Evaluating Barnett Shale Production Performance Using an Integrated Approach

Abstract

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThis paper presents the results of using a shale-specific, finitedifference reservoir simulation model to history match and forecast production data from the Barnett Shale reservoir. The paper will illustrate the many uses of the model for vertical and horizontal wells including determining gas in place, recovery factors, optimal well spacing, drainage areas and drainage shapes, optimal fracture half-lengths and conductivities, infill evaluations, horizontal well modeling and optimal number of stimulation treatments, analysis of microseismic data, and compression evaluations. The model was developed in the early 1990s to incorporate all of the production mechanisms inherent in shales including matrix gas porosity, gas desorption isotherm, single-or two-phase flow of gas and water in the natural fractures, layers, complex hydraulic fractures, and variable flowing bottomhole pressures. The paper will discuss the methodology to incorporate all field data into the simulator including core, logs, well test, completion, stimulation, microseismic, and production data. Examples will be given using public datasets. We also show production comparisons between vertical and horizontal wells since this is of topical interest in the play's development history. Furthermore, we discuss the various types of data to collect, their importance to proper stimulation design, and the integration methodology to evaluate and complete shale reservoirs.

Geological models of gas in place of the Longmaxi shale in Southeast Chongqing, South China

“…1; Hu et al, 2014). The water saturation in shale from productive wells in North America mainly ranges between 12% and 35% (Frantz et al, 2005;Cusack et al, 2010;Mullen, 2010;Hammes et al, 2011;Jarvie, 2012). According to the data of Liu and Wang (2013), the water saturation of the Longmaxi shale in the Southern Sichuan Basin is between 20% and 45% with an average value of approximately 30%.…”

Modeling free gas content of the Lower Paleozoic shales in the Weiyuan area of the Sichuan Basin, China

“…In this paper, the water saturation data of North American gas shales are cited since there is no water saturation data reported from the Weiyuan area so far. The data are presented as follows: Barnett, 25e35% (Frantz et al, 2005); Eagle Ford, 7e31% (Cusack et al, 2010;Mullen, 2010;Stoneburner, 2009); Haynesville, 15e35% (Stoneburner, 2009); Fayetteville, 25e50% (Bresch and Carpenter, 2009); and Marcellus, 12e35% (Jarvie, 2012 relationship between the water saturations and thermal maturities, with a main range between 10% and 30%. Among these shales, the Marcellus shale has the highest maturity, with a Ro mainly in the range of 1.5e3.5% (Zagorski et al, 2011), which is generally comparable with the maturity level of Lower Paleozoic shales in the Weiyuan area.…”

Unlocking the Shale Mystery: How Lateral Measurements and Well Placement Impact Completions and Resultant Production

“…Completions can be customized based upon LWD data to better stimulate the rock being targeted. 10. LWD measurements can be used to enhance production and resultant economics.…”

“…In shale plays, operators log and core offset vertical/pilot wells to characterize the reservoir and identify higher quality zones within the reservoir to target for production (Frantz et al, 2005). Based on this characterization, operators plan and geometrically drill horizontal wells near these data-rich pilot/offset vertical wells.…”