Geomechanical modeling for CO2 Storage in Wabamun Lake Area of Alberta, Canada

Goodarzi, Somayeh; Settari, A.; Keith, David W.

doi:10.1016/j.egypro.2011.02.263

Cited by 14 publications

(13 citation statements)

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“…Other studies have investigated geomechanical (Goodarzi et al, 2010), geochemical (Hutcheon, 1999), and fluid flow aspects of the Nisku Fm. Fluid flow simulations of CO 2 injection were made using the heterogeneous models produced for this project (see Ghaderi et al, 2008).…”

Section: Discussionmentioning

confidence: 99%

Reservoir Characterization for CO₂Sequestration: Assessing the Potential of the Devonian Carbonate Nisku Formation of Central Alberta

Eisinger

Jensen

2011

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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Résumé -Caractérisation de réservoir en vue du stockage géologique de CO 2 : évaluation du potentiel offert par les carbonates dévoniens de la formation de Nisku, en Alberta centralPlusieurs gros émetteurs de CO 2 , totalisant 30 Mt annuels, sont localisés dans la région du Lac Wabamun, au centre de l'Alberta (Canada). Des études antérieures ont montré le potentiel offert par les aquifères salins profonds de la région pour le stockage géologique de ce gaz et le présent article rend compte d'une caractérisation des carbonates dévoniens de la formation Nisku, en vue de réaliser un stockage de CO 2 . Une telle caractérisation doit surmonter plusieurs handicaps : données de puits et de sismique réflexion assez rares et dispersées, tests en forage de qualité médiocre et rareté des mesures modernes. Des diagraphies de porosité ne sont disponibles que pour un tiers des puits, de sorte qu'on a utilisé les diagraphies de résistivité pour évaluer la porosité et la transmissivité (perméabilité × épaisseur). Le facteur de cimentation d'Archie vaut entre 2 et 3, ce qui maintient une incertitude quant à l'estimation de la porosité ainsi obtenue ; toutefois, on peut identifier les intervalles de forte porosité. En ce qui concerne la transmissivité, les valeurs déduites des logs sont mieux corrélées à celles provenant des mesures sur carotte qu'à celles obtenues par DST ou test de production. Un tel comportement n'est pas surprenant, car les tests sont moins sensibles à l'occurrence très locale de bancs rendus extrêmement perméables par une porosité vacuolaire (vuggy ou moldic). La distribution des faciès sédimentaires a été modélisée à l'aide de deux approches, de type "pixel" ou de type "objet". La seconde, qui utilise des dimensions obtenues par imagerie satellitaire sur des environnements actuels, fournit des résultats plus cohérents avec la compréhension géologique que l'on a de la formation de Nisku, et se traduit par une connectivité à large échelle supérieure à celle obtenue par la méthode "pixel". Les volumes obtenus indiquent une capacité potentielle de stockage considérable dans cette formation, toutefois les simulations hydrauliques laissent penser que l'injectivité initiale resterait inférieure à 20 Mt/an (objectif souhaité), pour les puits verticaux. Un design plus élaboré des puits d'injection, avec la prise en compte de stimulation par fracturation et/ou de puits latéraux multiples, pourrait permettre d'atteindre l'objectif d'injection indiqué.

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Section: Discussionmentioning

confidence: 99%

Reservoir Characterization for CO₂Sequestration: Assessing the Potential of the Devonian Carbonate Nisku Formation of Central Alberta

Eisinger

Jensen

2011

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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“…This will model the effect of fracture on fluid flow and heat transfer, which will in turn change the stresses around the fracture through poroelasticity and thermoelasticity. The isothermal dynamic fracture model properties and the transmissibility multiplier function are described in Goodarzi et al (2010). The boundary conditions of this model were initially constant pressure in order to have a comparison with the models in Goodarzi et al (2010).…”

Section: Thermal Effects On Dynamic Fracturingmentioning

confidence: 99%

“…To generate relative permeability data, Van Genuchten (1980) function is used with an irreducible gas saturation of 0.05, an irreducible liquid saturation of 0.2 and an exponent of 0.457. The rest of rock and fluid properties can be found in Goodarzi et al (2010). In order to avoid having initial non-zero shear stresses along the principal directions, all the model grids in this study are aligned along the maximum horizontal (N47E) and minimum horizontal (N43W) stress direction.…”

Section: Coupled Thermal and Geomechanical Modelmentioning

confidence: 99%

“…In order to study the thermal effects of injection on fracture propagation, the coupled geomechanical and thermal model was run with a constant injection rate increased to 7.2E4 m 3 /day so that the bottomhole pressure reaches the fracture pressure. An effective-stress-dependent transmissibility multiplier function was dynamically computed for a plane of grid cells extending from the wellblock which was designated as the potential fracture plane (see Goodarzi et al, 2010 for details). This will model the effect of fracture on fluid flow and heat transfer, which will in turn change the stresses around the fracture through poroelasticity and thermoelasticity.…”

Section: Thermal Effects On Dynamic Fracturingmentioning

confidence: 99%

“…The coupled fluid flow and geomechanical model for injecting CO 2 in Rose Run sandstone aquifer has been built in an earlier study by Goodarzi et al (2010). In this study thermal effects of injection are incorporated in the exisiting coupled model.…”

