New Stimulation Techniques Improve Canyon Sand Gas Production: A Case Study

New Stimulation Techniques Improve Canyon Sand Gas Production: A Case Study D.J. Pferdehirt; D.J. Pferdehirt Dowell Schlumberger Search for other works by this author on: This Site Google Scholar J.E. Brown; J.E. Brown Dowell Schlumberger Search for other works by this author on: This Site Google Scholar L.R. Rucker L.R. Rucker Dowell Schlumberger Search for other works by this author on: This Site Google Scholar Paper presented at the Permian Basin Oil and Gas Recovery Conference, Midland, Texas, March 1990. Paper Number: SPE-20133-MS https://doi.org/10.2118/20133-MS Published: March 08 1990 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Pferdehirt, D.J., Brown, J.E., and L.R. Rucker. "New Stimulation Techniques Improve Canyon Sand Gas Production: A Case Study." Paper presented at the Permian Basin Oil and Gas Recovery Conference, Midland, Texas, March 1990. doi: https://doi.org/10.2118/20133-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu toolbar search search input Search input auto suggest filter your search All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE Permian Basin Oil and Gas Recovery Conference Search Advanced Search SPE MembersAbstractIt is an established fact that the Canyon Sand Formation in the Val Verde Basin must be fracture stimulated to exploit the reservoir's potential. However, in the past, the degree of stimulation required has been a judgement call at best. Due to recent results from an industry consortium dealing with conductivity, it became obvious that many past stimulation designs were inadequate. Change in fracturing fluids, as well as proppant selection, concentration, and placement, have led to an improved design.Past treatments were insufficient in Past treatments were insufficient in fracture half-length and conductivity. These treatments have now been modified to double the fracture half-length, and to increase the conductivity six-fold. These design changes are necessary to overcome fluid damage and long-term conductivity deterioration. Computer simulated fracturing programs have been used to develop improved programs have been used to develop improved designs. When implemented in the field, these designs have proven to increase profitability through post-frac production profitability through post-frac production results.Although previously reported laboratory work has addressed the topic of in-situ fracture conductivity, these findings were not substantiated with actual production results. Therefore, a case study of twenty four wells located in Sutton County, Texas was performed to determine the actual effect of fracturing fluid type on well performance. Comparison of post-frac performance. Comparison of post-frac well production indicates that different fracturing fluids can dramatically effect a well's producibility. This case study supports the consortium's findings, that different fracturing fluid types create varying levels of permeability impairment.BackgroundLocated within the Val Verde and Midland Basins, the Canyon Sand formation has provided commercial gas production for over 30 provided commercial gas production for over 30 years. The area of this producing horizon covers over 10 counties in sout central Texas. The information presented here concentrates primarily in Sutton, Crockett, and Edwards counties.Past fracturing treatments in this area Past fracturing treatments in this area have varied greatly in both size and type. Many different fracturing fluids and proppants have been used in trying to find an proppants have been used in trying to find an ideal stimulation treatment. The volume of fluid and proppant used in these treatments often varied due to individual perceptions as to what fracture height would be obtained and what fracture length was necessary. The producing intervals within the Canyon Sand are often separated by small-to-medium shale barriers, which may or may not act as a barrier to contain fracture height. Some fracture treatments were designed to pump into each individual zone, while others attempted to fracture stimulate many zones at once, hoping to overcome the horizontal stresses of the shale intervals.The fluids used in these stimulation treatments have also varied widely, and have included gelled oils, linear gelled water, 3% gelled acid, crosslinked gelled water, and foams of either nitrogen or carbon dioxide.P. 391 Keywords: crosslinker, procedure, fracture, upstream oil & gas, fracture length, fracture height, stimulation treatment, fracturing fluid, borate fluid, well avg Subjects: Hydraulic Fracturing, Fracturing materials (fluids, proppant) This content is only available via PDF. 1990. Society of Petroleum Engineers You can access this article if you purchase or spend a download.

Topic: Hydraulic Fracturing and Reservoir Analysis
Subfield: Mechanical Engineering
Field: Engineering
Domain: Physical Sciences