Simultaneous CO2 injection and water production to optimise aquifer storage capacity

Bergmo, Per Eirik Strand; Grimstad, Alv-Arne; Lindeberg, Erik

doi:10.1016/j.ijggc.2010.09.002

Cited by 121 publications

(74 citation statements)

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“…Instead of active pumping, water extraction wells can also be operated as passive producers (Bergmo et al, 2011) Four different brine disposal options are considered. The first option assumes that the pressure relief wells connect the storage formation with the ground surface.…”

Section: Pressure Management Via Passive Pressure Relief Wellsmentioning

confidence: 99%

“…One possible approach for management of formation pressure is to extract native fluids residing in the CO 2 storage reservoir so that additional pore space is provided (e.g., Court et al, 2011;Bergmo et al, 2011). While pressure management via brine extraction should not be considered a mandatory component for large-scale CO 2 sequestration projects, it can provide many benefits, such as increased storage capacity, reduced failure risk, simplified permitting, smaller area of review for site characterization, smaller area for monitoring, and, possibly, manipulation of the CO 2 plume.…”

Section: Introductionmentioning

confidence: 99%

“…The recent EU directive on geological storage of CO 2 (EU Directive, 2009) requires that GCS operations need to be managed in such a way that they will not impact other storage sites. It follows that there are restrictions to pressure increases (in spatial extent, magnitude, and duration), which can be an important factor limiting the amount of CO 2 that can be injected and stored.One possible approach for management of formation pressure is to extract native fluids residing in the CO 2 storage reservoir so that additional pore space is provided (e.g., Court et al, 2011;Bergmo et al, 2011). While pressure management via brine extraction should not be considered a mandatory component for large-scale CO 2 sequestration projects, it can provide many benefits, such as increased storage capacity, reduced failure risk, simplified permitting, smaller area of review for site characterization, smaller area for monitoring, and, possibly, manipulation of the CO 2 plume.…”

mentioning

confidence: 99%

“…We illustrate IDPM options and potential benefits in an idealized example case that involves a large-scale CO 2 storage operation in a saline formation with a critically stressed fault. Using a newly developed analytical solution for single-phase flow in multi-layered aquifer and aquitard systems, we test alternative brine extraction designs involving active pumping wells and (passive) pressure relief wells (e.g., Bergmo et al, 2011), as well as combinations of both. We define a maximum allowable pressure near the fault zone as the performance criterion for IDPM, and evaluate the selected extraction designs as to their ability to satisfy this criterion.…”

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confidence: 99%

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Impact-driven pressure management via targeted brine extraction—Conceptual studies of CO2 storage in saline formations

Birkhölzer

Cihan

Zhou

2012

International Journal of Greenhouse Gas Control

120

104

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Large-scale pressure buildup in response to carbon dioxide (CO 2 ) injection in the subsurface may limit the dynamic storage capacity of suitable formations, because elevated pressure can impact caprock integrity, induce reactivation of critically stressed faults, drive CO 2 and/or brine through conductive features into shallow groundwater resources, or may affect existing subsurface activities such as oil and gas production. It has been suggested that pressure management involving the extraction of native fluids from storage formations can be used to control subsurface pressure increases caused by CO 2 injection and storage, thereby limiting the possibility of unwanted effects. In this study, we introduce the concept of "impact-driven pressure management (IDPM)", which involves optimization of fluid extraction to meet local (not global) performance criteria (i.e., the goal is to limit pressure increases primarily where environmental impact is a concern). We evaluate the feasibility of IDPM for a hypothetical CO 2 storage operation in an idealized multi-formation system containing a critically stressed fault zone. Using a newly developed analytical solution, we assess alternative fluid extraction schemes and test whether a predefined performance criterion can be achieved, in this case the maximum allowable pressure near the fault zone. Alternative strategies for well placement are evaluated, comparing near-injection arrays of extraction wells with near-impact arrays. Extraction options include active extraction wells and (passive) pressure relief wells, as well as combinations of both, with and without reinjection into the subsurface. Our results suggest that strategic well placement and optimization of extraction may allow for a significant reduction in the brine extraction volumes. Additional work is required in the future to test the general concept of IDPM for more complex and realistic CO 2 storage scenarios.Page 2 IntroductionFor geologic carbon sequestration (GCS) to have a positive effect on reducing or at least stabilizing atmospheric carbon levels, the anticipated volume of CO 2 that would need to be injected in the subsurface is very large (e.g., Zhou and Birkholzer, 2011). One single coal-fired power plant alone may emit as much as 5-10 million tons of CO 2 per year. Unless storage is conducted in depleted oil or gas reservoirs, where fluids have been previously extracted as a result of production, the pore space in suitable storage formations is already filled with saline water. The CO 2 volume injected into saline formations then needs to be accommodated by expansion of reservoir pore space and compression of fluid in response to pressure buildup and, if reservoir boundaries are open, by pressure-driven migration of native brines into neighboring formations. Large and lasting pressure perturbation in the subsurface is an expected feature of GCS operations (e.g., Nicot, 2008;, and careful monitoring and management of pressure increases is generally considered of great importance to the saf...

