The Peterhead-goldeneye Gas Post-combustion CCS Project

Spence, Bill T.; Horan, Denise; Tucker, Owain

doi:10.1016/j.egypro.2014.11.657

Cited by 24 publications

(7 citation statements)

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“…§ 45Q) provided a tax credit of $20 per ton of CO 2 sequestered permanently. To encourage CCS using existing infrastructure, a number of locations-Sleipner site in the Norwegian North Sea (1 Mt/yr, Hosa et al, 2011), Kimberlina site in the western US (0.25 Mt over 4 years, Doughty, 2010), and Goldeneye reservoir in the North Sea (10 Mt CO 2 over 10 years, Spence et al, 2014)-are either targeted for future operations or are being used as permanent CO 2 storage sites. Hosa et al (2011) provided an overview of the storage capacity, reservoir characteristics, and injection rates of 20 active CCS sites over the world.…”

Section: Introductionmentioning

confidence: 99%

Geological Carbon Sequestration by Reactive Infiltration Instability

et al. 2020

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We study carbon capture and sequestration (CCS) over time scales of 2000 years by implementing a numerical model of reactive infiltration instability caused by reactive porous flow. Our model focuses on the mineralization of CO2 dissolved in the pore water—the geological carbon sequestration phase of a CCS operation—starting 10–100 years after the injection of CO2 in the subsurface. We test the influence of three parameters: porosity, mass fraction of the Ca-rich feldspar mineral anorthite in the solid, and the chemical reaction rate, on the mode of fluid flow and efficiency of CaCO3 precipitation during geological carbon sequestration. We demonstrate that the mode of porous flow switches from propagation of a planar front at low porosities to propagation of channels at porosities exceeding 10%. The channels develop earlier for more porous aquifers. Both high anorthite mass fraction in the solid phase and high reaction rates aid greater amounts of carbonate precipitation, with the reaction rate exerting the stronger influence of the two. Our calculations indicate that an aquifer with dimensions 500 m × 2 km × 2 km can sequester over 350 Mt solid CaCO3 after 2000 years. To precipitate 50 Mt CaCO3 after 2000 years in this aquifer, we suggest selecting a target aquifer with more than 10 wt% of reactive minerals. We recommend that the aquifer porosity, abundance of reactive aluminosilicate minerals such as anorthite, and reaction rates are taken into consideration while selecting future CCS sites.

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Section: Introductionmentioning

confidence: 99%

Geological Carbon Sequestration by Reactive Infiltration Instability

et al. 2020

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“…Abandoned hydrocarbon fields are well studied and possess pre-existing infrastructure which can be repurposed for injection rather than extraction. This helps to make CO 2 injection more economically viable, as is seen in the case of the Sleipner and Goldeneye fields in the North Sea (Chadwick et al 2002;Spence et al 2014). 73% of large-scale CCS projects in operation are based on enhanced oil recovery (EOR), such as Boundary Dam CCS, Canada, Petra Nova Carbon Capture, USA and the Jilin Oil Field CO 2 -EOR project, China (Page et al 2019).…”

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confidence: 99%

Pore-scale assessment of subsurface carbon storage potential: implications for the UK Geoenergy Observatories project

Payton

Fellgett

Clark

et al. 2021

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The growing importance of subsurface carbon storage for tackling anthropogenic carbon emissions requires new ideas to improve the rate and cost of carbon capture and storage (CCS) project development and implementation. We assess sandstones from the UK Geoenergy Observatories (UKGEOS) site in Glasgow, UK and the Wilmslow Sandstone Formation (WSF) in Cumbria, UK at the pore scale to indicate suitability for further assessment as CCS reservoirs. We measure porosity, permeability and other pore geometry characteristics using digital rock physics techniques on micro computed tomographic images of core material from each site. We find the Glasgow material to be unsuitable for CCS due to very little porosity—up to 1.65%—whereas the WSF material showed connected porosity up to 26.3% and permeabilities up to 6040 mD. Our results support the presence of a percolation threshold at 10% total porosity, introducing near full connectivity. We find total porosity varies with permeability with an exponent of 3.19. This provides reason to assume near full connectivity in sedimentary samples showing porosities above this threshold without the need for expensive and time consuming analyses.Supplementary material: Information about the boreholes sampled in this study, additional well logs of both boreholes and a summary of the supporting data plotted throughout this article from literature is available at https://doi.org/10.6084/m9.figshare.c.5260074.Thematic collection: This article is part of the Geoscience for CO2 storage collection available at: https://www.lyellcollection.org/cc/geoscience-for-co2-storage

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“…Thus, CCGT-CCS plants can be deployed in response to a relatively low CO 2 price (Nogueira et al, 2014and Johnsson, Odenberger & Göransson, 2014and Gerbelová et al, 2013. Whilst novel technologies, such as molten carbonate fuel cells and calcium looping processes (Cormos & Simon, 2013), have been proposed for decarbonising CCGT power plants (Campanari et al, 2014), the vast majority of current academic literature focuses on the utilisation of post-combustion amine scrubbing as the technology of choice for this purpose (Spence, Horan &Tucker, 2014 andCeccarelli et al, 2014). In this context, an aqueous 30 wt% solution of monoethanolamine (MEA) is still considered the benchmark solvent for the majority of academic studies (Boot-Handford et al, 2014).…”

Section: Introductionmentioning

confidence: 99%

Off-design point modelling of a 420 MW CCGT power plant integrated with an amine-based post-combustion CO2 capture and compression process

Adams

Dowell

2016

Applied Energy

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The use of natural gas for power generation is becoming increasingly important in many regions in the world. Given that the combined cycle gas turbine (CCGT) power stations are lower in capital cost and carbon intensity than their coal-fired counterparts, natural gas fired power stations are considered a vital part of the transition to a low carbon economy. However, CCGTs are not themselves "low carbon" and in order to reach a carbon intensity of less than 50 kg CO2 /MWh, it will be necessary to decarbonise them via CCS, with postcombustion CCS currently regarded as being a promising technology for this application. In this study, we present a detailed model of a 420 MW triple-pressure reheat CCGT and evaluate its technical and economic performance under full and part load conditions. We evaluate the technical performance of our CCGT model by comparison to an equivalent model implemented in Thermoflow THERMOFLEX and observe agreement of power output and efficiency to within 4.1% and the temperature profile within the HRSG within 2.9%. We further integrate the CCGT with a dynamic model of an amine based CCS process, and observe a reduction in the base plant efficiency from 51.84% at full-load and 50.23% at 60% load by 8.64% points at full-load and 7.93% points at 60% load. A core conclusion of this paper is that CCGT power plants equipped with post-combustion CCS technologies are well suited to dynamic operation, as might be required in an energy system characterised by high penetrations of intermittent renewable power generation.

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The Peterhead-goldeneye Gas Post-combustion CCS Project

Cited by 24 publications

References 0 publications

Geological Carbon Sequestration by Reactive Infiltration Instability

Geological Carbon Sequestration by Reactive Infiltration Instability

Pore-scale assessment of subsurface carbon storage potential: implications for the UK Geoenergy Observatories project

Off-design point modelling of a 420 MW CCGT power plant integrated with an amine-based post-combustion CO2 capture and compression process

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