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Title: Sensitivity and history match analysis of a carbon dioxide “huff-and-puff” injection test in a horizontal shale gas well in Tennessee

Abstract

Due to improvements in well development, shale gas production has gained importance recently, especially in the United States. To improve gas production and develop a better understanding of shale reservoirs, researchers are conducting field tests to monitor CO2 storage and enhanced gas recovery. Reservoir simulations can then utilize these field results for sensitivity studies, uncertainty analysis, history matching, gas production forecasts, and CO2 storage capacity estimations. One such field test was performed for the Chattanooga Shale formation in Morgan County, Tennessee. Approximately 463 tonnes (510 tons) of CO2 was successfully injected into a hydraulically fractured horizontal well over a thirteen-day period in March 2014. The injection test was achieved in four steps: pre-injection, injection, soaking, and flowback. In this paper, those steps were modeled with a reservoir simulator to match the historic production and injection rates with gas component compositions and forecast the production for five years. The reservoir fluid was modeled as a multi-component gas, including CH4, C2H6, C3H8, N2, and CO2. Langmuir constants, reservoir pressure, and fracture network volume were adjusted to match simulation results with observed production rates and gas composition. Results showed that, under the same reservoir conditions, each gas component behaves differently by way ofmore » compositional changes in production. CH4 behaves like N2, while CO2 behaves like heavier hydrocarbons such as C2H6 and C3H8. CO2 plume results showed that, after injection, the produced CO2 is mostly derived from fractured limestone (i.e., Fort Payne Formation) because the injected CO2 is not adsorbed in limestone but rather by shale formations.« less

Authors:
 [1];  [1];  [1];  [1];  [1]
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  1. Virginia Polytechnic Inst. and State Univ. (Virginia Tech), Blacksburg, VA (United States). Virginia Center for Coal, Energy Research Center
Publication Date:
Research Org.:
Virginia Polytechnic Inst. and State Univ. (Virginia Tech), Blacksburg, VA (United States)
Sponsoring Org.:
USDOE Office of Fossil Energy (FE)
OSTI Identifier:
1799732
Alternate Identifier(s):
OSTI ID: 1604520
Grant/Contract Number:  
FE0006827
Resource Type:
Accepted Manuscript
Journal Name:
Journal of Natural Gas Science and Engineering
Additional Journal Information:
Journal Volume: 77; Journal Issue: C; Journal ID: ISSN 1875-5100
Publisher:
Elsevier
Country of Publication:
United States
Language:
English
Subject:
03 NATURAL GAS; Energy & Fuels; Engineering; Shale gas; Reservoir modeling; Chattanooga shale; History match; Horizontal well

Citation Formats

Keles, C., Tang, X., Schlosser, C., Louk, A. K., and Ripepi, N. S. Sensitivity and history match analysis of a carbon dioxide “huff-and-puff” injection test in a horizontal shale gas well in Tennessee. United States: N. p., 2020. Web. doi:10.1016/j.jngse.2020.103226.
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Keles, C., Tang, X., Schlosser, C., Louk, A. K., & Ripepi, N. S. Sensitivity and history match analysis of a carbon dioxide “huff-and-puff” injection test in a horizontal shale gas well in Tennessee. United States. https://doi.org/10.1016/j.jngse.2020.103226
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Keles, C., Tang, X., Schlosser, C., Louk, A. K., and Ripepi, N. S. Mon . "Sensitivity and history match analysis of a carbon dioxide “huff-and-puff” injection test in a horizontal shale gas well in Tennessee". United States. https://doi.org/10.1016/j.jngse.2020.103226. https://www.osti.gov/servlets/purl/1799732.
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@article{osti_1799732,
title = {Sensitivity and history match analysis of a carbon dioxide “huff-and-puff” injection test in a horizontal shale gas well in Tennessee},
author = {Keles, C. and Tang, X. and Schlosser, C. and Louk, A. K. and Ripepi, N. S.},
abstractNote = {Due to improvements in well development, shale gas production has gained importance recently, especially in the United States. To improve gas production and develop a better understanding of shale reservoirs, researchers are conducting field tests to monitor CO2 storage and enhanced gas recovery. Reservoir simulations can then utilize these field results for sensitivity studies, uncertainty analysis, history matching, gas production forecasts, and CO2 storage capacity estimations. One such field test was performed for the Chattanooga Shale formation in Morgan County, Tennessee. Approximately 463 tonnes (510 tons) of CO2 was successfully injected into a hydraulically fractured horizontal well over a thirteen-day period in March 2014. The injection test was achieved in four steps: pre-injection, injection, soaking, and flowback. In this paper, those steps were modeled with a reservoir simulator to match the historic production and injection rates with gas component compositions and forecast the production for five years. The reservoir fluid was modeled as a multi-component gas, including CH4, C2H6, C3H8, N2, and CO2. Langmuir constants, reservoir pressure, and fracture network volume were adjusted to match simulation results with observed production rates and gas composition. Results showed that, under the same reservoir conditions, each gas component behaves differently by way of compositional changes in production. CH4 behaves like N2, while CO2 behaves like heavier hydrocarbons such as C2H6 and C3H8. CO2 plume results showed that, after injection, the produced CO2 is mostly derived from fractured limestone (i.e., Fort Payne Formation) because the injected CO2 is not adsorbed in limestone but rather by shale formations.},
doi = {10.1016/j.jngse.2020.103226},
journal = {Journal of Natural Gas Science and Engineering},
number = C,
volume = 77,
place = {United States},
year = {Mon Feb 24 00:00:00 EST 2020},
month = {Mon Feb 24 00:00:00 EST 2020}
}
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Publisher's Version of Record
https://doi.org/10.1016/j.jngse.2020.103226
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