-12

12-1N-7E

PONTOTOC

21.8750

19.1407

TEX #1-14

14-4N-16E

PITTSBURG

0.8203

0.6768

fieldpoint 2011 — TABLESGENERAL

GENERAL INFORMATION
FIELDPOINT PETROLEUM CORPORATION PROPERTIES

NET

WORKING

REVENUE

INTEREST

WELL NAME

LOCATION

COUNTY

THOMAS #1-20

20-2N-7E

PONTOTOC

21.8750

18.8241

GEORGE THOMPSON #1-1

1-1N-7E

PONTOTOC

15.1563

12.3145

PHARR THOMPSON #1-2

2-1N-7E

PONTOTOC

5.6989

4.9680

THOMPSON HEIRS #4 & 5-1

1-1N-7E

PONTOTOC

17.5938

15.0108

TROGDEN #1-15

15-6N-9W

CADDO

0.0936

0.0708

VIRGINIA #1-31

31-10N-11W

CADDO

0.0974

0.0676

fieldpoint 2011 — TABLESGENERAL

RESERVE AND ECONOMIC EVALUATION
FIELDPOINT PETROLEUM CORPORATION
AS OF JANUARY 1, 2011


		NET OIL		NET GAS		FUTURE NET		DISCOUNTED
NAME	STATUS	BBLS		MCF		CASHFLOW		10% $

ALEXANDER #1-3	PDP		0		0		0		0
BARGER #1-11	PDP		3		135		231		191
BARGER #2-11	PDP		2		17		35		32
BARROW #1-31	PDP		4		312		926		692
BARROW #2-31	PDP		11		1,076		3,920		2,913
BRITT LEASE	PDP		0		0		0		0
BRITT 10 LEASE	BHP		6,799		0		413,105		212,290
BRITT 10 LEASE	PDP		0		0		0		0
LOWINDA BROWN #6-8	PDP		1,516		17,299		108,934		74,527
BUTLER LEASE	PDP		6		18		1		1
	BHP		564		61,238		116,614		80,712
	PUD		9,405		11,287		592,325		237,065
CHANUTE LEASE	PDP		1,751		0		61,499		41,375
CITY OF ARDMORE #1-3	PDP		0		1,706		2,918		2,325
DEVAUGHAN #1-31	PDP		2		486		1,414		1,153
DIAMOND LEASE	PDP		20,228		0		937,635		602,086
	BHP		0		18,265		26,593		19,264
ECKROAT #1-15	PDP		0		0		0		0
FRANK EDGE #1-11	PDP		3		57		109		96
IDA EDGE #1-11	PDP		10		298		966		709
FOLMAR #1-27	PDP		5,743		0		320,667		176,334
DORA HELMS #3-2	PDP		336		11,241		39,051		25,764
DORA HELMS #4-2	PDP		0		4,743		7,259		5,532
HENDRICKS #1-15	PDP		0		47		37		34
HENDRICKS TRUST #1-27	PDP		0		0		0		0
IDA HOLLIE #1-20	PDP		0		1,555		4,341		3,464
IDA HOLLIE #2-20	PDP		0		146		65		60
E E HOUSE #1-12	PDP		985		5,265		72,489		52,365
E E HOUSE #10-12	PDP		0		22,611		53,447		34,465
JESSIE #1-24	PDP		0		598		774		624
JESSIE TOWNSITE #1-2	PDP		5,876		0		346,962		196,270
KOLB #1-15	PDP		0		0		0		0

