Force Energy Corporation (FORC) is an Oil & Gas Exploration and Development Company based in Denver, Colorado, with a primary focus on Wyoming.
Using a geology-based methodology, the US Geological Survey estimate a mean of 2.4 trillion cubic feet of undiscovered natural gas, a mean of 41 million barrels of undiscovered oil, and a mean of 20.5 million barrels of undiscovered natural gas liquids in the Wind River Basin Province of Wyoming. They further estimate a mean of 84.6 trillion cubic feet of undiscovered natural gas, a mean of 131 million barrels of undiscovered oil, and a mean of 2.6 billion barrels of undiscovered natural gas liquids in the Southwestern Wyoming Province. Force Energy Corp. has entered into LOI's to drill and develop two prospects located within each of these prolific areas.
Force Energy has entered into an LOI (Letter of Intent) to drill and develop the Diamond Springs Prospect located within the Wind River Basin. If successful, the Northwest segment of the Diamond Springs Prospect alone could yield an estimated return of approximately $190 Million in gross revenue.
Force Energy has also entered into an LOI on the Dripping Rock Prospect, located in Sweetwater County, Wyoming. Dripping Rock wells are prolific with reserves of up to 20 BCF (Billion Cubic Feet) per well with an average of 10 BCF. Assuming 50% recovery of the average Dripping Rock EUR, drilling 8 wells at $9.00 MCF gas represents an estimated $360 Million of gas potential in the ground.
Projects
Force Energy has entered into an LOI (Letter of Intent) to drill and develop the Diamond Springs Prospect located within the Wind River Basin. If successful, the Northwest segment of the Diamond Springs Prospect alone could yield an estimated return of approximately $190 Million in gross revenue.
Force Energy has also entered into an LOI on the Dripping Rock Prospect, located in Sweetwater County, Wyoming. Dripping Rock wells are prolific with reserves of up to 20 BCF (Billion Cubic Feet) per well with an average of 10 BCF. Assuming 50% recovery of the average Dripping Rock EUR, drilling 8 wells at $9.00 MCF gas represents an estimated $360 Million of gas potential in the ground.
Force Energy Corp. has a 20% working interest in the Hayter Well (10D Hayter 10-8-40-1 W4M) located in Alberta, Canada. The well was spudded in January 2007 and drilled to a total depth. The well logs revealed a gas zone of 4 to 5 meters of thickness in a shallow zone and a heavy oil pay zone of 2 meters of thickness in the target Dina Sand zone. Although the results in the Dina sand were lower than expected and a decision was made to case the well in 2007, at today’s prices, the Hayter could produce an economic well.
County Line Energy completed a $650,000 3D seismic program covering nine sections of land in pursuit of a potential multi well heavy oil drilling opportunity. The geological model was based on interpretation from a previous well, which produced 16,000 barrels of heavy oil. The seismic program was designed to determine whether the structure found in this well existed to a larger extent on the subject property. The 3D seismic revealed an extremely large anomaly with similar characteristics. The nature of this large anomaly suggested that a multi well drilling opportunity might exist. Although this well will likely be completed as a producing well the results of the drilling have negated the ultimate potential of the Hayter property.
About the Purchase of Interest in the Hayter Well
On August 1, 2006, County Line Energy Corp. (“County Line”) signed a participation agreement with Black Creek Resources Ltd. (“BCR”) in which County Line acquired the right to become the operator and drill the Hayter well (10D Hayter 10-8-40-1 W4M) located in Alberta, Canada. In order to exercise that interest and acquire the rights to drill the Hayter well, County Line agreed to pay 100% of all costs associated with the seismic option agreement and pay 100% of the funds required to purchase rights to any existing seismic on the property which may be for sale and or shoot additional 2D and 3D on the property as required, pursuant to standard industry costs and practices.
Pursuant to a Participation Agreement dated December 21, 2006 between Black Creek Resources Ltd (“BCR”) and Nuance Exploration Ltd. (“NEL”), a wholly owned subsidiary of the Company, we acquired a 100% ownership in the interpretation of 3D seismic data covering four sections of certain land located in the province of Alberta, Canada by paying $82,650 for the purpose of acquiring and interpreting the seismic data. On October 15, 2007, prior to the evaluation of the 3D seismic data, County Line sold to BCR its 100% interest in the subject property and received as consideration a non-interest bearing promissory note for $111,144 (CDN$110,000) to be repaid by November 30, 2007.
On November 30, 2007, County Line did not repay the amounts owing pursuant to the promissory note and NEL and County Line entered into a Participation Agreement whereby NEL accepted a 20% interest of the Grantor’s working interest in the County Line 10D Hayter 10-8-40-1 W4M well as full and final settlement of the promissory note. Pursuant to the terms of the Participation agreement NEL will assume 20% of all revenues, costs and expenses associated with the project.
