Evaluation of CO₂ Storage Mechanisms in CO₂ Enhanced Oil Recovery Sites: Application to Morrow Sandstone Reservoir

Abstract

This article presents numerical simulations of CO2 storage mechanisms in the Pennsylvanian Upper Morrow sandstone reservoir, locally termed the Morrow B sandstone in the Farnsworth Unit (FWU) of Ochiltree County, Texas. The CO2 storage mechanisms considered in the study under a CO2 enhanced oil recovery (EOR) mode include structural-stratigraphic trapping, CO2 dissolution in formation water and oil, and residual trapping. The reservoir simulation model was constructed on the basis of field geophysical, geological, and engineering data such as three-dimensional surface seismic data, well logs, and fluid analysis. A representative fluid sampled from the reservoir was analyzed and used to tune the equation of state. A thermodynamic minimum miscible pressure was subsequently computed and compared to the experimental outcome. A history-matched model was constructed and used as a baseline to determine the effects of different hypothetical injection strategies (that consider CO2 purchase, gas recycling, and infill drilling), water-alternating-gas (WAG) schemes, and variable salinity on CO2 storage. The simulation results showed that a significant amount of stored CO2 was dissolved in residual oil, contributing to enhanced oil recovery from the tertiary stage of the field operations. Supercritical-phase CO2 mass within the reservoir compared to CO2 dissolved in formation water was found to be dependent on the CO2 injection strategy. The residual trapping contribution was significant when hysteresis was considered. Pressure, volume of reservoir fluid present, caprock integrity, and optimized WAG injection strategies were significant parameters determining the long-term CO2 storage capacity within the FWU. Caprock integrity analyses showed that sealing units have excellent storage capacity with the potential to support column heights of up to 10000 ft. This work shows an improved strategy of maximizing CO2 storage within a depleted oil reservoir. The results from this study show that pressure changes within the reservoir should be continuously monitored to enhance CO2 storage. This study serves as a benchmark for future CO2-EOR projects in the Anadarko basin or geologically similar basins throughout the world.

Discrete Fracture Network Modelling in a Naturally Fractured Carbonate Reservoir in the Jingbei Oilfield, China

“…More recently, curvature attribute was widely used in delineating faults [6,10,11] and predicting fracture orientations and distributions [7,12,13]. Coherency attribute developed by Bahorich properties, e.g., porosity and permeability, can be calculated by upscaling the DFN model [27,46,47] into cells in order to simulate the reservoir fluid flow [48].…”

The Use of the Surface Roughness Value to Quantify the Extent of Supercritical CO2 Involved Geochemical Reaction at a CO2 Sequestration Site

“…Among them, geological sequestration will be deeply considered to reduce CO 2 emissions at low cost [7][8][9][10][11]. Several CO 2 sequestration projects in the world have been successfully conducted [12][13][14][15], but some CO 2 injection sites were found to be impractical, even though their site characterization, such as geophysical exploration, geo-structural investigation, and drilling core analysis, was thoroughly conducted [16,17].…”

Applicability of an Artificial Neural Network for Predicting Water-Alternating-CO2 Performance

“…The reservoir model is set with a constant depth of the top layer at 2362 m and a pay thickness of 9.15 m, which originated from the average depth and net pay at the Farnsworth field [21]. Other reservoir properties are presented in Table 1; porosity and horizontal permeability are heterogeneous over the reservoir with a nearly tenfold change between minimum and maximum values.…”