Reservoir: A Better Way to Forecast Production in Unconventional Gas Reservoirs

Speaker John Lee
Regents Professor of Petroleum Engineering Harold Vance Department of Petroleum Engineering at Texas A&M University John Lee holds the L.F. Peterson Endowed Chair and is a Regents Professor of Petroleum Engineering in the Harold Vance Department of Petroleum Engineering at TexasA&MUniversity. John received B.ChE, M.S., and PhD degrees in Chemical ...

Regents Professor of Petroleum Engineering
Harold Vance Department of Petroleum Engineering at Texas A&M University


John Lee holds the L.F. Peterson Endowed Chair and is a Regents Professor of Petroleum Engineering in the Harold Vance Department of Petroleum Engineering at TexasA&MUniversity.



John received B.ChE, M.S., and PhD degrees in Chemical Engineering from the Georgia Institute of Technology. He spent 15 years with ExxonMobil, leading teams on reservoir studies, and joined the Texas A&M faculty in 1977. While at A&M, he also worked with S.A. Holditch & Associates, petroleum engineering consultants, from 1980 to 1999, specializing in reservoir engineering aspects of low permeability gas reservoirs. He served as an Academic Engineering Fellow with the U.S. Securities and Exchange Commission from October 2007 to December 2008. As an SEC Fellow, he coordinated the technical aspects of the SEC’s modernization of oil and gas reporting regulations.



He has received numerous awards from the Society of Petroleum Engineers, including the Anthony Lucas Medal, the DeGolyer Medal, and Honorary Membership. He is a member of the U.S. National Academy of Engineering and the RussianAcademy of Natural Science.


Full Description

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For many decades, a standard method of forecasting future production in conventional oil and gas reservoirs has been to use Arps production decline equations. One of the limitations of the Arps empirical model is that stabilized (boundary-dominated) flow data are required to ensure reliable forecasts. In ultra-low permeability gas reservoirs, flow may remain transient (unstabilized) for much or all the life of a well. In such cases, the Arps model is seriously limited, and engineers have created imaginative methods to adapt the model to these unconventional reservoir conditions. An approach that may be more productive is to abandon the Arps model altogether and adopt an alternative empirical approach that is better suited to long-term transient flow in wells and in reservoirs. The “stretched exponential” model is such an approach. This model, which has been found to describe many decline processes in physics, is well suited to model production decline in ultra-low permeability gas wells with both early transient and later stabilized flow. We have applied the model successfully to production data from thousands of wells in the Barnett Shale, TravisPeak tight gas, and other reservoirs. In this presentation, we will discuss the results that we have obtained to date using the stretched exponential decline model.
Organizer Kishor Pitta

When?

Thu, May. 27, 2010
11:30 a.m. - 1 p.m. US/Central

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Where?

Courtyard on St James
1885 St James Place
Houston, TX 77056

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