Assigning value to stimulation in the Barnett Shale: a simultaneous analysis of 7000 plus production hystories and well completion records
- Peter P. Valko (Texas A&M U.)
- Document ID
- Society of Petroleum Engineers
- SPE Hydraulic Fracturing Technology Conference, 19-21 January, The Woodlands, Texas
- Publication Date
- Document Type
- Conference Paper
- 2009. Society of Petroleum Engineers
- 4.1.2 Separation and Treating, 5.8.3 Coal Seam Gas, 6.6.2 Environmental and Social Impact Assessments, 5.7 Reserves Evaluation, 4.2 Pipelines, Flowlines and Risers, 3.2.3 Hydraulic Fracturing Design, Implementation and Optimisation, 1.2.3 Rock properties, 2.5.2 Fracturing Materials (Fluids, Proppant), 5.1.1 Exploration, Development, Structural Geology, 1.6.6 Directional Drilling, 5.6.9 Production Forecasting, 2.4.3 Sand/Solids Control, 2 Well Completion, 4.6 Natural Gas, 3 Production and Well Operations, 4.3.4 Scale, 5.6.1 Open hole/cased hole log analysis, 5.8.1 Tight Gas, 5.8.2 Shale Gas, 1.6 Drilling Operations
- 10 in the last 30 days
- 2,684 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 8.50|
|SPE Non-Member Price:||USD 25.00|
Analysis of publicly available monthly production history and well completion records can shed light onto such long-standing questions as 1) what is the value of a stimulation (re-stimulation) treatment in the Barnett Shale, 2) how does the ultimate recovery depend on treatment type and size, 3) what factors determine the performance of a fractured well. This study starts with the month-by-moth analysis of production history for all gas wells in the Barnett Shale. Using a specialized decline-curve analysis methodology developed for shale gas wells, significant production behavior changes are automatically detected and jumps in estimated ultimate recoveries are calculated for individual wells as well, as for groups of wells. The study then continues with the textual analysis of publicly available well completion records consisting of more than 16 Gigabyte data. The obtained database is submitted to analysis relating ultimate recovery to well inclination, to location, to treatment parameters, etc.
Gas shales consist of fine-grained sedimentary rocks (shale to siltstone) containing a minimum of 0.5 weight percent total organic carbon. The amount, type, and thermal maturity of this organic matter determine the type and quantity of hydrocarbons in-place. Gas shales may contain biogenic to thermogenic methane that can be either sorbed on organic matter or occurring as free gas in the pores and naturally existing fractures (Cardott 2006). Shale gas reservoirs are self-sourcing where migration has been limited. The first large-scale, commercially successful shale gas development has been the Barnett Shale in the Fort Worth Basin.
There is a vast literature on the geophysical and petrophysical characteristics of the Barnett Shale (see for instance Bowker 2007, Gale, Reed and Holder J. 2007, Jacobi et al. 2008, Matthews, Schein and Malone 2007, Walser and Pursell 2008, Zhao, Givens and Curtis 2007.) The petroleum engineering literature is abundant on studies regarding completion techniques in the area (Lancaster et al. 1992, Coulter, Benton and Thomson 2004, Coulter et al. 2006, Ketter et al. 2006, Moore and Ramakrishnan 2006, Jennings et al. 2007, Zahid et al. 2007, Economides and Martin 2007, Miskimins, J.L. 2008, Shelley et al. 2008) and on assessing fracture geometry (Fisher et al. 2002, Fisher et al. 2004, Siebrits et al. 2000, Steinsberger 2005, Suarez-Rivera et al. 2006, Mayerhofer et al. 2006.) Reserve estimates are discussed in detail by Montgomery et al. 2005, Pollastro 2007 and Pollastro et al. 2007.
At the writing of this paper (October, 2008), according to the HPDI database there are 10,690 gas wells in the field that have been produced for at least one month. (Notice the change from 7,000 to 10,000 in the short time interval between the paper proposal was accepted and the actual paper was prepared.) Figure 1 shows the study area, its subdivision into 5 miles by 5 miles subareas, the location of city centers and the location of the wellheads.
The ability to analyze production histories of more than ten thousand gas wells concentrated both in location and time is an unprecedented opportunity but requires a specialized approach. We have developed a new decline curve model and data processing procedure for this purpose.
|File Size||1 MB||Number of Pages||19|