fieldpoint 2011 — TABLES

RESERVE AND ECONOMIC EVALUATION
FIELDPOINT PETROLEUM CORPORATION
AS OF JANUARY 1, 2011


		NET OIL		NET GAS		FUTURE NET		DISCOUNTED
NAME	STATUS	BBLS		MCF		CASHFLOW		10% $

LEWIS #1-11	PDP		326		22,794		125,211		61,678
LIVELY #1-6	PDP		0		435		710		627
MCBRlDE #1-8	PDP		0		0		0		0
MCCURTAIN #1-1	PDP		295		964		9,670		7,876
MCDONALD LEASE	PDP		876		0		13,752		11,707
	BHP		6,264		16,615		431,241		264,656
MCINTOSH #1-11	PDP		0		8		1		1
MOONEY #1-29	PDP		1,259		0		48,061		27,742
MOUNT GILCREASE #3-12	PDP		0		0		0		0
MOUNT GILCREASE #8-6	PDP		0		0		0		0
MOUNT GILCREASE #8-9	PDP		0		1,351		166		158
MOUNT GILCREASE UNIT	PDP		8,575		0		160,307		134,960
	BHP		0		279,036		383,045		259,343
	BHP		83,663		0		4,526,768		1,826,524
MUSE #1-33	PDP		1,206		0		63,577		35,111
NAN #1-30	PDP		726		0		14,284		11,424
	BHP		0		22,403		39,825		30,943
NAN #2-30	BHP		2,974		0		173,313		119,031
NORTHEAST FITTS UNIT	PDP		134		0		4,790		3,839
PARMENTER #2-4	PDP		6		813		1,373		1,120
K O PAYNE #1-10	PDP		0		0		0		0
PETTYJOHN B	PDP		0		0		0		0
CE PETTYJOHN	PDP		80		3,577		2,905		2,778
GLADYS PETTYJOHN	PDP		0		0		0		0
POLLARD #2-31	PDP		77		1,217		2,640		2,191
POWELL D #1-22	PDP		0		3,725		8,217		5,869
PROVENCE #1-2	PDP		0		0		0		0
PROVENCE A LEASE	PDP		0		5,270		4,190		3,517
	BHP		12,385		0		608,047		345,846
	PUD		4,272		0		209,858		124,845
ROSSER #1-31	PDP		1		172		555		403
ROZIE #1-31	PDP		2		310		689		523

fieldpoint 2011 — TABLES

RESERVE AND ECONOMIC EVALUATION
FIELDPOINT PETROLEUM CORPORATION
AS OF JANUARY 1, 2011


		NET OIL		NET GAS		FUTURE NET		DISCOUNTED
NAME	STATUS	BBLS		MCF		CASHFLOW		10% $

SANDY A #1-8	PDP		0		0		0		0
SHAW #1-11	PDP		0		0		0		0
R W SIMPSON #1-12	PDP		0		0		0		0
SPENCER #1-23	PDN		0		0		0		0
TEX #1-14	PDP		0		2,041		2,635		1,898
THOMAS #1-20	PDP		15,416		0		866,727		516,740
GEORGE THOMPSON #1-1	PDP		2,188		0		110,329		62,649
PHARR THOMPSON #1-2	PDP		141		1,285		6,001		4,248
THOMPSON HEIRS #4 & 5-1	PDP		2,743		0		122,226		81,056
TROGDEN #1-15	PDP		0		3		0		0
VIRGINIA #1-31	PDP		1		168		199		177

PROVED DEVELOPED PRODUCING			70,529		111,742		3,532,924		2,199,304
BEHIND-PIPE			112,649		397,557		6,718,551		3,158,607

PROVED UNDEVELOPED			13,677		11,287		802,183		361,910
SUMMARY PROVED			196,855		520,586		11,053,658		5,719,821

fieldpoint 2011 — TABLES

RESERVES AND ECONOMICS

SUMMARY

AS OF JAN 1, 2011
Run Date 2/4/2011 5:21

INTERESTS AND DATE FIRST EFFECTIVE

PRESENT WORTH M$

COST

LIQUID

GAS

DATE

5.000

7715.855

10.000

5719.821

15.000

4441.976

20.000

3577.572

25.000

2966.070


	WELL COUNT				API	BASE	TRANS	PROD	ADVAL	PRICES						CF/BBL		GROSS		RESERVES				% GROSS
	GROSS		NET		OR BTU	PRICE	CHARGE	TAXES	TAXES	BEGIN		ENDING		LIFE WT		BL/MMCF		CUMULATIVE		REMAINING		ULTIMATE		REMAINING
OIL		156		33.54							72.92		72.92		72.92		5064		7835.36		1161.90		8997.26	12.91% OIL
GAS		40		5.03							4.43		4.61		2.71		197		88514.53		6140.85		94655.37	6.49% GAS
COND		0		0.00							72.92		72.92		72.92		0		368.88		50.81		419.70	12.11% COND


