Use of rock mechanics laboratory data in geomechanical modelling to increase confidence in CO2 geological storage

Olden, Peter; Pickup, Gillian Elizabeth; Jin, Min; Mackay, Eric James; Hamilton, Sally Ann; Somerville, James McLean; Todd, Adrian Christopher

doi:10.1016/j.ijggc.2012.09.011

Cited by 36 publications

(17 citation statements)

References 19 publications

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“…To ensure an adequate flow, the CO2 must be injected at a pressure higher than that of the existing reservoir fluids [4]. Envisioned CO2 storage conditions involve temperatures up to 423 K with pressures up to 50 MPa [2].…”

Section: Introductionmentioning

confidence: 99%

Interfacial tensions of the (CO 2 + N 2 + H 2 O) system at temperatures of (298 to 448) K and pressures up to 40 MPa

Chow

Maitland

Trusler

2016

The Journal of Chemical Thermodynamics

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Interfacial tension measurements of the (CO2 + N2 + H2O) and (N2 + H2O) systems are reported at pressures of (2 to 40) MPa, and temperatures of (298.15 to 448.15) K. The pendant drop method was used in which it is necessary to know the density difference between the two phases. To permit calculation of this difference, the compositions of the coexisiting phases were first computed from a combination of the Peng-Robinson equation of state (applied to the non-aqueous phase) and the NRTL model (applied to the aqueous phase). Densities of the non-aqueous phase were computed from the GERG-2008 equation of state, while those of the aqueous phase were calculated knowing the partial molar volumes of the solutes. The expanded uncertainties at 95% confidence are 0.05 K for temperature, 0.07 MPa for pressure, 0.019·γ for interfacial tension in the binary (N2 + H2O) system; and 0.032γ for interfacial tension in the ternary (CO2 + N2 + H2O) system. The interfacial tensions in both systems were found to decrease with both increasing pressure and increasing temperature. An empirical correlation has been developed for the interfacial tension of the (N2 + H2O) system in the full range of conditions investigated, with an average absolute deviation of 0.20 mN·m -1 , and this is used to facilitate a comparison with literature values. Estimates of the interfacial tension for the (CO2 + N2 + H2O) ternary system, by means of empirical combining rules based on the coexisting phase compositions and the interfacial tensions of the binary sub-systems, (N2 + H2O) and (CO2 + H2O), were found to be somewhat inadequate at low temperatures, with an average absolute deviation of 1.9 mN·m -1 for all the conditions investigated. To enable this analysis, selected literature data for the interfacial tensions of the (CO2 + H2O) binary system have been re-analysed, allowing for improved estimates of the density difference between the two phases. The revised result on eleven isotherms were fitted with empirical models that generally represent the data to within 1 mN·m -1 .

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Section: Introductionmentioning

confidence: 99%

Interfacial tensions of the (CO 2 + N 2 + H 2 O) system at temperatures of (298 to 448) K and pressures up to 40 MPa

Chow

Maitland

Trusler

2016

The Journal of Chemical Thermodynamics

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“…These stresses, especially the magnitudes of maximum and minimum horizontal stresses govern the leakage pressure from the reservoir (Lynch et al, 2013;Rutqvist et al, 2008) and vary significantly in a gas storage operation (Cook et al, 2007). In fact, if the pressure increases during injection, the normal stress (which is a combination of in-situ stresses applied perpendicular to the surface of a fault) reduces, causing reactivation of faults or creation of new fractures within the caprock (Ashraf, 2014;Olden et al, 2012;Rutqvist et al, 2007;, depending on the characteristics of the storage medium and the in-situ stress regime of the field (Olden et al, 2012). Raza et al (2015b) did a study on the effective parameters of injectivity and concluded that the effect of injection on the in-situ stress must be taken into consideration to have a good estimation of the fracture initiation pressure.…”

Section: Geomechanical Effects Related To Co2 Injection 1stress Changesmentioning

confidence: 99%

“…However, there are many geomechanical issues, which can take place because of pressure buildup in depleted hydrocarbon reservoirs and aquifers which may not be totally eliminated by a combined production. These geomechanical issues have been covered in numerous studies by (i) predictions of the vertical uplift due to the increase in pore pressure (Ferronato et al, 2010;Karimnezhad et al, 2014;Shi and Durucan, 2009;Shi et al, 2013;Tillner et al, 2014;Zhu et al, 2015); (ii) modelling of fault reactivations due to injection (Ferronato et al, 2010;Kim and Hosseini, 2014;Olden et al, 2012;Rutqvist et al, 2007;Tillner et al, 2014;Vidal-Gilbert et al, 2010;Zhang et al, 2015); and (iii) analysis of fractures generation within the reservoir and caprock (Alonso et al, 2012;Chiaramonte et al, 2011;Ferronato et al, 2010;Goodarzi et al, 2011;Kim and Hosseini, 2014;Lynch et al, 2013;Rutqvist et al, 2008;Shi and Durucan, 2009). For instance, Rutqvist et al (2007) proposed a fully coupled numerical analysis to estimate the maximum sustainable injection pressure for the slip tendency of faults in a twophase system considering continuum stress-strain and discrete fault assessments.…”

