Identifying and quantifying natural CO2 sequestration processes over geological timescales: The Jackson Dome CO2 Deposit, USA

Zhou, Zheng; Ballentine, C. J.; Schoell, Martin; Stevens, Scott H.

doi:10.1016/j.gca.2012.02.028

Cited by 63 publications

(51 citation statements)

References 54 publications

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“…Dissolution is the dominant (≥75%) mechanism in most fields. In this respect, the findings from the Turkish geothermal fields appear to be in agreement with those from mid-US based gas fields that dissolution is the major control in CO 2 removal (Gilfillan et al, 2009;Zhou et al, 2012). However, within the limits of uncertainty imposed by a restricted number of samples, calcite precipitation seems to be the sole mechanism of CO 2 fixation at the reservoir temperature (232 • C) in one of the geothermal fields in Turkey (Germencik).…”

Section: Discussionsupporting

confidence: 76%

“…For example, CO 2 / 3 He ratios and ı 13 C values of samples from several gas fields in the USA, Europe and China have revealed that CO 2 dissolution in groundwater is the major trapping mechanism in many natural gas fields, although a minor proportion of the CO 2 is held as carbonate precipitation (mineral trapping) in reservoirs dominated by sandstones. (Gilfillan et al, 2009;Sherwood Lollar and Ballentine, 2009;Zhou et al, 2012). In another study, Dubacq et al (2012) suggested a synchronous groundwater degassing and CO 2 dissolution model for the gas field of Bravo Dome (New Mexico) where -as argued by Gilfillan et al (2009) -calcite precipitation comprises a minor (<18% of the total) sink for CO 2 .…”

Section: Introductionmentioning

confidence: 97%

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Turkish geothermal fields as natural analogues of CO 2 storage sites: Gas geochemistry and implications for CO 2 trapping mechanisms

Güleç

Hilton

2016

Geothermics

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Section: Discussionsupporting

confidence: 76%

Section: Introductionmentioning

confidence: 97%

Turkish geothermal fields as natural analogues of CO 2 storage sites: Gas geochemistry and implications for CO 2 trapping mechanisms

Güleç

Hilton

2016

Geothermics

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“…Additionally storage of anthropogenic CO 2 in geological structures as part of national CCS (Carbon Capture and Storage) strategies has further stimulated much recent interest in supercritical CO 2 -water systems (Kharaka et al, 2006;Bickle et al, 2007;Cole et al, 2010). With this focus noble gases have been used extensively to understand the processes controlling CO 2 behaviour in the subsurface (Gilfillan et al, 2008(Gilfillan et al, , 2009Dubacq et al, 2012;Zhou et al, 2012;Kampman et al, 2013) and they offer the potential to trace in-reservoir processes and subsurface leakage from engineered systems (Nimz and Hudson, 2005;Mackintosh and Ballentine, 2012).…”

Section: Sherwood-lollar Andmentioning

confidence: 99%

Determining noble gas partitioning within a CO2–H2O system at elevated temperatures and pressures

Warr

Rochelle

Masters

et al. 2015

Geochimica et Cosmochimica Acta

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Quantifying the distribution of noble gases between phases is essential for using these inert trace gases to track the processes controlling multi-phase subsurface systems. Here we present experimental data that defines noble gas partitioning for two phase CO 2 -water systems. These are at the pressure and temperature range relevant for engineered systems used for anthropogenic carbon capture and geological storage (CCS) technologies, and CO 2 -rich natural gas reservoirs (CO 2 density range 169-656 kg/m 3 at 323-377 K and 89-134 bar). The new partitioning data are compared to predictions of noble gas partitioning determined in low-pressure, pure noble gas-water systems for all noble gases except neon and radon. At low CO 2 density there was no difference between measured noble gas partitioning and that predicted in pure noble gas-water systems. At high CO 2 density, however, partition coefficients express significant deviation from pure noble gas-water systems. At 656 kg/m 3 , these deviations are À35%, 74%, 113% and 319% for helium, argon, krypton and xenon, respectively. A second order polynomial fit to the data for each noble gas describes the deviation from the pure noble gas-water system as a function of CO 2 density. We argue that the difference between pure noble gas-water systems and the high density CO 2 -water system is due to an enhanced degree of molecular interactions occurring within the dense CO 2 phase due to the combined effect of inductive and dispersive forces acting on the noble gases. As the magnitude of these forces are related to the size and polarisability of each noble gas, xenon followed by krypton and argon become significantly more soluble within dense CO 2 . In the case of helium repulsive forces dominate and so it becomes less soluble as a function of CO 2 density.