	GROSS		GROSS OIL +		GROSS GAS		NET OIL		NET GAS		EFF OIL &		EFFECTIVE		OIL + COND		GAS		TOTAL
	WELL COUNT		COND PROD		PRODUCTION		COND PROD		PRODUCTION		COND PRICE		GAS PRICE		SALES		SALES		SALES
YEAR	WELLS/MO		MBBLS		MMCF		MBBLS		MMCF		$/BBL		$/MCF		M$		M$		M$
2011		108.000		87.733		761.738		8.184		14.836		72.920		4.472		596.793		66.355		663.147
2012		112.000		88.689		709.758		9.570		25.982		72.920		3.928		697.835		102.046		799.881
2013		119.000		93.191		698.183		11.811		46.468		72.920		3.268		861.233		151.846		1013.079
2014		131.000		94.258		1164.033		13.142		163.347		72.920		2.170		958.335		354.486		1312.821
2015		139.000		95.322		938.672		14.411		129.412		72.920		2.167		1050.849		280.501		1331.349
2016		142.000		93.431		523.565		14.858		49.751		72.920		2.418		1083.439		120.286		1203.725
2017		86.000		89.726		374.258		14.833		29.843		72.920		2.635		1081.649		78.627		1160.276
2018		88.000		88.280		247.251		15.215		13.315		72.920		3.342		1109.514		44.496		1154.009
2019		71.000		73.983		180.337		14.028		9.412		72.920		3.606		1022.891		33.937		1056.828
2020		69.000		62.354		142.813		12.367		6.535		72.920		4.143		901.792		27.072		928.864
2021		66.000		54.920		109.077		10.878		4.949		72.920		4.482		793.204		22.185		815.389
2022		65.000		47.648		81.204		9.440		4.378		72.920		4.496		688.331		19.683		708.014
2023		62.000		40.858		52.008		8.081		3.629		72.920		4.554		589.296		16.524		605.820
2024		61.000		35.823		32.205		7.104		3.234		72.920		4.555		518.029		14.729		532.758
2025		58.000		31.498		22.533		6.247		2.821		72.920		4.565		455.531		12.879		468.410
SUB TOTAL		142.000		1077.714		6037.635		170.169		507.910		72.920		2.649		12408.719		1345.652		13754.371
REMAINDER		55.000		134.995		103.212		26.686		12.676		72.920		5.311		1945.943		67.320		2013.263
TOT 36.7 YR		142.000		1212.709		6140.847		196.855		520.586		72.920		2.714		14354.662		1412.972		15767.635


	EFFECTIVE		NET TOTAL		DIR OPR EXP		TOT OPR EXP		OPERATING		TOT INVEST		NET		CUM NET		NET C.F		CUM C.F
	WPT TAX		PROD TAXES		ADVAL TAX		+ TAXES		REVENUE		TANG+INTANG		CASHFLOW		CASHFLOW		DISC @ 10.0		DISC @ 10.0
YEAR	M$		M$		M$		M$		M$		M$		M$		M$		M$		M$
2011		0.000		47.765		159.356		207.121		456.026		0.000		456.026		456.026		434.133		434.133
2012		0.000		57.537		168.970		226.506		573.375		49.250		524.125		980.151		450.540		884.673
2013		0.000		72.888		194.113		267.001		746.078		51.250		694.828		1674.979		544.518		1429.191
2014		0.000		94.452		218.637		313.089		999.732		48.750		950.982		2625.960		677.538		2106.729
2015		0.000		95.793		236.636		332.429		998.920		33.750		965.170		3591.130		626.873		2733.602
2016		0.000		86.614		221.134		307.748		895.976		18.750		877.226		4468.357		517.361		3250.963
2017		0.000		83.474		164.933		248.408		911.869		18.750		893.119		5361.475		478.453		3729.417
2018		0.000		83.040		152.384		235.424		918.585		18.750		899.835		6261.311		438.712		4168.129
2019		0.000		76.038		143.232		219.270		837.558		0.000		837.558		7098.869		371.633		4539.762
2020		0.000		66.839		141.046		207.886		720.979		0.000		720.979		7819.848		290.890		4830.652
2021		0.000		58.672		138.998		197.669		617.720		0.000		617.720		8437.568		226.579		5057.230
2022		0.000		50.951		137.326		188.277		519.737		0.000		519.737		8957.305		173.387		5230.617
2023		0.000		43.589		133.761		177.350		428.470		0.000		428.470		9385.775		129.878		5360.495
2024		0.000		38.336		133.250		171.586		361.172		0.000		361.172		9746.947		99.541		5460.036
2025		0.000		33.704		132.188		165.892		302.518		0.000		302.518		10049.465		75.801		5535.837
SUB TOTAL		0.000		989.693		2475.963		3465.656		10288.715		239.250		10049.465		10049.465		5535.837		5535.837
REMAINDER		0.000		144.828		864.242		1009.070		1004.193		0.000		1004.193		11053.658		183.984		5719.821
TOT 36.7 YR		0.000		1134.521		3340.205		4474.726		11292.908		239.250		11053.658		11053.658		5719.821		5719.821

