atocha project update - hm brian no.1 perforat, page-32

Tight gas formations are a common occurance The release of chemically treated water under high pressure to fracture the shale rock to release the gas will be used. Its a common occurance but one has to be careful that they don't damage the formation thus having to extract drilling fluid and mud.
A lot of tight sand formations are in Tuscaloosa sand


From research into Tuscaloosa sand

Natural fractures are important in the economical production of low-permeability (tight) gas reservoirs throughout the Tuscaloosa sands. Previous studies have shown that fractures not only enhance the overall permeability of these reservoirs, they can also create significant permeability anisotropy. Permeability anisotropy causes the drainage area around the wells to be elliptical. Elongated drainage can create more production interference and drainage overlap between adjacent wells and may leave large areas of the reservoir undrained. Evaluation of infill well potential in these reservoirs requires knowledge of the magnitude and orientation of reservoir permeability anisotropy to determine the optimal number and location of new wells and assess their impact.

Vertical wells in tight gas reservoirs are always stimulated to increase production. Hydraulic fracturing is the most common stimulation treatment. In Phase II, evaluation of fracture stimulation treatments and their impact on infill drilling was accomplished by integrated reservoir description and fracture treatment analysis in the Pecos Slope Abo tight-gas reservoir in southeastern New Mexico and the Lewis Shale in the San Juan Basin. The integration of decline curve analysis and fracture analysis in the Abo Formation provides better descriptions of reservoir properties and more accurate designs of fracture propagation models. The combined approached also improves evaluation of infill drilling potential by evaluating reservoir properties and stimulation. The Lewis Shale study summarizes relevant geological and engineering data, analyzes current stimulation procedures, and makes recommendations for improving the efficiency of hydraulic fractures.
In Phase II, new analytical and numerical procedures and tools were also developed for production and well testing analysis of tight-gas reservoirs and applied to the field studies. These procedures and tools address issues related to estimation of reservoir production/flow characteristics, determination of reservoir permeability anisotropy and well interference, delineation of the drainage volume/area, and evaluation of infill well potential.


This not to be unexpected and proper faccing will stimulate gas to flow from a tight gas reservoir have listen to some uneducated guessing to which is not good