Section: Geomechanical Effects Related To Co2 Injection 1stress Changesmentioning

confidence: 99%

Integrity analysis of CO 2 storage sites concerning geochemical-geomechanical interactions in saline aquifers

Raza

Gholami

Sarmadivaleh

et al. 2016

Journal of Natural Gas Science and Engineering

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A systematic and careful analysis of changes in the magnitude of geomechanical parameters is essential to mitigate the risk of leakage from CO2 storage sites. However, depending on rocks and storage sites, these changes might be different due to chemical reactions taking place, especially when it comes to saline aquifers. There have only been few studies carried out in the past to evaluate the maximum sustained pressure of rocks being exposed to these chemical interactions. However, more studies are still required to evaluate the strength of the storage medium or seals when different kinds of rocks and fluids (fresh water or brine) are included in the hostile environment of a storage site. In this paper, attempts were made to evaluate changes in the variation of geomechanical parameters of the Berea sandstone during and after the injection of supercritical CO2 in a short period of time. The results obtained indicated that the presence of brine in the pore space during injection enhances the severity of geochemical reactions, causing reductions in the magnitudes of elastic parameters including shear modulus. Having a good look into the SEM images of the sample before and after exposure to scCO2 indicated that these changes can be attributed to the dissolution/fracturing of calcite and clays in the matrix of the sample. Although findings were provided based on the pulse measurements tests, more studies are required to have a deeper understanding as to how geochemical reactions may cause difficulties during and after injection into a storage site.

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“…The former is typically characterized by the failure properties of cohesion and angle of internal friction, and the lat- ter by the elastic (here termed deformation) properties of Young's modulus and Poisson's ratio derived from the strain gauge measurements on the rock samples. The details of the procedure used to derive the geomechanical properties are described elsewhere (Olden et al 2012). Owing to the vagaries of laboratory testing, the complete suite of tests described above was not carried out on all the samples.…”

Section: Site-specific Geomechanical Propertiesmentioning

confidence: 99%

“…The triaxial tests on brine-saturated (aquifer) sandstone samples enabled permeability stress sensitivity curves to be generated, as also described elsewhere (Olden et al 2012). The curves were used to calculate permeability reduction factors depending on mean effective stress, deriving initial in situ permeabilities for the updated geomechanical models depending on the initial mean effective stresses.…”

Section: Permeability Stress Sensitivitymentioning

confidence: 99%

Geomechanical modelling of CO ₂ geological storage with the use of site specific rock mechanics laboratory data

Olden

Jin

Pickup

et al. 2014

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Many diverse challenges – political, economic, legal and technical – face the continued development and deployment of geological storage of anthropogenic CO 2 . Among the technical challenges will be the satisfactory proof of storage site security and efficacy. Evidence from many past geotechnical projects has shown the investigations and analyses that are required to demonstrate safe and satisfactory performance will be site specific. This will hold for the geomechanical assessment of saline aquifer storage site integrity where, compared to depleted hydrocarbon fields, there will be no previous pressure response history or rock property characterization data available. The work presented was carried out as part of a project investigating the improvement in levels of confidence in all aspects of saline aquifer site selection and characterization that could be expected with increasing data availability and in-depth analysis. Attention focused on the geomechanical modelling and the rock mechanics data used to populate models of two storage sites in geological settings analogous to those where CO 2 storage might be considered. Coupled geomechanical models were developed from reservoir simulation models initially incorporating generic rock mechanical properties and then laboratory-derived site-specific properties. The models were run in various configurations to investigate the effect of changing the rock mechanical properties on the geomechanical response of the storage systems. Modelling results showed that the pressure response at one site due to low injectivity caused significant potential for fault reactivation. Increasing the number of injection wells, thereby reducing the individual rates needed to deliver the target capacity, reduced the injection pressures and ameliorated, but did not eliminate, this adverse response.

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Use of rock mechanics laboratory data in geomechanical modelling to increase confidence in CO2 geological storage

Cited by 36 publications

References 19 publications

Interfacial tensions of the (CO 2 + N 2 + H 2 O) system at temperatures of (298 to 448) K and pressures up to 40 MPa

Interfacial tensions of the (CO 2 + N 2 + H 2 O) system at temperatures of (298 to 448) K and pressures up to 40 MPa

Integrity analysis of CO 2 storage sites concerning geochemical-geomechanical interactions in saline aquifers

Geomechanical modelling of CO ₂ geological storage with the use of site specific rock mechanics laboratory data

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Use of rock mechanics laboratory data in geomechanical modelling to increase confidence in CO2 geological storage

Cited by 36 publications

References 19 publications

Interfacial tensions of the (CO 2 + N 2 + H 2 O) system at temperatures of (298 to 448) K and pressures up to 40 MPa

Interfacial tensions of the (CO 2 + N 2 + H 2 O) system at temperatures of (298 to 448) K and pressures up to 40 MPa

Integrity analysis of CO 2 storage sites concerning geochemical-geomechanical interactions in saline aquifers

Geomechanical modelling of CO 2 geological storage with the use of site specific rock mechanics laboratory data

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Geomechanical modelling of CO ₂ geological storage with the use of site specific rock mechanics laboratory data