RESERVES AND ECONOMICS

SUMMARY
PROVED DEVELOPED PRODUCING

AS OF JAN 1, 2011
Run Date 2/4/2011 5:14


INTERESTS AND DATE FIRST EFFECTIVE				PRESENT WORTH M$
COST	LIQUID	GAS	DATE		5.000	2714.550
					10.000	2199.304
					15.000	1851.176
					20.000	1602.506
					25.000	1416.931


	WELL		COUNT		API	BASE	TRANS.	PROD.	ADVAL	PRICES						CF/BBL		GROSS		RESERVES				% GROSS
	GROSS		NET		OR BTU	PRICE	CHARGE	TAXES	TAXES	BEGIN		ENDING		LIFE WT		BL/MMCF		CUMULATIVE		REMAINING		ULTIMATE		REMAINING
OIL		115		23.29							72.92		72.92		72.92		6833		7794.51		568.54		8363.04	6.80% OIL
GAS		25		1.28							4.43		5.91		4.91		146		88481.07		4232.13		92713.20	4.56% GAS
COND		0		0.00							72.92		72.92		72.92		0		368.88		50.81		419.70	12.11% COND


	GROSS		GROSS OIL +		GROSS GAS		NET OIL		NET GAS		EFF OIL &		EFFECTIVE		OIL + COND		GAS		TOTAL
	WELL COUNT		COND PROD		PRODUCTION		COND PROD		PRODUCTION		COND PRICE		GAS PRICE		SALES		SALES		SALES
YEAR	WELLS/MO		MBBLS		MMCF		MBBLS		MMCF		$/BBL		$/MCF		M$		M$		M$
2011		108.000		87.733		761.738		8.184		14.836		72.920		4.472		596.793		66.355		663.147
2012		104.000		80.249		644.901		7.832		12.922		72.920		4.593		571.100		59.348		630.447
2013		101.000		70.316		529.088		7.163		11.366		72.920		4.689		522.300		53.293		575.593
2014		100.000		62.150		453.362		6.494		9.808		72.920		4.742		473.563		46.509		520.072
2015		99.000		54.788		379.625		5.896		8.555		72.920		4.788		429.935		40.962		470.897
2016		97.000		47.423		327.978		5.120		7.730		72.920		4.807		373.344		37.157		410.501
2017		40.000		37.830		264.683		3.785		6.425		72.920		4.913		276.029		31.565		307.594
2018		37.000		33.166		210.178		3.415		5.596		72.920		4.891		249.058		27.368		276.426
2019		32.000		22.852		158.971		3.073		4.946		72.920		4.918		224.053		24.326		248.378
2020		30.000		17.723		132.760		2.811		4.435		72.920		4.939		204.969		21.907		226.876
2021		28.000		15.930		103.554		2.534		3.795		72.920		4.972		184.760		18.871		203.630
2022		27.000		14.099		76.856		2.264		3.469		72.920		4.984		165.057		17.289		182.345
2023		26.000		12.539		49.423		2.023		3.089		72.920		5.035		147.546		15.552		163.099
2024		25.000		11.053		29.749		1.809		2.721		72.920		5.074		131.917		13.806		145.723
2025		22.000		9.811		20.200		1.616		2.333		72.920		5.144		117.839		12.001		129.839
SUB TOTAL		108.000		577.662		4143.066		64.019		102.024		72.920		4.767		4668.261		486.307		5154.568
REMAINDER		19.000		41.686		89.061		6.510		9.718		72.920		6.379		474.709		61.996		536.705
TOT 36.7 YR		108.000		619.348		4232.127		70.529		111.742		72.920		4.907		5142.970		548.303		5691.274


