Impact of Three-Phase Relative Permeability and Hysteresis Models on Forecasts of Storage Associated With CO2-EOR

Jia, Wei; McPherson, Brian; Pan, Feng; Dai, Zhenxue; Moodie, Nathan; Xiao, Ting

doi:10.1002/2017WR021273

Impact of Three-Phase Relative Permeability and Hysteresis Models on Forecasts of Storage Associated With CO₂-EOR

Journal Article · Thu Dec 07 00:00:00 EST 2017 · Water Resources Research

DOI:https://doi.org/10.1002/2017WR021273· OSTI ID:1558052

^[1]; McPherson, Brian ^[1]; Pan, Feng ^[2]; ^[3]; Moodie, Nathan ^[1]; ^[1]

Univ. of Utah, Salt Lake City, UT (United States)
Utah Division of Water Resources, Salt Lake City, UT (United States)
Jilin Univ., Changchun (China); Los Alamos National Lab. (LANL), Los Alamos, NM (United States)

Geological CO₂ sequestration in conjunction with enhanced oil recovery (CO₂-EOR) includes complex multiphase flow processes compared to CO₂ storage in deep saline aquifers. Two of the most critical factors affecting multiphase flow in CO₂-EOR are three-phase relative permeability and associated hysteresis, both of which are difficult to measure and are usually represented by numerical interpolation models. The purpose of this research is to improve understanding of (1) the relative impacts of different three-phase relative permeability models and hysteresis models on CO₂ trapping mechanisms, and (2) uncertainty associated with these two factors. Four different three-phase relative permeability models and three hysteresis models were applied to simulations of an active CO₂-EOR site, the SACROC unit located in western Texas. To eliminate potential bias of deterministic parameters, we utilized a sequential Gaussian simulation technique to generate 50 realizations to describe heterogeneity of porosity and permeability, based on data obtained from well logs and seismic survey. Simulation results of forecasted CO₂ storage suggested that (1) the choice of three-phase relative permeability model and hysteresis model led to noticeable impacts on forecasted CO₂ sequestration capacity; (2) impacts of three-phase relative permeability models and hysteresis models on CO₂ trapping are small during the CO₂-EOR injection period, and increase during the post-EOR CO₂ injection period; (3) the specific choice of hysteresis model is more important relative to the choice of three-phase relative permeability model; and (4) using the recommended three-phase WAG (Water-Alternating-Gas) hysteresis model may increase the impact of three-phase relative permeability models and uncertainty due to heterogeneity.

View Accepted Manuscript (DOE)

Research Organization:: Los Alamos National Lab. (LANL), Los Alamos, NM (United States)

Sponsoring Organization:: Southwest Regional Partnership on Carbon Sequestration (SWP); USDOE National Nuclear Security Administration (NNSA); Utah Science Technology and Research Initiative (USTAR)

Grant/Contract Number:: 89233218CNA000001; FC26-05NT42591

OSTI ID:: 1558052

Alternate ID(s):: OSTI ID: 1422241

Report Number(s):: LA-UR--18-29374

Journal Information:: Water Resources Research, Journal Name: Water Resources Research Journal Issue: 2 Vol. 54; ISSN 0043-1397

Publisher:: American Geophysical Union (AGU)Copyright Statement

Country of Publication:: United States

Language:: English

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42 ENGINEERING
CO2 enhanced oil recovery (CO2‐EOR)
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