Impact of salinity on CO<sub>2</sub>containment security in highly heterogeneous reservoirs

Al‐Khdheeawi, Emad A.; Vialle, Stéphanie; Barifcani, Ahmed; Sarmadivaleh, Mohammad; Zhang, Yihuai; Iglauer, Stefan

doi:10.1002/ghg.1723

Cited by 57 publications

(34 citation statements)

References 105 publications

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“…The corrosion of quartz increases as the time increases at high temperature and pressure. 14 In sum, carbonate minerals such as calcite and Na-feldspar dissolve during CO 2 flooding. Such dissolution increases the porosity of the inlet part of the core sample, which leads to the migration of the cementation and silicate.…”

Section: Discussionmentioning

confidence: 99%

“…Between the solution system and minerals of the target core, dissolution interactions are as follows 26, 27 :

CaC {normalO}_{3} + {normalH}^{+} ⇌ C {normala}^{2 +} + {HCO}_{3}^{-}

\begin{matrix} true \\ left 2 NaAlS i_{3} O_{8} + 2 H^{+} + 9 H_{2} normalO \\ left ⇌ normalA l_{2} normalS i_{2} O_{5} {(OH)}_{4} + 2 normalN a^{+} + 4 H_{4} Si O_{4} \end{matrix}

\begin{matrix} true \\ left CaA l_{2} normalS i_{2} O_{8} + 2 H^{+} + H_{2} normalO \\ left ⇌ normalA l_{2} normalS i_{2} O_{5} {(OH)}_{4} + normalC a^{2 +} + 2 H_{4} Si O_{4} \end{matrix}

Si {normalO}_{2} + 2 {normalH}_{2} O \to {normalH}_{4} Si {normalO}_{4}

During the flooding, water–rock interactions are mainly the dissolution of calcite and Na‐feldspar. The corrosion of quartz increases as the time increases at high temperature and pressure . In the literature, batch experiments conducted by Mandalaparty at high temperature and high pressure were also observed to result in the precipitation of calcite and kaolinite of sandstone samples in the presence of CO 2 .…”

Section: Co2–water–rock Interaction Experimentsmentioning

confidence: 91%

“…Among them, miscible phase flooding is significant for enhancing CO 2 sweep efficiency and oil recovery . Among the various types of possible CO 2 storage, CO 2 trapping mechanisms mainly consist of structure‐based, soluble, residual, and mineral trappings . During the CO 2 flooding process, injected CO 2 displaces oil and occupies the pore space, and then a part of CO 2 dissolves in the ground water and remaining oil .…”

Section: Introductionmentioning

confidence: 99%

“…Many factors, such as geologic characteristics, 15,16,39 salinity, 14 permeability, 17 and water-rock interactions, 18,19 significantly influence the CO 2 storage. Recent studies [18][19][20][21][22] focus on the impact of CO 2 -water-rock interactions on CO 2 storage.…”

Section: Introductionmentioning

confidence: 99%

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Water–rock–CO₂ interactions and CO₂ storage of Honghe tight oil reservoirs: an experimental and simulation study

Yang

et al. 2019

Greenhouse Gases

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CO2 flooding is essential for significantly enhancing oil recoveries and long‐term CO2 storage. We performed CO2 flooding experiments on target tight cores obtained from Honghe oilfield to investigate the water–rock interaction during CO2 flooding. In addition, we investigate the impact of mineralization and CO2 injection patterns on the sweep efficiency and CO2 long‐term storage using numerical simulations. Results show target core samples are composed of calcite, quartz, Na‐feldspar, and K‐feldspar. In particular, the main water–rock interactions during CO2 flooding are calcite and Na‐feldspar dissolution. The impact of water–rock interactions on the reformation of the matrix is not significant. However, such water–rock interactions will decrease the permeability of the natural fracture system near injection wells, which will lead to the enhancement of CO2 flooding efficiency in fractured formations. In addition, results show that water alternating gas injection will enhance oil recovery and CO2 primary storage. After CO2 flooding, mineral‐trapped CO2 is only 0.53wt.% of the total CO2 storage. As the flooding time increases, the mineral‐trapped CO2 increases. Results show that mineral‐trapped CO2 is 31.08% of the total CO2 storage at the simulation time of 500 years. © 2019 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Section: Discussionmentioning

confidence: 99%

“…Between the solution system and minerals of the target core, dissolution interactions are as follows 26, 27 :

CaC {normalO}_{3} + {normalH}^{+} ⇌ C {normala}^{2 +} + {HCO}_{3}^{-}

\begin{matrix} true \\ left 2 NaAlS i_{3} O_{8} + 2 H^{+} + 9 H_{2} normalO \\ left ⇌ normalA l_{2} normalS i_{2} O_{5} {(OH)}_{4} + 2 normalN a^{+} + 4 H_{4} Si O_{4} \end{matrix}

\begin{matrix} true \\ left CaA l_{2} normalS i_{2} O_{8} + 2 H^{+} + H_{2} normalO \\ left ⇌ normalA l_{2} normalS i_{2} O_{5} {(OH)}_{4} + normalC a^{2 +} + 2 H_{4} Si O_{4} \end{matrix}

