Dissolution of arkose in dilute acetic acid solution under conditions relevant to burial diagenesis

Yang, Leilei; Xu, Tianfu; Wei, Mingcong; Feng, Guanhong; Wang, Fugang; Wang, Kairan

doi:10.1016/j.apgeochem.2015.01.007

Cited by 21 publications

(8 citation statements)

References 42 publications

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“…[4,5,65,67] The optimal capillary trapping limit, which we define here as the point where primary drainage is unaffected by wettability is at θa = 50°. [68] a is even more affected by the carboxylic acids concentration; even at a relatively low pressure of 10 MPa (note that increasing pressure increases ) [4,17] and 323 K, θa reaches 50° at 10 -10 M carboxylic acids concentration (note that this is a very minute concentration, much higher carboxylic acids concentration are measured in deep saline aquifers [22][23][24][25][26][27] and for 25 MPa this organic threshold is even below 10 -10 M ( Figure 1). The SEM images of the calcite surfaces were acquired before and after treatment with stearic acid; two examples are shown in Figure 2.…”

Section: Resultsmentioning

confidence: 96%

“…As mentioned above, real aquifers contain organic acid molecules which are partially adsorbed on the rock surface. [22][23][24][25][26][27] It is thus vital to re-create such mineral surfaces to realistically mimic aquifer rock surfaces, particularly with respect to their wettability characteristics. [28,[43][44][45] Thus below the procedure for preparing such realistic aquifer surfaces is described, as it was used in this research work.…”

Section: Simulating Real Aquifer Conditionsmentioning

confidence: 99%

“…in oxygen plasma or in UV-ozone atmosphere), [18,19] while it is well established that in the subsurface anoxic or reducing conditions prevail. [20,21] In addition, it is clear that storage formations always contains traces of dissolved organic acid material, [22][23][24][25][26][27] which is potentially sufficient to significantly change the rock's CO2-wettability.…”

Section: Introductionmentioning

confidence: 99%

See 2 more Smart Citations

Organic acid concentration thresholds for ageing of carbonate minerals: Implications for CO2 trapping/storage

Ali

Al-Anssari

Arif

et al. 2019

Journal of Colloid and Interface Science

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These thresholds (defined for structural trapping as a water contact angle θ > 90°; and for capillary trapping when primary drainage is unaffected, i.e. θ > 50°) were very low for structural trapping (∼10-10 M organic acid concentration C) and extremely low for capillary trapping (10 M to below 10 M C). Since minute organic acid concentrations are always present in deep saline aquifers and certainly in depleted hydrocarbon reservoirs, significantly lower storage capacities and containment security than previously thought can be predicted in carbonate reservoirs, and reservoir-scale models and evaluation schemes need to account for these effects to de-risk CGS projects.

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Section: Resultsmentioning

confidence: 96%

Section: Simulating Real Aquifer Conditionsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Organic acid concentration thresholds for ageing of carbonate minerals: Implications for CO2 trapping/storage

Ali

Al-Anssari

Arif

et al. 2019

Journal of Colloid and Interface Science

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“…Both authigenic kaolinite and dissolved feldspar minerals were observed in the reservoir rocks. In clastic reservoirs, kaolinite commonly precipitated initially during early burial and then transformed into illite concomitant with dissolution of feldspar minerals (Yang et al ., ). It was assumed that the dissolution of K‐feldspar and albite provided large quantities of aluminium and silicon needed for the precipitation of kaolinite.…”

Section: Introductionmentioning

confidence: 97%

Fluid–rock interactions during continuous diagenesis of sandstone reservoirs and their effects on reservoir porosity

Yang

Liu

et al. 2017

Sedimentology

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The Cretaceous sandstone reservoir in the Kuche Depression, Tarim Basin, western China, was investigated with reference to its reservoir property evolution during diagenesis. Six general diagenetic stages were recognized through petrographic, mineralogical and geochemical analyses. Fluid–rock interaction experiments were conducted under these six continuous diagenetic conditions, that is with a simulation sequence of compaction → early diagenesis → organic acid incursion I → elevated temperature/pressure → organic acid incursion II → late diagenesis. Corresponding to these six experimental stages, a total of six models were constructed. Finally, an extended model of fluid–rock interaction during diagenesis at a geological timescale (from 30 Ma to present) was constructed after various parameters had been validated. Results demonstrate that the diagenetic stages from both the experimental and numerical simulations generally matched findings obtained from the petrographic and geochemical analyses: (i) With compaction becoming weakened, cementation by various minerals was gradually increased. (ii) Quartz overgrowth occurred because the contemporaneous sedimentary water was alkaline. (iii) Most minerals (for example, calcite and feldspar minerals) displayed dissolution owing to the first organic acid incursion, resulting in the visual porosity increasing to 29·26%. (iv) Increases in temperature and pressure caused a minor fluctuation of the porosity change. (v) The cement that formed during earlier stages largely dissolved with the second organic acid incursion. (vi) During the last stage, the reservoir fluid was diluted by sedimentary alkaline water and most minerals precipitated under an alkalic environment. The present porosity simulated is about 11·4%, comparable with the actually measured data. This study demonstrates that the combination of petrographic observations, laboratory experiments and numerical simulations can not only reconstruct the diagenetic process, but also provide a quantitative evaluation and prediction of reservoir petrophysical properties.

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“…There were 54 different conditions considered to evaluate the evolution of fissure corrosion (Table 4). The simulation software used in this study was TOUGH-REACT, which is widely used in the numerical simulation of water-rock interactions [66,67]. Figure 9, during the same corrosion time, the corrosion range of 35°C was larger than that of 10°C.…”

Section: Geofluidsmentioning

confidence: 96%

Study of the Corrosion Characteristics of Tunnel Fissures in a Karst Area in Southwest China

Zhao

Wang

et al. 2018

Geofluids

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The development of the fissures in soluble rock of karst areas directly affects the construction and operation safety of tunnel engineering. It is thus of theoretical and practical significance to study the characteristics of its corrosion and its influencing factors. Taking the Wulong tunnel as the research object, the numerical model of the study area was established to quantitatively analyze the corrosion range, corrosion ratio, and changes in the permeability and porosity of the fissures in soluble rock of karst areas of the tunnel over the past 100 years, and the simulation results were verified by field experiments. The results show that the main controlling factor of the fissure corrosion of the tunnel in the karst area is the flow rate. The corrosion range and corrosion ratio of the fissures of the tunnels in the karst area increased with temperature because the reaction rate constant increased with temperature, causing the reactions’ equilibrium to move towards the direction of the solution. The larger the initial permeability and the larger the porosity of the fissures, the faster the fissures corrode. In the same time period, the fissures with high permeability and large porosity will lead to the permeability and porosity being more enhanced, thus causing the corrosion of the fissures to exhibit secondary enhancement effects. The opening of the dead-end pores greatly enhanced the permeability and slightly increased the porosity, which caused the differential corrosion of fissures in the karst area. The protection of the tunnel should be strengthened, mainly in strong hydrodynamic conditions and in the fracture development zone.

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Dissolution of arkose in dilute acetic acid solution under conditions relevant to burial diagenesis

Cited by 21 publications

References 42 publications

Organic acid concentration thresholds for ageing of carbonate minerals: Implications for CO2 trapping/storage

Organic acid concentration thresholds for ageing of carbonate minerals: Implications for CO2 trapping/storage

Fluid–rock interactions during continuous diagenesis of sandstone reservoirs and their effects on reservoir porosity

Study of the Corrosion Characteristics of Tunnel Fissures in a Karst Area in Southwest China

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