An engineering-economic model of pipeline transport of CO2 with application to carbon capture and storage

McCoy, Sean; Rubin, Edward S.

doi:10.1016/s1750-5836(07)00119-3

Cited by 313 publications

(223 citation statements)

References 14 publications

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“…If the cost of storage varies on the same scale as the cost of transport reported in literature, which our analysis supports, the optimal transport configuration must take into account variations in storage capacity (Gresham et al, 2010;McCoy and Rubin, 2008;Middleton and Bielicki, 2009). Without differentiating the cost at the end of the transport stage, the transport optimization algorithm will not map cost-efficient or possibly even practical routes for transporting CO 2 from sources to sinks.…”

Section: Discussionmentioning

confidence: 67%

“…To date, studies using transport modeling have done the best job integrating the cost of transportation and storage. Middleton andBielicki(2009), McCoy andRubin (2008), and Wildenborg et al (2004) among others have developed transport optimization algorithms that can take into account geologic and economic differences between storage sites. The disclosure of costs in these studies, however, is generally in the form of summary statistics (e.g.…”

Section: Discussionmentioning

confidence: 99%

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The impact of geologic variability on capacity and cost estimates for storing CO2 in deep-saline aquifers

et al. 2012

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While numerous studies find that deep-saline sandstone aquifers in the United States could store many decades worth of the nation's current annual CO 2 emissions, the likely cost of this storage (i.e. the cost of storage only and not capture and transport costs) has been harder to constrain. We use publicly available data of key reservoir properties to produce geo-referenced rasters of estimated storage capacity and cost for regions within 15 deep-saline sandstone aquifers in the United States. The rasters reveal the reservoir quality of these aquifers to be so variable that the cost estimates for storage span three orders of magnitude and average > $100/tonne CO 2 . However, when the cost and corresponding capacity estimates in the rasters are assembled into a marginal abatement cost curve (MACC), we find that~75% of the estimated storage capacity could be available for b $2/tonne. Furthermore,~80% of the total estimated storage capacity in the rasters is concentrated within just two of the aquifers-the Frio Formation along the Texas Gulf Coast, and the Mt. Simon Formation in the Michigan Basin, which together make up only~20% of the areas analyzed. While our assessment is not comprehensive, the results suggest there should be an abundance of low-cost storage for CO 2 in deep-saline aquifers, but a majority of this storage is likely to be concentrated within specific regions of a smaller number of these aquifers.

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Section: Discussionmentioning

confidence: 67%

Section: Discussionmentioning

confidence: 99%

The impact of geologic variability on capacity and cost estimates for storing CO2 in deep-saline aquifers

et al. 2012

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“…In large-scale pipeline transport, CO2 is mostly in a liquid or supercritical phase [15,16]. Therefore, it should be compressed to a pressure higher than the critical pressure of 7.38 MPa to change the phase to a liquid or supercritical state.…”

Section: Design Of Pipeline Transportmentioning

confidence: 99%

“…Therefore, it should be compressed to a pressure higher than the critical pressure of 7.38 MPa to change the phase to a liquid or supercritical state. In this study, the minimum pressure in the pipeline was set not to the critical pressure but to 8.6 MPa to avoid abrupt changes in the compressibility of CO2 [10,15]. The maximum pressure was set to 15 MPa to avoid exceeding the maximum allowable operating pressure of ASME-ANSI 900# flanges [15].…”

Section: Design Of Pipeline Transportmentioning

confidence: 99%

Estimation of CO2 Transport Costs in South Korea Using a Techno-Economic Model

Kang¹,

Seo

Chang

et al. 2015

Energies

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Abstract:In this study, a techno-economic model was used to calculate the costs of CO2 transport and specify the major equipment required for transport in order to demonstrate and implement CO2 sequestration in the offshore sediments of South Korea. First, three different carbon capture and storage demonstration scenarios were set up involving the use of three CO2 capture plants and one offshore storage site. Each transport scenario considered both the pipeline transport and ship transport options. The temperature and pressure conditions of CO2 in each transport stage were determined from engineering and economic viewpoints, and the corresponding specifications and equipment costs were calculated. The transport costs for a 1 MtCO2/year transport rate were estimated to be US$33/tCO2 and US$28/tCO2 for a pipeline transport of ~530 km and ship transport of ~724 km, respectively. Through the economies of scale effect, the pipeline and ship transport costs for a transport rate of 3 MtCO2/year were reduced to approximately US$21/tCO2 and US$23/tCO2, respectively. A CO2 hub terminal did not significantly reduce the cost because of the short distance from the hub to the storage site and the small number of captured sources. OPEN ACCESSEnergies 2015, 8 2177

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“…From the power plant, the CO 2 is then transported to the EOR project via pipeline. For pipeline transport over short distances (less than 100 km), we assume that no additional energy from what is used at the power plant to compress the CO 2 (and which is included in the efficiency of the power plant) is required for pumping (23). For longer pipeline transport (1000 km), 6.5 kWh of electricity are needed per metric ton of CO 2 transported for pumping (1).…”

Section: Life Cycle Emissions Of Fuels Used Within the Systemmentioning

confidence: 99%

Life Cycle Inventory of CO₂ in an Enhanced Oil Recovery System

Jaramillo

Griffin

McCoy

2009

Environ. Sci. Technol.

135

147

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Enhanced oil recovery (EOR) has been identified as a method of sequestering CO 2 recovered from power plants. In CO 2 -flood EOR, CO 2 is injected into an oil reservoir to reduce oil viscosity, reduce interfacial tension, and cause oil swelling which improves oil recovery. Previous studies suggest that substantial amounts of CO 2 from power plants could be sequestered in EOR projects, thus reducing the amount of CO 2 emitted into the atmosphere. This claim, however, ignores the fact that oil, a carbon rich fuel, is produced and 93% of the carbon in petroleum is refined into combustible products ultimately emitted into the atmosphere. In this study we analyze the net life cycle CO 2 emissions in an EOR system. This study assesses the overall life cycle emissions associated with sequestration via CO 2 -flood EOR under a number of different scenarios and explores the impact of various methods for allocating CO 2 system emissions and the benefits of sequestration.

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An engineering-economic model of pipeline transport of CO2 with application to carbon capture and storage

Cited by 313 publications

References 14 publications

The impact of geologic variability on capacity and cost estimates for storing CO2 in deep-saline aquifers

The impact of geologic variability on capacity and cost estimates for storing CO2 in deep-saline aquifers

Estimation of CO2 Transport Costs in South Korea Using a Techno-Economic Model

Life Cycle Inventory of CO₂ in an Enhanced Oil Recovery System

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An engineering-economic model of pipeline transport of CO2 with application to carbon capture and storage

Cited by 313 publications

References 14 publications

The impact of geologic variability on capacity and cost estimates for storing CO2 in deep-saline aquifers

The impact of geologic variability on capacity and cost estimates for storing CO2 in deep-saline aquifers

Estimation of CO2 Transport Costs in South Korea Using a Techno-Economic Model

Life Cycle Inventory of CO2 in an Enhanced Oil Recovery System

Contact Info

Product

Resources

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Life Cycle Inventory of CO₂ in an Enhanced Oil Recovery System