TY - GEN
T1 - A sensitivity study of potential CO2 injection for enhanced gas recovery in Barnett Shale reservoirs
AU - Yu, Wei
AU - Al-Shalabi, Emad W.
AU - Sepehrnoori, Kamy
PY - 2014
Y1 - 2014
N2 - Shale gas production has been gaining worldwide attention over the past several years. This is due to the economic gas reserves using two current advanced technologies that are horizontal drilling and multistage hydraulic fracturing. Shale has a high total organic content (TOC) that may adsorb significant amount of natural gas. In addition, laboratory and theoretical calculations indicate that organic-rich shales adsorb CO2 preferentially over CH4. Hence, the extent of organic matter in shale plays an important role in determining the feasibility of CO2 injection with potential benefit of enhanced gas recovery (EGR). The performance of CO2 injection and CH4 recovery in shale reservoirs is a complex function of several engineering parameters including fracture half-length, fracture conductivity, and fracture height, operating parameters such as injection volume and injection time, and geologic parameters including reservoir permeability, porosity, and thickness. Nevertheless, the effects of the above uncertain parameters on the process of CO2-EGR are not clearly understood and systematically studied. Therefore, it is absolutely critical to quantify uncertainties and investigate the most important influential parameters controlling this process. In this paper, we employ numerical reservoir simulation techniques to model multiple hydraulic fractures and multi-component Langmuir isotherms. Two scenarios for CO2 injection are investigated when the primary gas production decreases to the economic limit: (1) CO2 flooding in two horizontal wells, and (2) CO2 huff-n-puff in a horizontal well. A series of reservoir simulations based on Design of Experiment (DOE) are performed on the best scenario to investigate the critical parameters that control this CO 2-EGR process in the Barnett Shale. This work enables operators to plan ahead of time and optimize a tertiary shale gas production process by considering the different investigated influential parameters.
AB - Shale gas production has been gaining worldwide attention over the past several years. This is due to the economic gas reserves using two current advanced technologies that are horizontal drilling and multistage hydraulic fracturing. Shale has a high total organic content (TOC) that may adsorb significant amount of natural gas. In addition, laboratory and theoretical calculations indicate that organic-rich shales adsorb CO2 preferentially over CH4. Hence, the extent of organic matter in shale plays an important role in determining the feasibility of CO2 injection with potential benefit of enhanced gas recovery (EGR). The performance of CO2 injection and CH4 recovery in shale reservoirs is a complex function of several engineering parameters including fracture half-length, fracture conductivity, and fracture height, operating parameters such as injection volume and injection time, and geologic parameters including reservoir permeability, porosity, and thickness. Nevertheless, the effects of the above uncertain parameters on the process of CO2-EGR are not clearly understood and systematically studied. Therefore, it is absolutely critical to quantify uncertainties and investigate the most important influential parameters controlling this process. In this paper, we employ numerical reservoir simulation techniques to model multiple hydraulic fractures and multi-component Langmuir isotherms. Two scenarios for CO2 injection are investigated when the primary gas production decreases to the economic limit: (1) CO2 flooding in two horizontal wells, and (2) CO2 huff-n-puff in a horizontal well. A series of reservoir simulations based on Design of Experiment (DOE) are performed on the best scenario to investigate the critical parameters that control this CO 2-EGR process in the Barnett Shale. This work enables operators to plan ahead of time and optimize a tertiary shale gas production process by considering the different investigated influential parameters.
UR - http://www.scopus.com/inward/record.url?scp=84905749862&partnerID=8YFLogxK
U2 - 10.2118/169012-ms
DO - 10.2118/169012-ms
M3 - Conference contribution
AN - SCOPUS:84905749862
SN - 9781632663177
T3 - Society of Petroleum Engineers - SPE USA Unconventional Resources Conference 2014
SP - 610
EP - 625
BT - Society of Petroleum Engineers - SPE USA Unconventional Resources Conference 2014
T2 - SPE USA Unconventional Resources Conference 2014
Y2 - 1 April 2014 through 3 April 2014
ER -