Quantitative analysis of the influence of capillary pressure on geologic carbon storage forecasts case study: CO2-EOR in the Anadarko basin, Texas. (July 2021)

• Record Type: Journal Article
• Authors: Moodie, Nathan; Ampomah, William; Heath, Jason; Jia, Wei; McPherson, Brian
• Is Part Of: International journal of greenhouse gas control. Volume 109(2021)
• Publication Date: 2021-07
• Subjects: Geologic carbon storage -- Capillary pressure -- Relative Permeability -- CCUS; Greenhouse gases -- Environmental aspects -- Periodicals; Air -- Purification -- Technological innovations -- Periodicals; Gaz à effet de serre -- Périodiques; Gaz à effet de serre -- Réduction -- Périodiques; Air -- Purification -- Technological innovations; Greenhouse gases -- Environmental aspects; Periodicals; 363.73874605
• DOI: 10.1016/j.ijggc.2021.103373
• Languages: English
• ISSNs: 1750-5836

Abstract

Highlights: Capillary pressure is an important control on fluid flow in numerical models. Adding capillary pressure increased forecasts of oil recovery, decreased forecasts of water production, and increased forecasts of CO2 solubility trapping while having little impact on the pressure distribution. The strength of the capillary pressure curve and the shape of the relative permeability curve defines the fluid mobility. Abstract: Numerical models are a critical tool for forecasting subsurface multiphase flow associated with geologic carbon storage. The uncertainty of model results stems from many factors, including uncertainty in multiphase flow parameters. Specifically, relative permeability and capillary pressure relationships depend on both the rock properties and fluid properties, and the latter may be highly nonlinear as fluid temperature, and pressure conditions change. Forecasts of trapping mechanisms, phase behavior, and plume movement are impacted by choice of relative permeability and capillary pressure functions and how those functions are calibrated and constrained. In particular, one of the most neglected aspects of such simulations is meaningful capillary pressure processes. A primary goal of this study is to quantify the difference in forecasts for models that utilize capillary pressure functions calibrated with measured data from the results of models without such. Additionally, the relative permeability models developed here were derived from measured capillary pressure data. Those data were used to constrain saturation endpoints in the relative permeability curves and dictate how that relative permeability was distributed spatially. The main conclusions drawn from this analysis include (1) heterogeneity in relative permeability plays a significant role in simulated forecasts of CO2 migration, trapping mechanisms and storage capacity, as well as oil and water production, and (2) capillary pressure, and in particular, the magnitude of capillarity also plays a significant role in these processes. Conversely, if the magnitude of capillarity is small relative to in situ fluid pressures, it imparts insignificant effects on these processes.