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The geochemical reactions involved in injecting fluids into reservoirs remain poorly understood, yet this information is critical to the success of carbon capture and storage (CCS) projects. Remarkably, no standard methodology exists to estimate storage capacity for CCS, largely because of the inadequacy of thermo-kinetic databases needed to model...
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... injected CO 2 does not always immediately dissolve into solution or precipitate into minerals-for at least the injection period (25 to 50 years). The majority of CO 2 may reside as a separate phase on top of the formation brine because of its lower density (Figure 3). The reactions that occur in this part of the system are also very important to investigate. ...
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The CO2CRC Otway Project, established in Victoria, Australia in 2005, is the first carbon dioxide pilot project of the southern hemisphere. The main objective of CO2CRC (Cooperative Research Centre for Greenhouse Gas Technologies) is to demonstrate that carbon capture and storage (CCS) is technically and environmentally safe. Among others, factors...
The CO2CRC (Cooperative Research Centre for Greenhouse Gas Technologies) started a pilot project for carbon dioxide storage, the CO2CRC Otway Project, in Nirranda South, Victoria, Australia in 2005. Several analyses have been conducted to demonstrate that carbon capture and storage (CCS) is technically and environmentally safe. In particular, our w...
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... One such potential project is Spectra Energy's Fort Nelson CCS project. If fully operational, this CCS project would inject up to 2 Mtons of CO 2 into the Keg River Formation, a Devonian carbonate system located in Northeast British Columbia ( Fig. 1; Crockford et al., 2010). The global relevance of such a project is bolstered by its geology, since carbonates house approximately 60% of global oil and gas reserves, making them highly prospective CO 2 storage sites (Morse and Mackenzie, 1990). ...
a b s t r a c t The dissolution kinetics of carbonate rocks sampled from the Keg River Formation in Northeast British Columbia were measured at 50 bar pCO 2 and 105 °C, in both natural and synthetic brines of 0.4 M ionic strength. Natural brines yielded reaction rates of À12.16 ± 0.11 mol cm À2 s À1 for Log R Ca , and À12.64 ± 0.05 for Log R Mg . Synthetic brine yielded faster rates of reaction than natural brines. Experi-ments performed on synthetic brines, spiked with 10 mmol of either Sr or Zn, suggest that enhanced reac-tion rates observed in synthetic brines are due to a lack of trace ion interaction with mineral surfaces. Results were interpreted within the surface complexation model framework, allowing for the discrimina-tion of reactive surface sites, most importantly the hydration of the >MgOH surface site. Dissolution rates extrapolated from experiments predict that CO 2 injected into the Keg River Formation will dissolve a very minor portion of rock in contact with affected formation waters.
... This project is located within the WCSB approximately 20 km to the southwest of Fort Nelson, British Columbia (Figure 2.1). If fully deployed, up to 2 Mtons of CO 2 , and potentially H 2 S will be injected into the subsurface annually (Crockford and Telmer, 2010). The impact that this amount of GHG reduction would have in the context of ...
... Spectra Energy® and the government of British Columbia are exploring the potential for CCS in the province's growing fossil fuel sector. Spectra Energy's Fort Nelson sour gas processing facility is the province's largest point source CO 2 emitter and this makes it an ideal location to utilize CCS technology [2]. Gas processing facilities are one of the most economical areas of industry to begin deployment of CCS due to lower capture costs than those of power plants. ...
Elsevier use only: Received date here; revised date here; accepted date here Abstract The government of British Columbia and Spectra Energy are partnering to explore the potential of CCS in British Columbia to reduce emissions from Spectra Energy's Fort Nelson gas processing facility. This work is part of a site characterization study, which aims to assess the viability of such a project in the province. Dissolution rates of Keg River carbonates immersed in Keg River brines collected in May 2009 were measured. Experimental conditions simulating injection and formation conditions were CO 2 at 50 bar and 105°C. Results are higher but within an order of magnitude of literature values at similar pressure temperature conditions with values of Log R up to -8.45 mol⋅cm -2 ⋅s -1 . Experiments showed a strong effect of rock and fluid composition on reaction kinetics. The same experimental materials and conditions but using a synthetic 0.1M NaCl brine produced elevated reaction rates, potentially due to a lack of compositional inhibition that are caused by more complex mixtures. A full reactive transport simulation using these results would help constrain the spatial extent dissolution throughout the saline formation being considered for injection.
