For many years, local industry consensus and various authors1,2,3  have concluded that with few exceptions4 , fracture-stimulation of the Morrow sand series in southeastern New Mexico is best undertaken utilizing fluids containing [at least] CO2, KCl, and methanol. Unfortunately, this conclusion originates from hearsay and limited studies that looked at only a few treatments. Difficulties with past efforts to verify and compare post-fracture well performance were centered on the inability to database naturally-occurring parameters for the majority of wells, as well as problems stemming from inaccurate and erroneous public data.

Localized successes with foams containing CO2, KCl, nitrogen, and methanol prompted a more comprehensive study of the area that attempted to address the problems associated with the evaluation of public production data.

A Graphical Information System5  was coupled with publicly available production data and internal pumping service company records6  to attempt to determine if one completion methodology was really any better than another. Production from wells treated with Binary foams over a four-year period (1996 – 1999) was compared to production from up to 19 offsets per well of interest. A set of relatively rigid criteria was set up and followed to ensure that the study was as objective as possible, given the constraints of working with public data. Although it was not possible to "normalize" the wells of interest or their offsets to account for differences in natural parameters, the large number of wells examined provided some degree of confidence in the validity of the process.

Conclusions are presented. The average first 90-day cumulative production from wells treated with Binary foam was higher than the average of wells that were stimulated with other systems. Evidence is also presented to suggest that it may be prudent to fracture-stimulate wells with high initial natural production.

You can access this article if you purchase or spend a download.