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AAPG Bulletin

Abstract

AAPG Bulletin, V. 96, No. 4 (April 2012), P. 635664.

Copyright copy2012. The American Association of Petroleum Geologists. All rights reserved.

DOI:10.1306/07261110178

Geologic modeling and fluid-flow simulation of acid gas disposal in western Wyoming

Shuiquan Li,1 Ye Zhang,2 Xu Zhang,3 Changan Du4

1Department of Geology and Geophysics, University of Wyoming, 1000 East University Avenue, Laramie, Wyoming; [email protected]
2Department of Geology and Geophysics, University of Wyoming, 1000 East University Avenue, Laramie, Wyoming; [email protected]
3Schlumberger Information Solutions (SIS), Schlumberger, 5599 San Felipe, Suite 1700, Houston, Texas; [email protected]
4Schlumberger Information Solutions (SIS), Schlumberger, 14131 Midway Road, Suite 700, Addison, Texas; [email protected]

ABSTRACT

The Moxa arch anticline is a regional-scale northwest-trending uplift in western Wyoming where geologic storage of acid gas (carbon dioxide, methane, nitrogen, hydrogen sulfide, ethane) is under consideration. Nugget Sandstone, a deep saline aquifer at depths exceeding 17,000 ft (5180 m), is a candidate formation. This study builds three-dimensional local- to regional-scale geologic and fluid-flow models for the Nugget Sandstone and its neighboring formations. Geologic and engineering characterization data were assembled and screened for accuracy. Using geostatistical simulations (first, sequential indicator simulation of facies, then the sequential Gaussian simulation of porosity [phis]), the data were integrated to create a regional-scale geologic model from which a local-scale simulation model surrounding the proposed injection si te was extracted. Using this model, acid gas injection was simulated for 50 yr, followed by 1950 yr of monitoring. A sensitivity analysis was conducted, exploring the impact of geologic and engineering variables on model predictions. Results suggest that, at the simulation time scale, low dissolved solids in formation water, large gas-phase relative permeability (krg) hysteresis, and low vertical-to-horizontal intrinsic permeability (k) anisotropy all contribute to enhanced storage of acid gas in both residual (trapped) and dissolved forms. The parameter that exerts the largest control on gas storage is relative permeability hysteresis. However, given parameter uncertainty, the total predicted gas storage varies significantly. Prediction uncertainty increases in the order of dissolved gas, trapped gas, and mobile gas. In comparison, petrophysical uncertainty, as represented by multiple phis realizations, has limited impact on prediction, although future work is needed to expand the uncertainty analysis by developing alternative facies models for the storage formations.

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