	EFFECTIVE		NET TOTAL		DIR OPR EXP		TOT OPR EXP		OPERATING		TOT INVEST		NET		CUM NET		NET C.F.		CUM C.F.
	WPT TAX		PROD TAXES		ADVAL TAX		+ TAXES		REVENUE		TANG+INTANG		CASHFLOW		CASHFLOW		DISC [ILLEGIBLE] 10.0		DISC [ILLEGIBLE] 10.0
YEAR	M$		M$		M$		M$		M$		M$		M$		M$		M$		M$
2011		0.000		47.765		159.356		207.121		456.026		0.000		456.026		456.026		434.133		434.133
2012		0.000		45.358		158.020		203.377		427.070		0.000		427.070		883.096		369.126		803.258
2013		0.000		41.410		157.213		198.623		376.970		0.000		376.970		1260.066		296.248		1099.506
2014		0.000		37.418		154.437		191.855		328.216		0.000		328.216		1588.283		234.519		1334.026
2015		0.000		33.887		152.336		186.223		284.674		0.000		284.674		1872.956		184.985		1519.011
2016		0.000		29.540		135.134		164.674		245.827		0.000		245.827		2118.783		145.228		1664.239
2017		0.000		22.125		69.233		91.359		216.236		0.000		216.236		2335.019		116.030		1780.269
2018		0.000		19.899		64.684		84.583		191.843		0.000		191.843		2526.862		93.688		1873.957
2019		0.000		17.866		59.832		77.698		170.681		0.000		170.681		2697.543		75.682		1949.639
2020		0.000		16.326		59.246		75.573		151.303		0.000		151.303		2848.846		61.038		2010.677
2021		0.000		14.660		57.998		72.657		130.973		0.000		130.973		2979.819		48.089		2058.766
2022		0.000		13.125		57.926		71.052		111.294		0.000		111.294		3091.113		37.123		2095.889
2023		0.000		11.735		57.561		69.296		93.803		0.000		93.803		3184.915		28.434		2124.323
2024		0.000		10.492		57.050		67.542		78.181		0.000		78.181		3263.096		21.570		2145.893
2025		0.000		9.342		55.988		65.330		64.509		0.000		64.509		3327.605		16.166		2162.059
SUB TOTAL		0.000		370.950		1456.013		1826.963		3327.605		0.000		3327.605		3327.605		2162.059		2162.059
REMAINDER		0.000		38.595		292.792		331.387		205.318		0.000		205.318		3532.924		37.245		2199.304
TOT 36.7 YR		0.000		409.545		1748.805		2158.350		3532.924		0.000		3532.924		3532.924		2199.304		2199.304

RESERVES AND ECONOMICS

SUMMARY
BEHIND-PIPE

AS OF JAN 1, 2011

Run Date 2/4/2011 5:18


INTERESTS AND DATE FIRST EFFECTIVE				PRESENT WORTH M$
COST	LIQUID	GAS	DATE
					5.000	4482.312
					10.000	3158.607
					15.000	2324.040
					20.000	1770.171
					25.000	1386.783


	WELL		COUNT		API	BASE	TRANS	PROD	ADVAL	PRICES						CF/BBL		GROSS		RESERVES				% GROSS
	GROSS		NET		OR BTU	PRICE	CHARGE	TAXES	TAXES	BEGIN		ENDING		LIFE WT		BL/MMCF		CUMULATIVE		REMAINING		ULTIMATE		REMAINING
OIL		37		9.25							0.00		72.92		72.92		3513		0.00		527.90		527.90	100.00% OIL
GAS		15		3.75							0.00		2.57		2.12		285		0.00		1854.72		1854.72	100.00% GAS
COND		0		0.00							0.00		0.00		0.00		0		0.00		0.00		0.00	0.00% COND


