SPE 63087 Guidelines for Choosing Compositional and Black-Oil Models for Volatile Oil and Gas-Condensate Reservoirs
Øivind Fevang, SPE, PERA | Kameshwar Singh, SPE, NTNU | Curtis H. Whitson, SPE, NTNU/PERA
SPE Annual Technical Conference and Exhibition, Dallas, Texas, 1–4 October 2000
This paper provides specific guidelines for choosing the PVT model, black-oil or equation of state (EOS), for full-field reservoir simulation of volatile/near-critical oil and gas condensate fluid systems produced by depletion and/or gas
In the paper we have used a “generic” reservoir from the North Sea containing a fluid system with compositional grading from a medium-rich gas condensate upstructure, through an undersaturated critical mixture at the gas-oil contact, to a volatile oil downstructure.
A component pseudoization procedure is described which involves a stepwise automated regression from the original 22- component EOS. We found that a six-component pseudoized EOS model described the reservoir fluid system with good accuracy and, for the most part, this EOS model was used in the study.
Methods are proposed for generating consistent black-oil PVT tables for this complex fluid system. The methods are based on consistent initialization and accurate in-place surface gas and surface oil volumes when compared with initialization with an EOS model. We also discuss the trade-off between accurate initialization and accurate depletion performance (oil and gas recoveries).
Each “reservoir” is simulated using black-oil and compositional models for various depletion and gas injection cases. The simulated performance for the two PVT models is compared for fluid systems ranging from a medium rich gas condensate to a critical fluid, to slightly volatile oils. The initial reservoir fluid composition is either constant with depth or exhibits a vertical compositional gradient. Scenarios both with saturated and undersaturated GOC are considered. The reservoir performance for the two PVT models is also compared for different permeability distributions.
Reservoir simulation results show that the black-oil model can be used for all depletion cases if the black-oil PVT data are generated properly. In most gas injection cases, the blackoil model is not recommended with only a few exceptions. We also show that black-oil simulations using solution oil/gas ratio equal to zero (rs=0) does not always define a conservative (“P10”) sensitivity for gas injection processes. If gravity segregation is strong, the incremental loss of oil recovery due to “zero vaporization” is more than offset by exaggerated density differences caused by erroneous gas densities.
Copyright 2000, Society of Petroleum Engineers Inc.