Injection strategies for large-scale CO2 storage sites

Michael, Karsten; Neal, Peter; Allinson, Guy; Ennis‐King, Jonathan; Hou, Wanwan; Paterson, Lincoln; Sharma, Sandeep; Aiken, Toby

doi:10.1016/j.egypro.2011.02.376

Cited by 23 publications

(11 citation statements)

References 28 publications

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“…Through these processes, dissolved CO 2 becomes the dominant of CO 2 storage in aquifers over periods of tens to hundreds of years following injection [21]. Over these timescales the CO 2 disperse [22] by dispersion and diffusion, and dissolution into the brine [20]. Continued migration and dispersion drive both free and dissolved CO 2 toward zero [23].…”

Section: Resultsmentioning

confidence: 99%

Pressure evolution in deep saline aquifers during CO<inf>2</inf> injection: A method to control high pressure buildup

Kabera

2011

2011 International Conference on Electrical and Control Engineering

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Production of saline formation water from the storage formation in sufficient amount helps to control the pressure increment during CO2 storage in saline aquifers. In this paper, we present an engineering design to control the pressure buildup during CO2 storage in deep saline aquifer and we propose that the extracted saline formation water can be processed at the industrial level in order to produce commercial salt. We investigated the effects of different aquifer properties to pressure increase. Several design options for the injection operations are investigated: Injection of CO2 without saline formation water production, Injection of CO2 with one production well and finally Injection of CO2 with two production wells (one on the left side and another on right side of the injection well). We showed that an increase in saline formation water production rate leads to pressure buildup decrement, when the production rate was tripled (from 61.42 kg/s to 184.26 kg/s); the maximum pressure decreased about 15 bars. About a half of base case temperature (890C to 450C) increased the maximum pressure to about 35 bars. The pore compressibility which is a key parameter defining the pressure response to CO2 injection has also been investigated whereby an increase in pore compressibility leads to decrease in pressure buildup. Aquifer with low thickness showed high pressure build up results. Simulations results indicated that the injection arrangement contribute significantly to the pressure development.

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Section: Resultsmentioning

confidence: 99%

Pressure evolution in deep saline aquifers during CO<inf>2</inf> injection: A method to control high pressure buildup

Kabera

2011

2011 International Conference on Electrical and Control Engineering

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“…Infrastructure for injecting carbon dioxide will need to be an order of magnitude larger than current pilot-scale CCS projects. 31 Also it should be noted that in most cases, the CO 2 injection scheme will consist of multiple wells, potentially including wells for monitoring and pressure control. 31 Therefore, postclosure monitoring will be critical to control of large ULGSS projects.…”

Section: Permit Requirementsmentioning

confidence: 99%

Planning, Designing, Operating, and Regulating a Geologic Sequestration Repository as an Underground Landfill—A Review

Brown

Poiencot

Sornberger

2011

Journal of the Air & Waste Management Association

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Geologic sequestration appears to be a technically feasible method of storing carbon dioxide in underground aquifers in order to lower greenhouse gas emissions into the atmosphere. The overall feasibility of geologic sequestration is still in question and as such, has been the focus of intense research over the past decade. Researchers have looked to the oil/gas industry and water well industry for lessons learned and technical knowledge, however, a better industry to emulate may well be the waste industry. Viewing geologic sequestration repositories as underground landfills has a great many benefits. First, there is a plethora of existing research and investigations that are directly analogous to geologic sequestration projects. Second, the regulatory framework is rather mature and can be easily adapted to serve geologic sequestration. This paper conducts an extensive literature search of the environmental, waste, and geologic sequestration literature to ascertain planning, design, and operational methodologies, lessons learned, and concepts that are directly useful for geologic sequestration to improve the technical and regulatory framework. Lastly, the paper uses a hypothetical underground landfill geologic sequestration site (ULGSS) in Florida, USA to discuss some of the findings and implications from the literature. It is concluded that there are a number of literature findings from the waste and environmental arena that should be adapted for geologic sequestration.

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“…Therefore, CO 2 would be trapped at the injected location eventually without migration in a reservoir scale. The co-injection scheme also allows us to use open, dipping aquifer structures for CO 2 storage (Akervoll et al 2006;Georgescu et al 2006;Michael et al 2010) and provides huge storage potential in addition to that of closed dome structures .…”

Section: Introductionmentioning

confidence: 98%

In-Situ Capillary Trapping of CO2 by Co-Injection

et al. 2011

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Co-injection of water with CO 2 is an effective scheme to control initial gas saturation in porous media. A fractional flow rate of water of approximately 5-10% is sufficient to reduce initial gas saturations. After water injection following the co-injection, most of the gas injected in the porous media is trapped by capillarity with a low fractional volume of migrating gas. In this study, we first derive an analytical model to predict the gas saturation levels for co-injection with water. The initial gas saturation is controlled by the fractional flow ratio in the co-injection process. Next, we experimentally investigate the effect of initial gas saturation on residual gas saturation at capillary trapping by co-injecting gas and water followed by pure water injection, using a water and nitrogen system at room temperature. Depending on relative permeability, initial gas saturation is reduced by co-injection of water. If the initial saturation in the Berea sandstone core is controlled at 20-40%, most of the gas is trapped by capillarity, and less than 20% of the gas with respect to the injected gas volume is migrated by water injection. In the packed bed of Toyoura standard sand, the initial gas saturation is approximately 20% for a wide range of gas with a fractional flow rate from 0.50 to 0.95. The residual gas saturation for these conditions is approximately 15%. Less than approximately 25% of the gas migrates by water injection. The amount of water required for co-injection systems is estimated on the basis of the analytical model and experimental results.

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Injection strategies for large-scale CO2 storage sites

Cited by 23 publications

References 28 publications

Pressure evolution in deep saline aquifers during CO<inf>2</inf> injection: A method to control high pressure buildup

Pressure evolution in deep saline aquifers during CO<inf>2</inf> injection: A method to control high pressure buildup

Planning, Designing, Operating, and Regulating a Geologic Sequestration Repository as an Underground Landfill—A Review

In-Situ Capillary Trapping of CO2 by Co-Injection

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