	GROSS		GROSS OIL +		GROSS GAS		NET OIL		NET GAS		EFF OIL &		EFFECTIVE		OIL + COND		GAS		TOTAL
	WELL COUNT		COND PROD		PRODUCTION		COND PROD		PRODUCTION		COND PRICE		GAS PRICE		SALES		SALES		SALES
YEAR	WELLS/MO		MBBLS		MMCF		MBBLS		MMCF		$/BBL		$/MCF		M$		M$		M$
2011		0.000		0.000		0.000		0.000		0.000		0.000		0.000		0.000		0.000		0.000
2012		6.000		6.712		64.857		1.377		13.060		72.920		3.269		100.411		42.699		143.109
2013		15.000		18.035		166.962		3.638		34.656		72.920		2.821		265.283		97.751		363.034
2014		28.000		26.084		706.567		5.389		152.681		72.920		2.007		392.966		306.433		699.398
2015		37.000		35.072		555.148		7.374		120.042		72.920		1.983		537.712		238.071		775.783
2016		42.000		41.041		191.883		8.700		41.247		72.920		1.982		634.404		81.736		716.140
2017		43.000		47.365		106.057		10.101		22.683		72.920		2.016		736.565		45.739		782.304
2018		48.000		50.970		33.731		10.934		7.021		72.920		2.261		797.307		15.871		813.178
2019		36.000		47.330		18.191		10.161		3.802		72.920		2.214		740.940		8.416		749.356
2020		36.000		41.136		7.037		8.826		1.470		72.920		2.742		643.592		4.031		647.623
2021		35.000		35.768		2.658		7.671		.555		72.920		4.030		559.369		2.237		561.606
2022		35.000		30.571		1.627		6.554		.340		72.920		4.030		477.918		1.370		479.288
2023		33.000		25.562		0.000		5.482		0.000		72.920		0.000		399.747		0.000		399.747
2024		33.000		22.211		0.000		4.760		0.000		72.920		0.000		347.099		0.000		347.099
2025		33.000		19.307		0.000		4.134		0.000		72.920		0.000		301.451		0.000		301.451
SUB TOTAL		48.000		447.164		1854.718		95.101		397.557		72.920		2.124		6934.765		844.352		7779.117
REMAINDER		33.000		80.738		0.000		17.548		0.000		72.920		0.000		1279.600		0.000		1279.600
TOT 24.8 YR		48.000		527.902		1854.718		112.649		397.557		72.920		2.124		8214.365		844.352		9058.717


	EFFECTIVE		NET TOTAL		DIR OPR EXP		TOT OPR EXP		OPERATING		TOT INVEST		NET		CUM NET		NET C.F		CUM C.F
	WPT TAX		PROD TAXES		ADVAL TAX		+ TAXES		REVENUE		TANG+INTANG		CASHFLOW		CASHFLOW		DISC [ILLEGIBLE]10.0		DISC [ILLEGIBLE]10.0
YEAR	M$		M$		M$		M$		M$		M$		M$		M$		M$		M$
2011		0.000		0.000		0.000		0.000		0.000		0.000		0.000		0.000		0.000		0.000
2012		0.000		10.286		9.000		19.286		123.823		31.750		92.073		92.073		77.511		77.511
2013		0.000		26.117		31.800		57.917		305.117		36.250		268.867		360.941		210.121		287.631
2014		0.000		50.321		57.900		108.221		591.177		48.750		542.427		903.368		385.662		673.293
2015		0.000		55.814		78.000		133.814		641.969		33.750		608.219		1511.587		394.949		1068.242
2016		0.000		51.529		79.700		131.229		584.911		18.750		566.161		2077.748		333.629		1401.870
2017		0.000		56.288		89.400		145.688		636.616		18.750		617.866		2695.614		330.767		1732.637
2018		0.000		58.508		81.400		139.908		673.270		18.750		654.520		3350.134		318.942		2051.580
2019		0.000		53.920		77.100		131.020		618.336		0.000		618.336		3968.470		274.419		2325.999
2020		0.000		46.601		75.500		122.101		525.522		0.000		525.522		4493.992		212.042		2538.041
2021		0.000		40.403		74.700		115.103		446.503		0.000		446.503		4940.494		163.734		2701.775
2022		0.000		34.488		73.100		107.588		371.700		0.000		371.700		5312.194		124.018		2825.793
2023		0.000		28.762		69.900		98.662		301.085		0.000		301.085		5613.280		91.268		2917.061
2024		0.000		24.973		69.900		94.873		252.226		0.000		252.226		5865.506		69.504		2986.565
2025		0.000		21.690		69.900		91.590		209.861		0.000		209.861		6075.367		52.583		3039.148
SUB TOTAL		0.000		559.700		937.300		1497.000		6282.117		206.750		6075.367		6075.367		3039.148		3039.148
REMAINDER		0.000		92.066		544.350		636.416		643.184		0.000		643.184		6718.551		119.459		3158.607
TOT 24.8 YR		0.000		651.766		1481.650		2133.416		6925.301		206.750		6718.551		6718.551		3158.607		3158.607

