Petrophysical and Mineralogical Research on the Influence of CO<sub>2</sub>Injection on Mesozoic Reservoir and Caprocks from the Polish Lowlands

Tarkowski, Radosław; Wdowin, Magdalena

doi:10.2516/ogst/2011005

Cited by 25 publications

(13 citation statements)

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“…Other studies of CO 2 storage cap-rock or reservoir rock cores have characterised changes in accessible porosity or more often permeability before and after pure CO 2 and water or brine reaction by various techniques and over different pore size ranges. A study on two Polish cap-rocks and six reservoir rocks showed that porosity decreased in both cap-rocks (in agreement with our results) and five of the six measured reservoir rock cores after reaction with CO 2 -brine (Tarkowski and Wdowin, 2011). In addition they reported that the N 2 permeability of the cap-rocks showed no change before and after reaction at < 0.01 MD, but decreased in three reservoir rocks and increased in three reservoir rocks.…”

Section: Accepted Manuscriptsupporting

confidence: 91%

Impure CO2 reaction of feldspar, clay, and organic matter rich cap-rocks: Decreases in the fraction of accessible mesopores measured by SANS

Pearce

Dawson

Blach

et al. 2018

International Journal of Coal Geology

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During CO 2 geological storage, low porosity and permeability cap-rock can act as a structural trap, preventing CO 2 vertical migration to overlying fresh water aquifers or the surface. Clay and organic matter rich shales, fine-grained sandstones and mudstones often act as cap-rocks and may contain substantial sub-micron porosity. CO 2 -brine-rock interactions can open or close pore throats through dissolution, precipitation or migration of clay fines or grains. This could affect CO 2 migration if the porosity is accessible, with unchanging or decreasing accessible porosity favourable for trapping and integrity. Two cap-rock core samples, a clay and organic-rich mudstone and a more organic-lean feldspar-rich fine grained sandstone, from a well drilled for a CO 2 storage feasibility study in Australia were experimentally reacted with impure CO 2 (+SO 2 ,O 2 ) and low salinity brine at reservoir conditions. Mercury injection capillary pressure indicated that the majority of pores in both cores had pore throat radii ~ 5 -150 nm with porosities of 5.5 -8.4%. After reaction with impure CO 2brine the measured pore throats decreased in the clay-rich mudstone core. Dissolution and precipitation of carbonate and silicate minerals were observed during impure CO 2 reaction of both cores via changes in water chemistry. Scanning electron microscopy identified macroporosity in clays, mica and amorphous silica cements. After impure CO 2 -brine reaction, precipitation of barite, Fe-oxides, clays and gypsum was observed. Ion leaching from Fe-rich chlorite was also apparent, with clay structural collapse, and fines migration. Small-angle neutron scattering measured the fraction of total and non-accessible pores (~ 10-150 nm radii pores) before and after reaction. The fraction of pores that was accessible in both virgin cap-rocks had a decreasing trend to smaller pore size. The clay-rich cap-rock had a higher fraction of accessible pores (~0.9) at the smallest SANS measured pore size, than the feldspar rich fine-grained sandstone (~0.75). Both core samples showed a decrease in SANS accessible pores after impure CO 2 -water reaction at CO 2 storage conditions. The clay-rich cap-rock showed a more pronounced decrease. After impure CO 2 -brine reaction the fraction of accessible pores at the smallest pore size was ~0.85 in the clay-rich cap-rock ACCEPTED MANUSCRIPT A C C E P T E D M A N U S C R I P Tand ~0.75 in the feldspar-rich fine-grained sandstone. Reactions during impure CO 2 -brine-rock reaction have the potential to close cap-rock pores, which is favourable for CO 2 storage integrity.

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Section: Accepted Manuscriptsupporting

confidence: 91%

Impure CO2 reaction of feldspar, clay, and organic matter rich cap-rocks: Decreases in the fraction of accessible mesopores measured by SANS

Pearce

Dawson

Blach

et al. 2018

International Journal of Coal Geology

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“…was based on other systems described by [15,20,26,28]. In general terms, two cylinders of commercial CO2 of 99.8% purity were connected via 5 mm stainless steel tubes to (i) the chamber of 3 dm 3 where the samples were placed and (ii) to a piston pump also connected to the chamber.…”

Section: Experimental Setup (Sample Preparation and Sc Co2 Injection)mentioning

confidence: 99%

Qualitative and Quantitative Changes of Carbonate Rocks Exposed to SC CO2 (Basque-Cantabrian Basin, Northern Spain)

Berrezueta

Kovács²,

Luquot

2017

Applied Sciences

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Abstract:This study aims at the qualitative and quantitative determination of porosity, mineralogical and textural changes in carbonate rock samples after injection of (i) supercritical CO 2 -rich brine and (ii) dry supercritical CO 2 , under similar experimental conditions (P ≈ 75 bar, T ≈ 35 • C, 970 h exposure time and no CO 2 flow). The studied rocks were sampled in the western Basque-Cantabrian Basin, North Spain, and consist of vuggy carbonates ("Carniolas") of the Puerto de la Palombera formation (Hettangian). Mineralogical and pore space characterization is completed using optical microscopy, scanning electron microscopy and optical image analysis. In addition, X-ray fluorescence analyses are performed to refine the mineralogical information and to obtain whole rock geochemical data and the brine composition is analysed before and after the experiment. Mineralogical and chemical results indicate that the carbonate rocks exposed to supercritical CO 2 in dry conditions do not suffer significant changes. However, the injection of supercritical CO 2 -rich brine induces chemical and physical changes in the rock due to the high reactivity of calcite at the low pH conditions produced by the acidified brine. Numerical modelling validates the experimental observations. These results can be used to characterize the behaviour of carbonate rocks under conditions similar to the vicinity of a CO 2 injection well. The results should be considered only at the scale of the studied samples and not at reservoir scale.

