Flood characteristic and fluid rock interactions of a supercritical CO 2 , brine, rock system: South West Hub, Western Australia

Saeedi, Ali; Piane, Claudio Delle; Esteban, Lionel; Xie, Quan

doi:10.1016/j.ijggc.2016.09.017

Cited by 39 publications

(17 citation statements)

References 59 publications

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“…Permeability reduction has also been observed due to pore structure modification. This can be caused by blocking of flow paths due to pore-filling secondary mineral precipitation (Lu et al, 2011), fine kaolinite particle migration due to petrophysical alteration (Saeedi et al, 2016), or mechanical compaction of the framework grains (Khather et al, 2017). Dissolution rates are relatively high when the initial fluid is far away from equilibrium (Luquot et al, 2016;Tutolo et al, 2015), and the rate is proportional to the surface area of the rocks and the partial pressure of CO 2 (Lamy-Chappuis et al, 2014;Luquot et al, 2014;Wang et al, 2017).…”

Section: Introductionmentioning

confidence: 99%

Chemo‐mechanical Alterations Induced From CO₂ Injection in Carbonate‐Cemented Sandstone: An Experimental Study at 71 °C and 29 MPa

Luhmann

Rinehart

et al. 2020

JGR Solid Earth

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Carbon capture, utilization, and storage may lead to mechanical degradation of the subsurface reservoir from fluid‐rock interaction, which could lead to wellbore instability or reservoir compaction. To better understand potential relationship between mechanical degradation with various carbonate cement textures and compositions in sandstone reservoirs, six flow‐through experiments were conducted. Formation water (TDS = 5,390 mg/L) enriched with CO2 flowed through two types of Pennsylvanian Morrow B Sandstone: an ankerite‐siderite‐cemented sandstone (disseminated cement texture) and a calcite‐cemented sandstone (poikilotopic cement texture). The experiments produced little change in permeability in the ankerite‐siderite‐cemented sandstone, but permeability increased up to more than 1 order of magnitude in the calcite‐cemented sandstone. Ultrasonic measurements and cylinder‐splitting tests (also known as Brazilian tests) suggested negligible mechanical degradation of the ankerite‐siderite‐cemented sandstone. Variable changes, with significant mechanical degradation in the static moduli, were observed in the calcite‐cemented sandstone. Thus, dissolution of the disseminated ankerite‐siderite cement (0.28–0.30%) had minimal impact on modifying the flow network and the mechanical integrity of the sandstone, whereas dissolution of the poikilotopic calcite cement (0.89–1.13%, quantified with fluid chemistry and visualized with X‐ray microcomputed tomography) impacted the mechanical strength of the sandstone by disconnecting framework grains. With the high water‐to‐rock mass ratios (7.3–8.2) and number of pore volumes (147–675) employed in these experiments, potential risks are most relevant to regions near injection wells. Ultimately, the chemo‐mechanical effects induced by CO2 injection are strongly influenced by the cement texture and composition and the burial history of the reservoir rock.

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Section: Introductionmentioning

confidence: 99%

Chemo‐mechanical Alterations Induced From CO₂ Injection in Carbonate‐Cemented Sandstone: An Experimental Study at 71 °C and 29 MPa

Luhmann

Rinehart

et al. 2020

JGR Solid Earth

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“…The T2 spectrum indicate that the pore size distribution changes after the injection of CO2, however, there is no significant change in the total pore volume, which represents there are mutual transformations among the pores with different sizes in the core [12,25]. The main occurrence in this paper is the transformation of large pores to medium pores.…”

Section: Pore Size Transformationmentioning

confidence: 74%

“…After that, the core began to be flooded by CO 2 and the injection flow rate of the was set to 1 mL/h in in order to avoid the damage of velocity sensitivity to the core. The flooding continued until the pressure at the outlet and inlet were stable (which meant the structure inside the core did not change in the short term) and the total flooding time was at least 150 h [22,25].…”

Section: Core-floodingmentioning

confidence: 99%

“…The dissolution of carbonate cements and feldspar in the matrix causes the movable fines to be released. The migration of these fines and the precipitation of new minerals due to the change in pH of the fluid in the pore lead to blockage in pores during the flooding process, eventually causing the decline of rock permeability [22,25,39,40].…”

Section: Permeability Decline and Fines Migrationmentioning

confidence: 99%

“…The changes in the rocks were analyzed and compared after the CO 2 -brine-rock interactions through X-ray diffraction (XRD), scanning electron microscopy (SEM), nuclear magnetic resonance (NMR), computed tomography scan (CT), mercury injection, etc. The contact modes between rock, CO 2 and formation water during the experiments usually include carbonated water soaking, CO 2 flooding, carbonated water flooding, CO 2 -WAG flooding [21][22][23][24][25][26][27][28]. The results of the studies above show that during the process of CO 2 injection and CO 2 storage in the reservoirs, the fines migration and carbonate precipitate caused by CO 2 -brine-rock interactions result in changes in rock minerals, permeability, pore structure, wettability and break the chemical balance of the formation water, ultimately affecting the seepage of multiphase fluid and threating to safety of CO 2 storage.…”

Section: Introductionmentioning

confidence: 99%

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Experimental Investigation on the Effects of CO2 Displacement Methods on Petrophysical Property Changes of Ultra-Low Permeability Sandstone Reservoirs Near Injection Wells