Diamond Springs Prospect
Force Energy Corp. (FORC) has entered into an LOI (Letter of Intent) to drill and develop the Diamond Springs Prospect located within the Wind River Basin, Wyoming. Force Energy is seeking to acquire a 75% NRI (Net Revenue Interest) in G2 Petroleum’s inaugural well to be spudded sometime early summer 2008.
G2 Petroleum of Midland, Texas, holds 3,300 acres of prospective oil and natural gas property in Freemont County, Wyoming. Geological reports provided to Force Energy provide an estimated recoverable reserve of approximately 4.3 Million barrels of oil for the Diamond Springs Prospect. Force Energy has negotiated rights to purchase an additional 25% working interest in the field upon receiving results of the completion of the first well.
The Diamond Springs Prospect is comprised of 3 independent but geologically similar prospective locations within the 3,300 acre track and is situated in close proximity to productive oil and gas fields. The Northwest, North, and West Diamond Springs are shallow drilling prospects of 200’ to 1,100’ in depth, with a possible 72 drilling sites between the three locations based on 40 acre spacing.
ABOUT THE INITIAL DRILLING LOCATION
The initial shallow drilling prospect is estimated to be completed within a range of 250’ to 900’ and yield a 75’ pay-zone in the Frontier Sands (a very prolific oil-producing sand). Such a shallow well in this area is initially estimated to cost less than $350,000 for turnkey drilling.
If successful, the Northwest segment of the Diamond Springs Prospect could yield an estimated return of approximately $190 Million in gross revenue. These figures are based on the 2 Million barrels of recoverable oil present for this particular segment of the Diamond Springs Prospect in conjunction with current oil and gas pricing.
Dripping Rock Prospect
Dripping Rock Field produces gas mainly from the Cretaceous Upper Almond Formation. The producing sand is a stratigraphically trapped sand bar pinching out updip on the east side of the field. The wells in the field are prolific with reserves up to 20 BCF per well. The average well in Dripping Rock has a EUR of 10 BCF. Typical completion includes a frac. The Almond Sand is overpressured.
The Celsius MDU-20 well is located 90' fnl, 1,120' fel of section 6 and was drilled to 12,700'. Intermediate casing was set to 11,007', but no completion was attempted due to mechanical problems. No tests were run. The intermediate casing is still in this well to a depth of 11,007'. Celsius tried to set two cement plugs below the intermediate casing. Both plugs were unsuccessful due to leaking high-pressure gas. Celsius was unable to successfully kill the well with 13.6# mud. The well was finally plugged by placing a cement retainer in the intermediate casing at 9,855'. Everything below this retainer is high-pressured gas.
The Upper Almond sand was encountered in the Celsius MDU 20 well (12425-12458) and is well developed with 20' of over 12% porosity. This is typical of producing wells in the field. The Almond was cored but no description is available. The resistivity is 10ohms. The proposed location should encounter the Upper Almond 50' high to this well.
The best Almond sand is seen in the Almond Main body (12595-12620') where 16' of sand with over 12% porosity and gas effect was encountered. This sand is not present in the updip wells or in the well in the south half of section 6. This sand is comparable in porosity and resistivity to the upper Almond Sand and has the added advantage of not having been depleted by updip wells.
A secondary target is seen in the Lewis, which has several potentially productive sands. Reserves for the Lewis in the Dripping Rock Field are hard to assess as it is co-mingled with the Almond in the rare instances where it is completed. The nearest "Lewis only" production is in sec 5-T13N-R95W (seven miles to the southwest) where 15' of very tight Lewis sand has cumulated 1.8 BCF. The porosity of the Lewis sand at Dripping Rock is considerably better than this well. The Lewis is overpressured. The mud logs indicate overpressured gas from 10000' with continuous gas flares reported to the bottom of the hole, even when the mud weight was raised to 13.5 pounds
The second well in section 6 is the MDU 3 located in NWSE. This well has the Upper Almond sand (producing sand for the field) developed. The upper Almond in this well is 90' downdip from the MDU 20 well and 140' downdip from the proposed location. Pipe was run and the Upper Almond zone was perforated. This well flowed at rates 18mcf gas and 47 barrels of water during a short test. The well was abandoned without further stimulation. The core from this well had water saturations of 35% and less in the upper 10'. The resistivity logs indicate gas in the upper 10' of the Upper Almond. This well may be at the gas water contact although there appears to be a substantial transition zone that makes the contact hard to pick if it exists in this wellbore. All the wells in the field produce some water along with the gas. The average water production starts at 20 barrels per day and decreases along with the gas production.
The proposed location is the substantially updip to both the existing wells in section 6.
