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Title: Geomechanical response of jointed caprock during CO2 geological sequestration.

Abstract

Abstract not provided.

Authors:
; ;
Publication Date:
Research Org.:
Sandia National Lab. (SNL-NM), Albuquerque, NM (United States)
Sponsoring Org.:
USDOE National Nuclear Security Administration (NNSA)
OSTI Identifier:
1398847
Report Number(s):
SAND2016-9846C
647942
DOE Contract Number:
AC04-94AL85000
Resource Type:
Conference
Resource Relation:
Conference: Proposed for presentation at the AGU2014 Fall meeting held December 15-19, 2014 in San Fransisco, CA.
Country of Publication:
United States
Language:
English

Citation Formats

Newell, Pania, Martinez, Mario J., and Bishop, Joseph E. Geomechanical response of jointed caprock during CO2 geological sequestration.. United States: N. p., 2016. Web.
Newell, Pania, Martinez, Mario J., & Bishop, Joseph E. Geomechanical response of jointed caprock during CO2 geological sequestration.. United States.
Newell, Pania, Martinez, Mario J., and Bishop, Joseph E. 2016. "Geomechanical response of jointed caprock during CO2 geological sequestration.". United States. doi:. https://www.osti.gov/servlets/purl/1398847.
@article{osti_1398847,
title = {Geomechanical response of jointed caprock during CO2 geological sequestration.},
author = {Newell, Pania and Martinez, Mario J. and Bishop, Joseph E.},
abstractNote = {Abstract not provided.},
doi = {},
journal = {},
number = ,
volume = ,
place = {United States},
year = 2016,
month =
}

Conference:
Other availability
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  • Numerical models play an essential role in understanding the facts of carbon dioxide (CO2) geological sequestration in the life cycle of a storage reservoir. We present a series of test cases that reflect a broad and realistic range of aquifer reservoir properties to systematically evaluate and compare the impacts on the geomechanical response to CO2 injection. In this study, a coupled hydro-mechanical model was introduced to simulate the sequestration process, and a quasi-Monte Carlo sampling method was introduced to efficiently sample the value of aquifer properties and geometry parameters. Aquifer permeability was found to be of significant importance to themore » geomechanical response to the injection. To study the influence of uncertainty of the permeability distribution in the aquifer, an additional series of tests is presented, based on a default permeability distribution site sample with various distribution deviations generated by the Monte Carlo sampling method. The results of the test series show that different permeability distributions significantly affect the displacement and possible failure zone.« less
  • In this paper we present results of a numerical simulationof the potential for fault reactivation and hydraulic fracturingassociated with CO2 injection in a multilayered reservoir-caprock system,and discuss its implications on site characterization. The numericalsimulation is performed using the coupled processes simulator TOUGH-FLAC(Rutqvist et al. 2002, Rutqvist and Tsang, 2003), and is an extension ofearlier numerical studies of a single caprock system (Rutqvist and Tsang,2002). In this study, CO2 is injected for 30 years in a 200 meter thickpermeable saline water formation located at 1600 meters depth (Figure 1).The injection formation is overlaid by several layers of caprocks, whichare intersected bymore » a permeable fault zone allowing upward migration ofthe CO2 within the multilayered system (see Table 1 for materialproperties). The potential for fault slip or fracturing are calculated,based on the time-dependent evolution and local distribution of fluidpressure and the three-dimensional stress field, including importantporo-elastic stresses.The numerical results are discussed with respect tothe site-characterization strategy that would be recommended forevaluation of maximum sustainable injection pressure at an industrial CO2injection site.« less
  • A series of numerical test cases reflecting broad and realistic ranges of geological formation properties was developed to systematically evaluate and compare the impacts of those properties on geomechanical responses to CO2 injection. A coupled hydro-geomechanical subsurface transport simulator, STOMP (Subsurface Transport over Multiple Phases), was adopted to simulate the CO2 migration process and geomechanical behaviors of the surrounding geological formations. A quasi-Monte Carlo sampling method was applied to efficiently sample a high-dimensional parameter space consisting of injection rate and 14 subsurface formation properties, including porosity, permeability, entry pressure, irreducible gas and aqueous saturation, Young’s modulus, and Poisson’s ratio formore » both reservoir and caprock. Generalized cross-validation and analysis of variance methods were used to quantitatively measure the significance of the 15 input parameters. Reservoir porosity, permeability, and injection rate were found to be among the most significant factors affecting the geomechanical responses to the CO2 injection. We used a quadrature generalized linear model to build a reduced-order model that can estimate the geomechanical response instantly instead of running computationally expensive numerical simulations.« less
  • A series of numerical test cases reflecting broad and realistic ranges of geological formation properties was developed to systematically evaluate and compare the impacts of those properties on geomechanical responses to CO2 injection. A coupled hydro-geomechanical subsurface transport simulator, STOMP (Subsurface Transport over Multiple Phases), was adopted to simulate the CO2 migration process and geomechanical behaviors of the surrounding geological formations. A quasi-Monte Carlo sampling method was applied to efficiently sample a high-dimensional parameter space consisting of injection rate and 14 subsurface formation properties, including porosity, permeability, entry pressure, irreducible gas and aqueous saturation, Young’s modulus, and Poisson’s ratio formore » both reservoir and caprock. Generalized cross-validation and analysis of variance methods were used to quantitatively measure the significance of the 15 input parameters. Reservoir porosity, permeability, and injection rate were found to be among the most significant factors affecting the geomechanical responses to the CO2 injection. We used a quadrature generalized linear model to build a reduced-order model that can estimate the geomechanical response instantly instead of running computationally expensive numerical simulations. The injection pressure and ground surface displacement are often monitored for injection well safety, and are believed can partially reflect the risk of fault reactivation and seismicity. Based on the reduced order model and response surface, the input parameters can be screened for control the risk of induced seismicity. The uncertainty of the subsurface structure properties cause the numerical simulation based on a single or a few samples does not accurately estimate the geomechanical response in the actual injection site. Probability of risk can be used to evaluate and predict the risk of injection when there are great uncertainty in the subsurface properties and operation conditions.« less
  • We present an analysis of the geomechanical effects of injection rate fluctuations for geological sequestration of carbon dioxide (CO2). Initially, we present analytical solutions for the effects of injection rate fluctuations on CO2 fluid pressure spatial distribution and temporal evolution for a typical injection scenario. Numerical calculations are performed using a finite element method to investigate the effects of injection rate fluctuations on geomechanical deformation, stresses, and potential failure of the aquifer and caprock layers. The numerical method was first validated by the fluid pressure distribution’s good agreement with the analytical solution. It was shown that for any Gaussian fluctuationsmore » of injection rate Q with given mean Q and variance ε_Q, the coefficients of variance for fluid pressure (ϵ_p=ε_p ), deformation (ϵ_u=ε_u ), and stresses (ϵ_σ=ε_σ ) increase linearly with the coefficient of variance for injection rate (ϵ_Q=ε_Q ). The proportional constants are identified, and the fluctuations have the most pronounced effect on the geomechanical stresses, and, therefore, on the potential failure of the aquifer and caprock layers. Instead of expensive computational simulation, this study provides an efficient tool to estimate the geomechanical response variance to injection rate fluctuation. A failure analysis was presented based on the numerical results, where probability of failure was estimated for fluctuating injection rates with different mean and variance during the entire injection period. It was found that with increasing injection rate fluctuation, the failure probability increases significantly. Therefore, the risk associated with injection rate fluctuations should be carefully evaluated.« less