Section: Introductionmentioning

confidence: 99%

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Thermal Aspects of Geomechanics and Induced Fracturing in CO2 Injection With Application to CO2 Sequestration in Ohio River Valley

Goodarzi

Settari

Zoback³

et al. 2010

All Days

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Ohio River Valley is considered a potential site for CO 2 storage since it is in close proximity to large CO 2 emitters in the area. In a CO 2 storage project, the temperature of the injected CO 2 is usually considerably lower than the formation temperature. The heat transfer between the injected fluid and rock has to be investigated in order to test the viability of the target formation to act as an effective storage unit and to optimize the storage process.A coupled flow, geomechanical and heat transfer model for the potential injection zone and surrounding formations has been developed. All the modeling focuses on a single well performance and considers induced fracturing for both isothermal and thermal injection conditions. The induced thermal effects of CO 2 injection on stresses, displacements, fracture pressure and propagation are investigated. Possibility of shear failure in the caprock resulting from heat transfer between reservoir and the overburden layers is also examined.Displacements will be smaller for the thermal model compared to isothermal model. In the thermal case, the total minimum stress at the wellbore decreases with time and falls below the injection pressure quite early during injection. Therefore, fracturing occurs at considerably lower pressure for the thermal model. The coupled thermal and dynamic fracture model shows that thermal effects of injection could increase the speed of fracture propagation in the storage layer depending on the injection rate. These phenomena are dependent primarily on the difference between the injection and reservoir temperature. An optimization algorithm for injection temperature is discussed based on limiting the maximum fracture length and minimizing the risk of leakage from thermal effects of CO 2 storage while improving the injection capacity.Incorporation of thermal effects in modeling of CO 2 injection is significant for understanding the dynamics of induced fracturing in storage operations. Our work shows that the injection capacity with cold CO 2 injection could be significantly lower than expected, and it may be impractical to avoid induced fracture development. In risk assessment studies inclusion of the thermal effects will help prevent the unexpected leakage in storage projects. The methodology developed will play an important role in process optimization for maximizing the injection capacity while maintaining the safety of storage.

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Impact of geochemical and geomechanical changes on CO₂ sequestration potential in sandstone and limestone aquifers

et al. 2019

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CO2 storage in different geological formations has been recognized as one of the promising mitigation approaches to reduce the emission of CO2 into the atmosphere. There are many complex hydro‐chemo‐mechanical interactions (effective stress changes, water acidification, and mineral dissolution) that may take place in a storage site during or after injection, reducing the integrity of formations in the short or long term. Although there have been several studies carried out in the past to assess the feasibility of sandstones and limestone formations as a safe CO2 storage site, the effect of hydrological, mechanical, and chemical processes on the storage site integrity has not been deeply addressed. The aim of this study is to couple thermo‐hydro‐chemo‐mechanical processes upon CO2 injection and assess their impact on the key storage aspects of quartz‐rich sandstone and calcite‐rich limestone. A numerical model was built to simulate CO2 flooding into a saline aquifer with sandstone and limestone composition for 500 years. The results obtained indicated that geochemical activity and CO2 dissolution are significantly higher in limestone and may increase the porosity by ∼16%. During injection, a decrease in the reservoir strength was observed in both rock types upon exposure to CO2. A remarkable variation in the geomechanical characteristics was also revealed in the sandstone after injection. However, ground displacements (subsidence) of 0.0017 and 0.033 m were, respectively, observed in sandstone and limestone aquifers, at the end of 500 years. It is recommended to consider a high‐strength reservoir for carbon capture and storage (CCS) projects in order to reduce the likelihood of compaction. It was also found that both rock types have a good storage capacity, injectivity, and trapping potentials (the structural and dissolution trappings) to capture and hold CO2 in place. © 2019 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Geomechanical modeling for CO2 Storage in Wabamun Lake Area of Alberta, Canada

Cited by 14 publications

References 4 publications

Reservoir Characterization for CO₂Sequestration: Assessing the Potential of the Devonian Carbonate Nisku Formation of Central Alberta

Reservoir Characterization for CO₂Sequestration: Assessing the Potential of the Devonian Carbonate Nisku Formation of Central Alberta

Thermal Aspects of Geomechanics and Induced Fracturing in CO2 Injection With Application to CO2 Sequestration in Ohio River Valley

Impact of geochemical and geomechanical changes on CO₂ sequestration potential in sandstone and limestone aquifers

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Geomechanical modeling for CO2 Storage in Wabamun Lake Area of Alberta, Canada

Cited by 14 publications

References 4 publications

Reservoir Characterization for CO2Sequestration: Assessing the Potential of the Devonian Carbonate Nisku Formation of Central Alberta

Reservoir Characterization for CO2Sequestration: Assessing the Potential of the Devonian Carbonate Nisku Formation of Central Alberta

Thermal Aspects of Geomechanics and Induced Fracturing in CO2 Injection With Application to CO2 Sequestration in Ohio River Valley

Impact of geochemical and geomechanical changes on CO2 sequestration potential in sandstone and limestone aquifers

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Product

Resources

About

Reservoir Characterization for CO₂Sequestration: Assessing the Potential of the Devonian Carbonate Nisku Formation of Central Alberta

Reservoir Characterization for CO₂Sequestration: Assessing the Potential of the Devonian Carbonate Nisku Formation of Central Alberta

Impact of geochemical and geomechanical changes on CO₂ sequestration potential in sandstone and limestone aquifers