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“…In addition, CO 2 injection can be used to enhance oil recovery if the reservoir is in depletion stages. In recent years, CO 2 storage in depleted hydrocarbon fields has been extensively studied including simulation of CO 2 migration, geochemical modeling, longterm storage integrity, and risk assessment (e.g., Bachu, 2000;Oldenburg et al, 2001;Li et al, 2006;Mito et al, 2008;Tarkowski and Wdowin, 2011). Generally, the feasibility of sequestration in depleted oil and gas fields depends on the storage capacity of the reservoirs.…”

Section: Introductionmentioning

confidence: 99%

Reservoir stratigraphic heterogeneity within the Lower Cretaceous Muddy Sandstone in the Powder River Basin, northeast Wyoming, U.S.A.: Implications for carbon dioxide sequestration

Fan

2014

Rocky Mountain Geology

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The Muddy Sandstone in the Powder River Basin (PRB), northeast Wyoming, is a promising reservoir for CO 2 sequestration because: (1) existing wells for hydrocarbon production can be used for CO 2 injection when a field is depleted; and (2) data are available to assess the ability and capacity to trap CO 2 . Here, I provide new data and compile published results to: (1) characterize four oil and gas fields (the Amos Draw, Kitty, Hilight, and Sand Dunes fields) in the PRB with respect to lithofacies, sedimentary environment, sandstone composition, sand-body geometry, and porosity and permeability; and (2) assess the controls on reservoir heterogeneity and the CO 2 sequestration potential.Five lithofacies are recognized based on core description and log responses. They are interpreted as offshore, lower-middle wave-dominated shoreface, weathering zone, fluvial incised-valley, and tideinfluenced estuarine depositional environments. The Muddy Sandstone contains predominantly quartz, with total quartz higher than 70 percent of the total framework grains. The percentage of feldspar is generally less than 5 percent, except for the Rozet Member in the Amos Draw Field, which is up to 22 percent. Sandstone petrographic examination also shows that the Muddy Sandstone can be divided into four groups based on the relative abundance of pore space, carbonate cement, and matrix. Sandstone with high porosity up to 23 percent is found in the shoreface lithofacies in the Amos Draw and Hilight fields and is also found in the estuarine lithofacies in the Kitty Field. The incised-valley lithofacies is of particularly low porosity due to high matrix content and carbonate cementation. The measured porosity in the sandstone varies between 1 percent and 23 percent, and the permeability is generally less than 10 millidarcys (mD). The variation of porosity is consistent with the observation in thin sections. XRD results show that the pore-filling clay minerals include kaolinite, chlorite, illite, and smectite. Core and well log correlation show that sandstone formed in lower-middle shoreface environments is laterally extensive and of uniform thickness, whereas sandstone of fluvial and estuarine origins is more variable in lateral extent and thickness. Based on examination of lithofacies, sandstone geometry, and thin section petrography, I suggest that the best reservoir interval for CO 2 sequestration in the Amos Draw Field is the lower Rozet Member, in the Sand Dunes and Hilight fields is the Springen Ranch Member, and in the Kitty Field is the Ute Member. Variables examined in this study provide important inputs for calculating CO 2 capacity potential and predicting chemical reactivity after CO 2 injection.Reservoir quality of the Muddy Sandstone is highly heterogeneous, and the complexity may be attributed to a combination of depositional environment, history of relative sea-level change during deposition, and type and extent of diagenetic alteration. The Muddy Sandstone, along with the overlying Mowry Shale, represents one third-order de...

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Petrophysical and Mineralogical Research on the Influence of CO₂Injection on Mesozoic Reservoir and Caprocks from the Polish Lowlands

Cited by 25 publications

References 22 publications

Impure CO2 reaction of feldspar, clay, and organic matter rich cap-rocks: Decreases in the fraction of accessible mesopores measured by SANS

Impure CO2 reaction of feldspar, clay, and organic matter rich cap-rocks: Decreases in the fraction of accessible mesopores measured by SANS

Qualitative and Quantitative Changes of Carbonate Rocks Exposed to SC CO2 (Basque-Cantabrian Basin, Northern Spain)

Reservoir stratigraphic heterogeneity within the Lower Cretaceous Muddy Sandstone in the Powder River Basin, northeast Wyoming, U.S.A.: Implications for carbon dioxide sequestration

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Petrophysical and Mineralogical Research on the Influence of CO2Injection on Mesozoic Reservoir and Caprocks from the Polish Lowlands

Cited by 25 publications

References 22 publications

Impure CO2 reaction of feldspar, clay, and organic matter rich cap-rocks: Decreases in the fraction of accessible mesopores measured by SANS

Impure CO2 reaction of feldspar, clay, and organic matter rich cap-rocks: Decreases in the fraction of accessible mesopores measured by SANS

Qualitative and Quantitative Changes of Carbonate Rocks Exposed to SC CO2 (Basque-Cantabrian Basin, Northern Spain)

Reservoir stratigraphic heterogeneity within the Lower Cretaceous Muddy Sandstone in the Powder River Basin, northeast Wyoming, U.S.A.: Implications for carbon dioxide sequestration

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Petrophysical and Mineralogical Research on the Influence of CO₂Injection on Mesozoic Reservoir and Caprocks from the Polish Lowlands