Kousha Gohari, Julian Ortiz

Abstract

Steam Assisted Gravity Drainage (SAGD) is a complex process whose success relies heavily on efficient steam utilization. Flow Control Devices (FCDs) have been identified as one of the technologies that offer improved downhole steam utilization and injection/production efficiency.

This presentation explores field application and data along with numerical simulation to identify the key factors that influence the successful implementation of FCDs. The study examines the impact of geometries, resistance factors and FCD implementation strategies. The presentation summarizes the findings from a comprehensive study that has been published in SPE-203866 and SPE-203868.

Ahmed Elgendy, ENI S.P.A.

February 19, 2021

Cap rock integrity and thermally induced fractures (TIF) are two key issues to be evaluated when dealing with CO2 sequestration projects. We will present the current status of geomechanical modelling strategy for CO2 disposal projects, the actual developments towards a single integrated modelling environment (CMG-GEM). The presentation shall include several comparisons (case studies):

1. ECL-ABAQUS Vs CMG-GEM for subsidence prediction (PUNQ-S3)
2. COMSOL Vs CMG-GEM for TIF evaluation (Perkins analytical model)
3. COMSOL Vs CMG-GEM for TIF evaluation (Real case study)

Geochemical investigation in CCS operation: a new perspective

In the framework of Carbon Capture and Storage (CCS), geochemical investigation plays an important role in the assessment of the main physical and the chemical phenomena occurring during and after the CO2 injection in sedimentary formations. To increase the reliability and specificity of the investigation a strong integration between experimental analysis and numerical modelling is nowadays mandatory. Under this theme we shall present:

1. An integrated workflow starting from real samples, couples lab activities and numerical simulations
2. Comparative analysis between PHREEQC-3 and CMG-GEM via 0D (batch) models
3. CO2 injection in 2D multi-layered radial model (including site-specific minerals)

Samin Raziperchikolaee, Research Scientist, Battelle Memorial Institute, Columbus, OH, USA

Abstract

Studying the geomechanical responses of CO2 sequestration into geological formations is necessary since it affects CO2 injectivity, reservoir mechanical integrity, and associated risks of the injection. Coupled hydromechanical numerical modeling can be used to evaluate the poroelastic responses of injection. In the first part of the presentation, we show how hydromechanical modeling (using CMG-GEM) can estimate geomechanical response of CO2 injection into the deep aquifers and depleted oil fields of U.S North East. This includes the geomechanical response of a stacked reservoir-caprock system of the Appalachian basin¹, and a depleted oil reef in Michigan basin².

In the second part of the presentation, we show the application of statistical-based models to estimate poroelastic response to injection ^3,4.

1. Raziperchikolaee et al., The impact of the depth-dependence of in-situ stresses on the effectiveness of stacked caprock reservoir systems for CO2 Storage." Journal of Natural Gas Science and Engineering 79 (2020): 103361.
2. Raziperchikolaee et al.. Assessing mechanical response of CO2 storage into a depleted carbonate reef using a site-scale geomechanical model calibrated with field tests and InSAR monitoring data. Journal of Natural Gas Science and Engineering 86 (2021): 103744.
3. Raziperchikolaee et al.. Statistical based hydromechanical models to estimate poroelastic effects of CO2 injection into a closed reservoir. Greenhouse Gases: Science and Technology (2020).
4. Raziperchikolaee et al.,. Statistical learning based predictive models to assess stress changes-reservoir deformation due to CO2 sequestration into saline aquifers. International Journal of Greenhouse Gas Control 88:416-29(2019).

Seyed Mostafa Jafari Raad

Abstract

Development of safe technologies for CO2 injection, and risk assessment of mechanisms contributing to the permanent storage are necessary steps to avoid undesired consequences of possible leakage of the injected CO2 from subsurface geological formations. Injection wells as the pathway for placing CO2 underground into the targeted subsurface formations, are the primary engineered component of pilot and commercial-scale CCS projects (Nordbotten et al., 2005).

In this study, we investigate the dynamics of a CO2 injection wellbore using a fully-coupled non- isothermal transient multiphase wellbore-reservoir flow model. This study was motivated by issues related to well-bore transient flow dynamics observed in shallow CO2 injection tests undertaken at the Containment and Monitoring Institute (CaMI) Field Research Station (FRS) storage site in Alberta, Canada, particularly gas-liquid transient flow in the well-bore in a gaseous CO2 injection scenario and phase changes along the wellbore. For this study, we set up a transient flow and heat transfer model of the injection well coupled with the surrounding formation and the target storage formation using a commercial thermal multiphase flow simulator CMG STARS (Computer Modelling Group Ltd. 2019). FlexWell CMG STARS was adapted for simulating the complex well-bore physics associated with the heat transfer and fluid flow in the well-bore and interactions with the reservoir. Wellbore transient pressure and temperature and subsequent CO2 phase behavior through the wellbore were analyzed, and the impacts of the reservoir parameters on the wellbore transient flow behavior are characterized. We also performed history-matching of the injection tests to examine various combinations of porosity and permeability multipliers in an attempt to match the historical pressure and temperature data obtained from the CO2 injection tests undertaken at the FRS injection site. The history matching results confirm that the numerical model developed predicts very well the field data trends for both steady and unsteady injection rates.

The outcomes of this study provide an improved understanding of the transient wellbore behavior during CO2 injection over certain pressure-temperature ranges. Results developed here may be used to monitor the injection performance, well and reservoir responses under different injection scenarios.