Exhibit 99.3


Proved2008 Actual


Developed

Producing


Developed

Nonproducing


Undeveloped


Total

ProvedFuture Gross Revenue


76,974.15



905,479



2,716,441



-



3,621,920Production and Ad Valorem Taxes @ 7.5%


5,773.06



67,911



203,733



-



271,644Operating Expenses


3,600.00



36,000



36,000



-



72,000Capital Costs


-



-



-



-



-Abandonment


-



12,000



12,000



-



24,000Future Net Revenue


67,601



789,568



2,464,708



-



3,254,276Present Worth at 10 Percent






710,611



2,218,237



-



2,928,848Jett Rink 18.5% WI


12,506



131,463



410,374







541,837  Proved2009 Actual


Developed

Producing


Developed

Nonproducing


Undeveloped


Total

ProvedFuture Gross Revenue


32,441.29



828,505



2,716,441



-



3,544,946Production and Ad Valorem Taxes @ 7.5%


2,433.10



56,365



203,733



-



260,098Operating Expenses


3,600.00



32,400



36,000



-



68,400Capital Costs


-



-



-



-



-Abandonment


-



12,000



12,000



-



24,000Future Net Revenue


26,408



727,740



2,464,708



-



3,192,448Present Worth at 10 Percent






654,966



2,218,237



-



2,873,203Jett Rink 18.5% WI


4,886



121,169



410,374







531,543









On June 10, 2010, the Company obtained a valuation report for each of the two leases from Richard F. Mooney, a petroleum geologist/geophysicist, based on reported well data and available production history (the “Reports”).  The following is a discussion of the Reports with respect to such leases.
  Two wells were drilled in 2006, the Shilo #1, NE/4 SW/4 NE/4 NE/4 and the Shilo #2, SE/4 SW/4 NW/4 NE/4.  The wells were drilled by a now defunct operator, Mr. Dempsey Todd Shelton, of Tulsa.  The Shilo #1 originally produced 550 MCFG/D w/no water from a 10 foot Dutcher section (2940’ ─ 2950’).  From June, 2007 through November, 2009, (the available production history of the well) this well produced a cumulative 61,087 MCFG at an average monthly rate of 2068 MCFG/month and 374 BO.  Logs were not available for this well, but pertinent reservoir characteristics are well known.  Dutcher sands typically have porosities of 15 ─ 25 %.  Although the well made no water, a water saturation of 25% was assumed (again, the values for this reservoir average 14 ─ 33% in producing sands).  Allowing for a 10 acre drainage, this reservoir volumetrics calculates to 588,060 cubic feet of available reservoir.  This translates to a 104,738 barrel capacity, or 1,047,380 MCFG capacity.  Deducting the gas already produced leaves a volume of 986,287 MCFG in place.  Industry standard is a 33% primary recovery rate, leaving 284,542 MCFG available for primary recovery.  If $3/MCFG is assumed (gas is presently @ $4/MCFG), this represents a potential of $853,627 revenue for a net 100% revenue interest, or @ $85,363 for a 10% revenue interest.  Initial reservoir shut-in pressure was 875 psi (11/64 choke).  The reservoir was perf’d and given a light acid job, but not frac’d.  Historically, the production went from a high of 3,361 MCFG/M in January, 2008, and tapered off in late 2009 to a low of 625 MCFG/M in November, 2009.  This probably is more representative of the quality of the operator than reservoir quality.  This well, with a light frac and acid job and an ongoing program of pressure maintenance will potentially resume the volume of production formerly seen.
  The Shilo #2 produced from the Bartlesville sand at 2410’ ─ 2414’.  Initial production was 55MCFG + 2 BO + 1⁄4 BW per day.  Initial shut-in pressure was reported @ 800 psi and the reservoir flow via a 16/64 choke.  No production history is available for this well, but applying volumetric analysis as above (porosity is assumed @ 15% and water saturation @ 33%), then a reservoir volume of 175,111 cubic feet of volume is estimated in 10 acres.  This translates to a volumetric equivalent of 31,189 barrels.  The gas to oil ratio is roughly 27:1 and the gas equivalent is 5.5 barrels.  This means original oil in place would be 10,292 barrel - equivalent by primary recovery, or about 9,924 MCFG and 368 BO from this reservoir.  This represents a potential 100% revenue interest of $29,772 for gas and $22,080 for oil. A 10% revenue interest would be $2,977 and $2,208, respectively.  This well also was perf’d and acidized, but not frac’d.  A light frac and follow-up acid job may increase potential production.
  Oklahoma Corporation Commission Orders # 523196 (Bartlesville) and #30640 (Dutcher) place spacing at 40 acres on this acreage.  This would increase drainage area potential by a factor of 4 to the above calculations, increasing potential of a 10% revenue interest in the Shilo #1 to $341,452 and the Shilo #2 to a potential of $20,740.  Actual value of the leases will be increased by the equipment remaining in place on the lease.