RESERVES AND ECONOMICS

SUMMARY
PROVED UNDEVELOPED

AS OF JAN 1, 2011

Run Date 2/4/2011 5:18


INTERESTS AND DATE FIRST EFFECTIVE				PRESENT WORTH M$
COST	LIQUID	GAS	DATE		5.000	518.992
					10.000	361.910
					15.000	266.760
					20.000	204.895
					25.000	162.357


	WELL		COUNT		API	BASE	TRANS	PROD	ADVAL	PRICES						CF/BBL		GROSS		RESERVES				% GROSS
	GROSS		NET		OR BTU	PRICE	CHARGE	TAXES	TAXES	BEGIN		ENDING		LIFE WT		BL/MMCF		CUMULATIVE		REMAINING		ULTIMATE		REMAINING
OIL		3		.75							0.00		72.920		72.92		825		0.00		65.46		65.46	100.00% OIL
GAS		0		0.00							0.00		1.80		1.80		1212		0.00		54.00		54.00	100.00% GAS
COND		0		0.00							0.00		0.00		0.00		0		0.00		0.00		0.00	0.00% COND


	GROSS		GROSS OIL +		GROSS GAS		NET OIL		NET GAS		EFF OIL &		EFFECTIVE		OIL + COND		GAS		TOTAL
	WELL COUNT		COND PROD		PRODUCTION		COND PROD		PRODUCTION		COND PRICE		GAS PRICE		SALES		SALES		SALES
YEAR	WELLS/MO		MBBLS		MMCF		MBBLS		MMCF		$/BBL		$/MCF		M$		M$		M$
2011		0.000		0.000		0.000		0.000		0.000		0.000		0.000		0.000		0.000		0.000
2012		2.000		1.728		0.000		.361		0.000		72.920		0.000		26.324		0.000		26.324
2013		3.000		4.840		2.133		1.010		.446		72.920		1.800		73.649		.803		74.452
2014		3.000		6.024		4.104		1.259		.858		72.920		1.800		91.806		1.544		93.351
2015		3.000		5.462		3.899		1.141		.815		72.920		1.800		83.202		1.467		84.669
2016		3.000		4.967		3.704		1.038		.774		72.920		1.800		75.691		1.393		77.084
2017		3.000		4.531		3.518		.947		.735		72.920		1.800		69.055		1.323		70.378
2018		3.000		4.144		3.342		.866		.698		72.920		1.800		63.149		1.256		64.405
2019		3.000		3.801		3.175		.794		.664		72.920		1.800		57.898		1.195		59.094
2020		3.000		3.495		3.016		.730		.630		72.920		1.800		53.232		1.134		54.366
2021		3.000		3.222		2.865		.673		.599		72.920		1.800		49.075		1.078		50.153
2022		3.000		2.978		2.721		.622		.569		72.920		1.800		45.356		1.024		46.380
2023		3.000		2.757		2.585		.576		.540		72.920		1.800		42.002		.972		42.974
2024		3.000		2.559		2.456		.535		.513		72.920		1.800		39.012		.923		39.936
2025		3.000		2.380		2.333		.497		.488		72.920		1.800		36.241		.878		37.120
SUB TOTAL		3.000		52.888		39.851		11.049		8.329		72.920		1.800		805.693		14.992		820.685
REMAINDER		3.000		12.571		14.151		2.628		2.958		72,920		1.800		191.634		5.324		196.958
TOT 22.5 YR		3.000		65.459		54.002		13.677		11.287		72.920		1.800		997.327		20.317		1017.643


