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Title: Targeted Pressure Management During CO2 Sequestration: Optimization of Well Placement and Brine Extraction

Abstract

Large-scale pressure increases resulting from carbon dioxide (CO2) injection in the subsurface can potentially impact caprock integrity, induce reactivation of critically stressed faults, and drive CO2 or brine through conductive features into shallow groundwater. Pressure management involving the extraction of native fluids from storage formations can be used to minimize pressure increases while maximizing CO2 storage. However, brine extraction requires pumping, transportation, possibly treatment, and disposal of substantial volumes of extracted brackish or saline water, all of which can be technically challenging and expensive. This paper describes a constrained differential evolution (CDE) algorithm for optimal well placement and injection/ extraction control with the goal of minimizing brine extraction while achieving predefined pressure contraints. The CDE methodology was tested for a simple optimization problem whose solution can be partially obtained with a gradient-based optimization methodology. The CDE successfully estimated the true global optimum for both extraction well location and extraction rate, needed for the test problem. A more complex example application of the developed strategy was also presented for a hypothetical CO2 storage scenario in a heterogeneous reservoir consisting of a critically stressed fault nearby an injection zone. Through the CDE optimization algorithm coupled to a numerical vertically-averaged reservoir model, wemore » successfully estimated optimal rates and locations for CO2 injection and brine extraction wells while simultaneously satisfying multiple pressure buildup constraints to avoid fault activation and caprock fracturing. The study shows that the CDE methodology is a very promising tool to solve also other optimization problems related to GCS, such as reducing ‘Area of Review’, monitoring design, reducing risk of leakage and increasing storage capacity and trapping.« less

Authors:
; ;
Publication Date:
Research Org.:
Lawrence Berkeley National Laboratory (LBNL), Berkeley, CA (United States)
Sponsoring Org.:
USDOE Office of Fossil Energy (FE)
OSTI Identifier:
1829103
Alternate Identifier(s):
OSTI ID: 1203640
Grant/Contract Number:  
AC02-05CH11231
Resource Type:
Journal Article: Published Article
Journal Name:
Energy Procedia (Online)
Additional Journal Information:
Journal Name: Energy Procedia (Online) Journal Volume: 63 Journal Issue: C; Journal ID: ISSN 1876-6102
Publisher:
Elsevier
Country of Publication:
Netherlands
Language:
English
Subject:
54 ENVIRONMENTAL SCIENCES; 58 GEOSCIENCES

Citation Formats

Cihan, Abdullah, Birkholzer, Jens, and Bianchi, Marco. Targeted Pressure Management During CO2 Sequestration: Optimization of Well Placement and Brine Extraction. Netherlands: N. p., 2014. Web. doi:10.1016/j.egypro.2014.11.564.
Cihan, Abdullah, Birkholzer, Jens, & Bianchi, Marco. Targeted Pressure Management During CO2 Sequestration: Optimization of Well Placement and Brine Extraction. Netherlands. https://doi.org/10.1016/j.egypro.2014.11.564
Cihan, Abdullah, Birkholzer, Jens, and Bianchi, Marco. 2014. "Targeted Pressure Management During CO2 Sequestration: Optimization of Well Placement and Brine Extraction". Netherlands. https://doi.org/10.1016/j.egypro.2014.11.564.
@article{osti_1829103,
title = {Targeted Pressure Management During CO2 Sequestration: Optimization of Well Placement and Brine Extraction},
author = {Cihan, Abdullah and Birkholzer, Jens and Bianchi, Marco},
abstractNote = {Large-scale pressure increases resulting from carbon dioxide (CO2) injection in the subsurface can potentially impact caprock integrity, induce reactivation of critically stressed faults, and drive CO2 or brine through conductive features into shallow groundwater. Pressure management involving the extraction of native fluids from storage formations can be used to minimize pressure increases while maximizing CO2 storage. However, brine extraction requires pumping, transportation, possibly treatment, and disposal of substantial volumes of extracted brackish or saline water, all of which can be technically challenging and expensive. This paper describes a constrained differential evolution (CDE) algorithm for optimal well placement and injection/ extraction control with the goal of minimizing brine extraction while achieving predefined pressure contraints. The CDE methodology was tested for a simple optimization problem whose solution can be partially obtained with a gradient-based optimization methodology. The CDE successfully estimated the true global optimum for both extraction well location and extraction rate, needed for the test problem. A more complex example application of the developed strategy was also presented for a hypothetical CO2 storage scenario in a heterogeneous reservoir consisting of a critically stressed fault nearby an injection zone. Through the CDE optimization algorithm coupled to a numerical vertically-averaged reservoir model, we successfully estimated optimal rates and locations for CO2 injection and brine extraction wells while simultaneously satisfying multiple pressure buildup constraints to avoid fault activation and caprock fracturing. The study shows that the CDE methodology is a very promising tool to solve also other optimization problems related to GCS, such as reducing ‘Area of Review’, monitoring design, reducing risk of leakage and increasing storage capacity and trapping.},
doi = {10.1016/j.egypro.2014.11.564},
url = {https://www.osti.gov/biblio/1829103}, journal = {Energy Procedia (Online)},
issn = {1876-6102},
number = C,
volume = 63,
place = {Netherlands},
year = {Wed Jan 01 00:00:00 EST 2014},
month = {Wed Jan 01 00:00:00 EST 2014}
}

Journal Article:
Free Publicly Available Full Text
Publisher's Version of Record at https://doi.org/10.1016/j.egypro.2014.11.564

Citation Metrics:
Cited by: 9 works
Citation information provided by
Web of Science

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Works referenced in this record:

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