PetroMax has spent over two years of reservoir analysis and geologic evaluation of the South East Texas Woodbine trend including the modeling of the early results of the horizontally drilled woodbine wells which have been drilled. The results indicate low permeabilities have historically inhibited daily flow rates in the vertical wells; and a horizontal lateral greatly increases these rates due to the expansive productive area exposed to the reservoir versus a vertical well. In January 2005 BWOC planned and drilled the Stroman#1H horizontal well in the Woodbine sand in Madison County, just 2 miles north of our prospect area. The well produced excellent results, nearly quadrupling the initial daily production values of the offsetting vertical wells. Since that first well, eleven additional horizontal wells have been drilled and completed in the field with similar results. Through the use of the new science of micro seismic evaluation, BWOC determined that "the fracs were not always being evenly distributed through the lateral." Starting in late 2006, BWOC began using the Packers Plus fracture system, which enables multi-stage fractures to be separately initiated in each 500 feet of the lateral well bore. These horizontal packer systems have had dramatic results in other horizontal trends.
The Kurten Field Woodbine sandstones are of marine-shelf origin and form a large stratigraphic trap, productive over an area in excess of 60 square miles. These sands are large, lenticular bodies that pinch out up-dip (north) of the prospect area. The Woodbine sand in the Kurten Woodbine Field averages 30-50 feet in thickness across the productive part of the field. The sand consists of fine to medium-grained, laminated sandstone with porosities ranging between 10-17% and permeabilities from 0.1 to 20 millidarcies. Until recently, all of the production from the Kurten Woodbine Field has been vertical well completions. The basic field completion consists of running casing through the sands, perforating the sand interval, and then fracture stimulating that interval to enhance daily production.
This vertical type of completion method was used through the 1970's-80's. Cumulative production in our study area has averaged 36,500 BBLS. Historically the Kurten Woodbine wells were brought on with rates of 50-75 barrels of oil per day. The lower daily rates were primarily due to low permeabilities in the sands, one reason most were fracture stimulated to accelerate daily rates. To this point eleven horizontal wells have been completed. The latest horizontal completion and closest to our prospect area is the Herbich Unit 2H. This well has produced 35,707 BO in only 10 months.