	EFFECTIVE		NET TOTAL		DIR OPR EXP		TOT OPR EXP		OPERATING		TOT INVEST		NET		CUM NET		NET C.F.		CUM C.F.
	WPT TAX		PROD TAXES		ADVAL TAX		+ TAXES		REVENUE		TANG+INTANG		CASHFLOW		CASHFLOW		DISC [ILLEGIBLE] 10.0		DISC [ILLEGIBLE] 10.0
YEAR	M$		M$		M$		M$		M$		M$		M$		M$		M$		M$
2011		0.000		0.000		0.000		0.000		0.000		0.000		0.000		0.000		0.000		0.000
2012		0.000		1.893		1.950		3.843		22.481		17.500		4.981		4.981		3.904		3.904
2013		0.000		5.361		5.100		10.461		63.991		15.000		48.991		53.972		38.149		42.053
2014		0.000		6.713		6.300		13.013		80.338		0.000		80.338		134.310		57.357		99.411
2015		0.000		6.092		6.300		12.392		72.277		0.000		72.277		206.587		46.940		146.350
2016		0.000		5.545		6.300		11.845		65.239		0.000		65.239		271.826		38.504		184.854
2017		0.000		5.061		6.300		11.361		59.017		0.000		59.017		330.843		31.656		216.510
2018		0.000		4.633		6.300		10.933		53.472		0.000		53.472		384.315		26.081		242.591
2019		0.000		4.252		6.300		10.552		48.542		0.000		48.542		432.857		21.533		264.124
2020		0.000		3.912		6.300		10.212		44.154		0.000		44.154		477.010		17.810		281.934
2021		0.000		3.609		6.300		9.909		40.244		0.000		40.244		517.255		14.756		296.690
2022		0.000		3.337		6.300		9.637		36.743		0.000		36.743		553.998		12.246		308.935
2023		0.000		3.092		6.300		9.392		33.582		0.000		33.582		587.580		10.176		319.111
2024		0.000		2.871		6.300		9.171		30.765		0.000		30.765		618.345		8.467		327.578
2025		0.000		2.672		6.300		8.972		28.148		0.000		28.148		646.492		7.052		334.630
SUB TOTAL		0.000		59.043		82.650		141.693		678.992		32.500		646.492		646.492		334.630		334.630
REMAINDER		0.000		14.167		27.100		41.267		155.691		0.000		155.691		802.183		27.281		361.910
TOT 22.5 YR		0.000		73.210		109.750		182.960		834.683		32.500		802.183		802.183		361.910		361.910

Fletcher Lewis Engineering, Inc.

Standard Board and Rules 4-10(a) (1)-(32) of Regulation S-X and Rules 302(b), 1201, 1202(a) (1), (2), (3), (4), (8), and 1203(a) of Regulations S-K of the Securities and Exchange Commission; provided, however, future income tax expenses have not been taken into account in estimating the future net revenue and present worth values set forth herein.

Fletcher Lewis Engineering, Inc. is an independent petroleum engineering consulting firm that has been providing petroleum consulting services throughout the United States for over 28 years. Fletcher Lewis Engineering, Inc. does not have any financial interest including stock ownership, in FieldPoint. Our fees were not contingent on the results of our evaluation. Fletcher Lewis Engineering, Inc. has used all procedures and methods that it considers necessary to prepare this report.


	Submitted,
	/s/ Fletcher Lewis Engineering, Inc.
	Fletcher Lewis Engineering, Inc
	Oklahoma Registered Engineering Firm CA-804 Texas Registration ID #47928 Oklahoma Registration ID # 11663

	/s/ Fletcher Lewis, P.E.
	Fletcher Lewis, P.E.
	President Fletcher Lewis Engineering, Inc.

CERTIFICATE of QUALIFICATION

I, Fletcher Lewis, Petroleum Engineer with Fletcher Lewis Engineering, Inc., 5001 N. Pennsylvania, Suite 300, Oklahoma City, Oklahoma, 73112 U.S.A., hereby certify:

That I am President with Fletcher Lewis Engineering, Inc., which company did prepare the letter report addressed to FieldPoint dated March 1, 2010, and that I, as President, was responsible for the preparation of this report.

That I attended Oklahoma University, and that I graduated with a Master of Science degree in Petroleum Engineering in the year 1978; that I am a Registered Professional Engineer in the State of Texas and Oklahoma; that I am a member of the Society of Petroleum Engineers and the American Association of Petroleum Geologists; and that I have in excess of 35 years of experience in the oil and gas reservoir studies and reserves evaluations.


	/s/ Fletcher Lewis, P.E.
	Fletcher Lewis, P.E.
	President Fletcher Lewis Engineering, Inc.

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