Si {normalO}_{2} + 2 {normalH}_{2} O \to {normalH}_{4} Si {normalO}_{4}

Section: Co2–water–rock Interaction Experimentsmentioning

confidence: 91%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Water–rock–CO₂ interactions and CO₂ storage of Honghe tight oil reservoirs: an experimental and simulation study

Yang

et al. 2019

Greenhouse Gases

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“…The effectiveness of the trapping mechanisms depends on various geological and hydraulic parameters, including geological reservoir heterogeneities, caprock properties, CO 2 ‐rock wettability, reservoir temperature, wettability heterogeneity, and brine salinity . Moreover, although many geological parameters cannot be changed for a particular site, it has been shown that intelligent selection of CO 2 injection technology (e.g.…”

Section: Introductionmentioning

confidence: 99%

Enhancement of CO₂ trapping efficiency in heterogeneous reservoirs by water‐alternating gas injection

et al. 2018

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Carbon geosequestration efficiency is affected by various factors including reservoir heterogeneity, caprock properties, rock wettability, aquifer brine salinity and injection‐well configuration. Some parameters (e.g. the formation geology) cannot be changed but it is possible to select others and engineer an optimized storage program. One of these parameters is the way CO2 is injected into the reservoir. There are three main options for this: (1) continuous injection, (2) intermittent injection, and (3) water‐alternating gas (WAG) injection. We thus studied the efficiency of each injection option and predicted the associated storage capacities and CO2‐plume movements (which are related to the containment security). We found that WAG injection showed significantly superior behavior over continuous and intermittent injections (which resulted in similar CO2 flow responses). Specifically, residual and solubility trapping were significantly enhanced, whereas vertical CO2 migration was cut by approximately two‐thirds. Thus, in the examined reservoir, the WAG injection is preferred as it strongly enhances CO2 storage efficiency and containment security. © 2018 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Effect of brine salinity on the geological sequestration of CO₂ in a deep saline carbonate formation

et al. 2020

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When supercritical CO2 is injected into a deep saline aquifer, the salinity of the brine can influence both the solubility of the injected CO2 in the brine and the subsequent aqueous geochemical reactions that occur. The objective of this study is to assess the effect of brine salinity on CO2 storage in deep saline carbonate formations. Specifically, the study aims to quantitatively assess the effect of brine salinity on (a) the amount of CO2 that can be sequestered in the aqueous phase, (b) the storage efficiency of the repository, (c) the change in pH of the residual brine after dissolution of CO2, and (d) changes in the mineralogy and porosity of the rock matrix that result from mineral dissolution and precipitation reactions induced by CO2 injection. Injection of CO2 into a model layered carbonate formation was simulated using the reactive‐transport code TOUGHREACT 3.3. The simulations consisted of 50 years of injection into a partially completed injection well, followed by 50 years of equilibration (no injection). Salinity of the brine was varied between 1% and 15% to determine the effects of salinity. Because the solubility of CO2 decreases as the salinity of the brine increases, an increase in brine salinity from 1% to 15% resulted in a 19% decrease in storage efficiency and a 25% decrease in the mass of CO2 dissolved in the aqueous phase. However, despite the strong effect of brine salinity on CO2 dissolution, there was almost no effect of salinity on the pH change in the residual brine: the chemical activity coefficient of the dissolved CO2 increases with brine salinity, counteracting the effects of decreased solubility. Consequently, brine salinity had little effect on mineral dissolution or precipitation, or on changes in formation porosity. The study therefore helps to choose sequestration sites depending upon the salinity of the brine: lower salinity results in more solubility trapping and better storage efficiency without noticeable differences in pH drop or mineral dissolution. © 2020 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Impact of salinity on CO₂containment security in highly heterogeneous reservoirs

Cited by 57 publications

References 105 publications

Water–rock–CO₂ interactions and CO₂ storage of Honghe tight oil reservoirs: an experimental and simulation study

Water–rock–CO₂ interactions and CO₂ storage of Honghe tight oil reservoirs: an experimental and simulation study

Enhancement of CO₂ trapping efficiency in heterogeneous reservoirs by water‐alternating gas injection

Effect of brine salinity on the geological sequestration of CO₂ in a deep saline carbonate formation

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Impact of salinity on CO2containment security in highly heterogeneous reservoirs

Cited by 57 publications

References 105 publications

Water–rock–CO2 interactions and CO2 storage of Honghe tight oil reservoirs: an experimental and simulation study

Water–rock–CO2 interactions and CO2 storage of Honghe tight oil reservoirs: an experimental and simulation study

Enhancement of CO2 trapping efficiency in heterogeneous reservoirs by water‐alternating gas injection

Effect of brine salinity on the geological sequestration of CO2 in a deep saline carbonate formation

Contact Info

Product

Resources

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Impact of salinity on CO₂containment security in highly heterogeneous reservoirs

Water–rock–CO₂ interactions and CO₂ storage of Honghe tight oil reservoirs: an experimental and simulation study

Water–rock–CO₂ interactions and CO₂ storage of Honghe tight oil reservoirs: an experimental and simulation study

Enhancement of CO₂ trapping efficiency in heterogeneous reservoirs by water‐alternating gas injection

Effect of brine salinity on the geological sequestration of CO₂ in a deep saline carbonate formation