Change in cap rock porosity triggered by pressure and temperature dependent CO2–water–rock interactions in CO2 storage systems

Hemme, Christina; Berk, Wolfgang van

doi:10.1016/j.petlm.2016.11.010

Cited by 29 publications

(8 citation statements)

References 34 publications

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“…Another risk of underground hydrogen storage (ii) is the reaction of H 2(g/aq) with the minerals of the reservoir rock and the cap rock, which can lead to mineral dissolution and precipitation and resulting porosity changes as known from carbon capture and storage e.g., [26][27][28][29]. Changes in the porosity of the cap rock can either improve or deteriorate its sealing capacity.…”

Section: Bacterial Sulfate Reduction (Bsr)mentioning

confidence: 99%

Hydrogeochemical Modeling to Identify Potential Risks of Underground Hydrogen Storage in Depleted Gas Fields

2018

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Underground hydrogen storage is a potential way to balance seasonal fluctuations in energy production from renewable energies. The risks of hydrogen storage in depleted gas fields include the conversion of hydrogen to CH4(g) and H2S(g) due to microbial activity, gas–water–rock interactions in the reservoir and cap rock, which are connected with porosity changes, and the loss of aqueous hydrogen by diffusion through the cap rock brine. These risks lead to loss of hydrogen and thus to a loss of energy. A hydrogeochemical modeling approach is developed to analyze these risks and to understand the basic hydrogeochemical mechanisms of hydrogen storage over storage times at the reservoir scale. The one-dimensional diffusive mass transport model is based on equilibrium reactions for gas–water–rock interactions and kinetic reactions for sulfate reduction and methanogenesis. The modeling code is PHREEQC (pH-REdox-EQuilibrium written in the C programming language). The parameters that influence the hydrogen loss are identified. Crucial parameters are the amount of available electron acceptors, the storage time, and the kinetic rate constants. Hydrogen storage causes a slight decrease in porosity of the reservoir rock. Loss of aqueous hydrogen by diffusion is minimal. A wide range of conditions for optimized hydrogen storage in depleted gas fields is identified.

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Section: Bacterial Sulfate Reduction (Bsr)mentioning

confidence: 99%

Hydrogeochemical Modeling to Identify Potential Risks of Underground Hydrogen Storage in Depleted Gas Fields

2018

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“…28 The CO 2 solubility at 60 °C and 10 MPa is ∼23 cm 3 (STP) per gram of brine. 29 As a result of the dissolution of minerals such as kaolinite and muscovite, the pore volume of the caprock increases, 30 enhancing its flowability/permeability, 4 which is a disadvantage for caprock performance.…”

Section: Resultsmentioning

confidence: 99%

Effect of Geochemical Characteristics on Caprock Performance in Deep Saline Aquifers

Jayasekara

Ranjith

2021

Energy Fuels

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Sequestration of CO2 in deep saline aquifers has attracted positive attention from the scientific community as a mitigatory measure to reduce anthropogenic CO2 in the atmosphere. Caprock layers/zones, which are saturated with brine and CO2 at different degrees of saturation (DOSs), behave differently. Since the risk of CO2 back-migration through different zones in the caprock varies, the focus of this study is on the effects of injected CO2 on the mineralogical and mechanical behavior of caprock with different DOSs due to chemical alteration. A series of reactivity tests were conducted on siltstone samples under different saturation conditions. The experimental results showed that fast dissolution of minerals such as kaolinite and muscovite due to carbonic acid increases the pore volume of caprock. Therefore, flow paths and porosity increase in the fully CO2–brine-saturated zone compared to other zones in the caprock that are not fully saturated with CO2 and brine. In addition, the caprock layer, which is fully saturated with CO2 and brine, has the highest stress corrosion and shear weakening due to mineral dissolution and wetting softening effects, which occur due to surface energy consumption. The next weakest zone in the caprock is the fully brine-saturated siltstone layer due to quartz hydrolysis and wetting softening effects. Therefore, serious attention should be paid to a caprock layer fully saturated with a CO2–brine mixture during sequestration because the risk of CO2 migration via this caprock zone is high, and this affects the permanence and security of injected CO2, especially during periodic CO2 injections and minor seismic events.

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“…The popular research methods consist of laboratory experiments and numerical simulations (Table , Table ). The primary influencing factors include the rock properties, injected pressure, injected flow rate, injected volume, temperature, salinity, reaction time, mineral composition, etc. − Research on asphaltene precipitation involves the evaluation of the change of crude oil composition, the generation and aggregation behavior of precipitation during CO 2 injection, and the variations in porosity and permeability. The dissolution-related study is focused on the types of soluble components in rock minerals and their content change, as well as the induced changes in pore throat structure and physical properties.…”

Section: Influence Of Various Factorsmentioning

confidence: 99%

A Minireview of the Influence of CO₂ Injection on the Pore Structure of Reservoir Rocks: Advances and Outlook

Gao

Xie²,

Cheng

et al. 2022

Energy Fuels

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The recoverable hydrocarbon reserves of conventional oil and gas resources are very limited in China. As important alternative resources, unconventional oil and gas have become a research hotspot. Though tight reservoirs have great potential to alleviate the increasing demand, issues during the development process, such as the rapid pressure depletion, fast decline in production, low productivity, and difficulties in water injection, are usually encountered due to poor physical properties like small pore throats and strong heterogeneity of the pore structure. The CO2 flooding technique could effectively replace crude oil from micro-nanopores, which is considered as a promising way to enhance the development performance of tight oil. However, precipitation and dissolution phenomena usually occur along with the CO2 injection process into reservoirs, affecting the pore structure evolution and oil displacement efficiency. In addition, artificial and natural fractures will even make this process more complicated. This paper presents the commonly used experimental approaches for CO2 injection into tight reservoirs and summarizes the main methods for investigating the influence of CO2 injection on the pore structure of reservoir rocks. Based on this, we highlighted that more attention should be paid to the influence of fractures and their dynamic changes on the evolution of pore structure during CO2 injection and the study of the solid–liquid interactions. To establish a method that could quantitatively evaluate the full-scale evolution of pore throats after CO2 injection is necessary. Meanwhile, the interaction strength of precipitation and dissolution and their effects on pore structure also remain open. Finally, a rigorous framework that could reveal the evolution mechanism and characterize the multiscale pore structure involving multiple influencing factors is urgently warranted.

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Change in cap rock porosity triggered by pressure and temperature dependent CO2–water–rock interactions in CO2 storage systems

Cited by 29 publications

References 34 publications

Hydrogeochemical Modeling to Identify Potential Risks of Underground Hydrogen Storage in Depleted Gas Fields

Hydrogeochemical Modeling to Identify Potential Risks of Underground Hydrogen Storage in Depleted Gas Fields

Effect of Geochemical Characteristics on Caprock Performance in Deep Saline Aquifers

A Minireview of the Influence of CO₂ Injection on the Pore Structure of Reservoir Rocks: Advances and Outlook

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Change in cap rock porosity triggered by pressure and temperature dependent CO2–water–rock interactions in CO2 storage systems

Cited by 29 publications

References 34 publications

Hydrogeochemical Modeling to Identify Potential Risks of Underground Hydrogen Storage in Depleted Gas Fields

Hydrogeochemical Modeling to Identify Potential Risks of Underground Hydrogen Storage in Depleted Gas Fields

Effect of Geochemical Characteristics on Caprock Performance in Deep Saline Aquifers

A Minireview of the Influence of CO2 Injection on the Pore Structure of Reservoir Rocks: Advances and Outlook

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A Minireview of the Influence of CO₂ Injection on the Pore Structure of Reservoir Rocks: Advances and Outlook