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Section: Pressure Management Via Passive Pressure Relief Wellsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

mentioning

confidence: 99%

mentioning

confidence: 99%

See 2 more Smart Citations

Impact-driven pressure management via targeted brine extraction—Conceptual studies of CO2 storage in saline formations

Birkhölzer

Cihan

Zhou

2012

International Journal of Greenhouse Gas Control

120

104

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“…Potential impacts related to elevated formation pressure include: (1) caprock fracturing and fault reactivation, and (2) pressure-driven leakage of CO 2 and brine (Rutqvist et al, 2008). One developing technique for mitigating pressure concerns is GCS with brine extraction, whereby CO 2 is injected into a saline formation and resident brine is brought to the surface through extraction wells to direct CO 2 plume flow and to manage formation pressure (Bergmo et al, 2011;Birkholzer et al, 2012;Buscheck et al, 2012).…”

Section: Introductionmentioning

confidence: 99%

Regional evaluation of brine management for geologic carbon sequestration

Breunig

Birkhölzer

Borgia

et al. 2013

International Journal of Greenhouse Gas Control

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Large scale deployment of carbon dioxide (CO 2 ) capture and sequestration (CCS) has the potential to significantly reduce global CO 2 emissions, but this technology faces social, economic, and environmental challenges that must be managed early on. Carbon capture technology is water-, energy-, and capitalintensive and proposed geologic carbon sequestration (GCS) storage options, if conducted in pressure-constrained formations, may generate large volumes of extracted brine that require costly disposal. In this study, we evaluate brine management in three locations of the United States (US) and assess whether recovered heat, water, and minerals can turn the brine into a resource. Climate and aquifer parameters varied between the three regions and strongly affected technical feasibility. We discovered that the levelized net present value (NPV) of extracted brine can range from −$50 (a cost) to +$10 (a revenue) per ton of CO 2 injected (mt-CO 2 ) for a CO 2 point source equivalent to emissions from a 1000 MW coal-fired power plant (CFPP), compared to CCS NPV ranging from −$40 to −$70 per mt-CO 2 . Upper bound scenarios reflect assumed advancements in current treatment technologies and a favorable market and regulation landscape for brine products and disposal. A regionally appropriate management strategy may be able to treat the extracted brine as a source of revenue, energy, and water.

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Robust optimization of well location to enhance hysteretical trapping of CO₂: Assessment of various uncertainty quantification methods and utilization of mixed response surface surrogates

Babaei

Pan

Alkhatib

2015

Water Resources Research

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The paper aims to solve a robust optimization problem (optimization in presence of uncertainty) for finding the optimal locations of a number of CO 2 injection wells for geological sequestration of carbon dioxide in a saline aquifer. The parametric uncertainties are the interfacial tension between CO 2 and aquifer brine, the Land's trapping coefficient and the boundary aquifer's absolute permeability. The spatial uncertainties are due to the channelized permeability field which exhibits a binary channel-non-channel system. The objective function of the optimization is the amount of residually trapped CO 2 due to the hysteresis of the relative permeability curves. A risk-averse value derived from the cumulative density function of the distribution of the amount of trapped gas is chosen as the objective function value. In order to ensure that the uncertainties are effectively taken into account, Monte Carlo simulation and Polynomial Chaos Expansion (PCE)-based methods are used and compared with each other. For different cases of parametric and spatial uncertainties, the most accurate uncertainty quantification (UQ) method is chosen to be integrated within the optimization algorithm. While for parametric uncertainty cases of up to two uncertain variables, PCE-based methods computationally outperform Monte Carlo simulations, it is shown that for the multimodal distributions of the function of trapped gas occurring for the spatial uncertainty case, Monte Carlo simulations are more reliable than PCE-based UQ methods. For the discrete (integer) optimization problem, various mixed response surface surrogate models are tested and the robust optimization resulted in optimal CO 2 injection well locations. Key Points:The trapped CO 2 by hysteresis maximized in presence of uncertainty Parametric uncertainty dealt with by polynomial chaos expansion Monte Carlo simulation was more effective for spatial uncertainty case Correspondence to: M. Babaei, masoud.babaei@manchester.ac.uk Citation: Babaei, M., I. Pan, and A. Alkhatib (2015), Robust optimization of well location to enhance hysteretical trapping of CO 2 : Assessment of various uncertainty quantification methods and utilization of mixed response surface surrogates, Water Resour. Res., 51, 9402-9424,

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Simultaneous CO2 injection and water production to optimise aquifer storage capacity

Cited by 121 publications

References 11 publications

Impact-driven pressure management via targeted brine extraction—Conceptual studies of CO2 storage in saline formations

Impact-driven pressure management via targeted brine extraction—Conceptual studies of CO2 storage in saline formations

Regional evaluation of brine management for geologic carbon sequestration

Robust optimization of well location to enhance hysteretical trapping of CO₂: Assessment of various uncertainty quantification methods and utilization of mixed response surface surrogates

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Simultaneous CO2 injection and water production to optimise aquifer storage capacity

Cited by 121 publications

References 11 publications

Impact-driven pressure management via targeted brine extraction—Conceptual studies of CO2 storage in saline formations

Impact-driven pressure management via targeted brine extraction—Conceptual studies of CO2 storage in saline formations

Regional evaluation of brine management for geologic carbon sequestration

Robust optimization of well location to enhance hysteretical trapping of CO2: Assessment of various uncertainty quantification methods and utilization of mixed response surface surrogates

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Robust optimization of well location to enhance hysteretical trapping of CO₂: Assessment of various uncertainty quantification methods and utilization of mixed response surface surrogates