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“…Noble gases (He, Ne, Ar, Kr and Xe) exist in trace amounts in geological environments and they can be used as tracers within natural CO 2 reservoirs (Gilfillan et al, 2008;Gilfillan et al, 2009;Zhou et al, 2012;Sathaye et al, 2014) and for CO 2 used in EOR projects (Nimz and Hudson, 2005;Györe et al, 2015;Györe et al, 2017). As such, small amounts of noble gas blends can also be intentionally added to the CO 2 being injected for storage or be measured in the captured CO 2 stream and used as tracers to monitor CO 2 movement (Hovorka et al, 2013;Flude et al, 2016;Flude et al, 2017).…”

Section: Introductionmentioning

confidence: 99%

Experimental determination of noble gases and SF6, as tracers of CO2 flow through porous sandstone

et al. 2018

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A B S T R A C TIn order to label the CO 2 injected underground for geological storage and allow it to be differentiated from natural sources, a panoply of additive chemical tracers have been proposed. Yet, the transport of these tracers relative to CO 2 in pore space is currently poorly constrained. This leads to uncertainty as to whether tracers will act as an early warning of CO 2 arrival, or be preferentially retained in the pore space making them ineffective. Here, we present the factors affecting transport of noble gases and SF 6 relative to CO 2 in a porous rock. Using a porous sandstone core, each of the tracers were loaded into a sample loop and injected as discrete gas pulses into a CO 2 carrier stream at five different experiment pressures (10-50 kPag upstream to ambient pressure downstream). Tracer arrival profiles were measured using a quadrupole mass spectrometer. Significantly, our results show that peak arrival times of helium were slower than the other noble gases at each pressure gradient. The differences in peak arrival times between helium and other noble gases increased as the pressure gradient along the system decreased and the curve profiles for each noble gas differ significantly. The heavier noble gases (Kr and Xe) along with SF 6 show an earlier arrival time and a wider curve profile compared to He and Ne curves through the CO 2 carrier gas stream. This shows that Kr and Xe could be substituted for SF 6 , a potent greenhouse gas, in tracer applications. For comparison, CO 2 pulses were passed through a N 2 carrier gas resulting in significantly slower peak arrival times compared to those of noble gases and SF 6 . Hence, all investigated tracers when co-injected with CO 2 could potentially act as early warning tracers of CO 2 arrival, though we find that Kr, Xe and SF 6 will provide the most robust advance warning. Analysis of our experimental results shows that they cannot be explained by a simple one dimensional flow model through a porous medium. We outline a conceptual model that incorporates different preferential flow paths depending on flow velocities of individual gas streams. This model can explain the observed dataset and shows that the flow of noble gases and SF 6 tracers is influenced by pore-scale heterogeneity.

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Identifying and quantifying natural CO2 sequestration processes over geological timescales: The Jackson Dome CO2 Deposit, USA

Cited by 63 publications

References 54 publications

Turkish geothermal fields as natural analogues of CO 2 storage sites: Gas geochemistry and implications for CO 2 trapping mechanisms

Turkish geothermal fields as natural analogues of CO 2 storage sites: Gas geochemistry and implications for CO 2 trapping mechanisms

Determining noble gas partitioning within a CO2–H2O system at elevated temperatures and pressures

Experimental determination of noble gases and SF6, as tracers of CO2 flow through porous sandstone

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