Wang

Yang

Han³

et al. 2019

Energies

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The petrophysical properties of ultra-low permeability sandstone reservoirs near the injection wells change significantly after CO2 injection for enhanced oil recovery (EOR) and CO2 storage, and different CO2 displacement methods have different effects on these changes. In order to provide the basis for selecting a reasonable displacement method to reduce the damage to these high water cut reservoirs near the injection wells during CO2 injection, CO2-formation water alternate (CO2-WAG) flooding and CO2 flooding experiments were carried out on the fully saturated formation water cores of reservoirs with similar physical properties at in-situ reservoir conditions (78 °, 18 MPa), the similarities and differences of the changes in physical properties of the cores before and after flooding were compared and analyzed. The measurement results of the permeability, porosity, nuclear magnetic resonance (NMR) transversal relaxation time (T2) spectrum and scanning electron microscopy (SEM) of the cores show that the decrease of core permeability after CO2 flooding is smaller than that after CO2-WAG flooding, with almost unchanged porosity in both cores. The proportion of large pores decreases while the proportion of medium pores increases, the proportion of small pores remains almost unchanged, the distribution of pore size of the cores concentrates in the middle. The changes in range and amplitude of the pore size distribution in the core after CO2 flooding are less than those after CO2-WAG flooding. After flooding experiments, clay mineral, clastic fines and salt crystals adhere to some large pores or accumulate at throats, blocking the pores. The changes in core physical properties are the results of mineral dissolution and fines migration, and the differences in these changes under the two displacement methods are caused by the differences in three aspects: the degree of CO2-brine-rock interaction, the radius range of pores where fine migration occurs, the power of fine migration.

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Influence of CO₂ injection on the pore size distribution and petrophysical properties of tight sandstone cores using nuclear magnetic resonance

Zhao

Wang

Zhang³

et al. 2020

Energy Science & Engineering

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CO2 injection has been proposed as an efficient method for enhanced oil recovery in low‐permeability sandstone reservoirs. When CO2 is injected into such reservoirs, the petrophysical properties as well as the pore size distribution of tight formation can be altered due to the interactions between CO2, water, and rock minerals. In this work, CO2 is introduced into the water‐saturated sandstone cores; nuclear magnetic resonance technique is then applied to obtain T2 spectrum of the sandstone cores before and after CO2 injection. The effect of CO2 injection on the pore size distribution is analyzed by comparing the obtained T2 spectrum. In addition, the change of petrophysical properties, that is, total porosity, porosity of the movable fluid, and permeability, are also discussed in this work. Test results show that after introducing CO2, the total volume of small pores is significantly increased. On the contrary, the total volume of medium pores decreases. In addition, the immovable fluid porosity increases in the small pores, while it decreases in the medium pores after injecting CO2. Based on the composition analysis, the concentration of the ions of Na+, K+, Ca2+, and Mg2+ increases in the produced fluid due to the interactions between CO2 and albite, and potash feldspar. After CO2 injection, the total porosity, movable fluid porosity, and permeability of these tight cores are significantly improved. This study is expected to be significant for understanding the mechanisms of alterations of petrophysical properties and pore size distribution of tight sandstone cores due to the CO2 flooding.

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Flood characteristic and fluid rock interactions of a supercritical CO 2 , brine, rock system: South West Hub, Western Australia

Cited by 39 publications

References 59 publications

Chemo‐mechanical Alterations Induced From CO₂ Injection in Carbonate‐Cemented Sandstone: An Experimental Study at 71 °C and 29 MPa

Chemo‐mechanical Alterations Induced From CO₂ Injection in Carbonate‐Cemented Sandstone: An Experimental Study at 71 °C and 29 MPa

Experimental Investigation on the Effects of CO2 Displacement Methods on Petrophysical Property Changes of Ultra-Low Permeability Sandstone Reservoirs Near Injection Wells

Influence of CO₂ injection on the pore size distribution and petrophysical properties of tight sandstone cores using nuclear magnetic resonance

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Flood characteristic and fluid rock interactions of a supercritical CO 2 , brine, rock system: South West Hub, Western Australia

Cited by 39 publications

References 59 publications

Chemo‐mechanical Alterations Induced From CO2 Injection in Carbonate‐Cemented Sandstone: An Experimental Study at 71 °C and 29 MPa

Chemo‐mechanical Alterations Induced From CO2 Injection in Carbonate‐Cemented Sandstone: An Experimental Study at 71 °C and 29 MPa

Experimental Investigation on the Effects of CO2 Displacement Methods on Petrophysical Property Changes of Ultra-Low Permeability Sandstone Reservoirs Near Injection Wells

Influence of CO2 injection on the pore size distribution and petrophysical properties of tight sandstone cores using nuclear magnetic resonance

Contact Info

Product

Resources

About

Chemo‐mechanical Alterations Induced From CO₂ Injection in Carbonate‐Cemented Sandstone: An Experimental Study at 71 °C and 29 MPa

Chemo‐mechanical Alterations Induced From CO₂ Injection in Carbonate‐Cemented Sandstone: An Experimental Study at 71 °C and 29 MPa

Influence of CO₂ injection on the pore size distribution and petrophysical properties of tight sandstone cores using nuclear magnetic resonance