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The AAPG/Datapages Combined Publications Database
AAPG Bulletin
Abstract
AAPG Bulletin, V.
Modeling
and Geopseudo Upscaling
Applied to Waterflood Performance Prediction of an Incised Valley Reservoir:
Countess YY Pool, Southern Alberta, Canada
1Manuscript received April 2, 1997; revised manuscript received
February 24, 1998; final acceptance March 21, 1998.
2Graduate of Heriot-Watt University. Current address: Halliburton
Energy Services, Reservoir Description, 91-1SE-25J, 10200 Bellaire Boulevard,
Houston, Texas 77072-5299; e-mail: [email protected]
3Mobil Technology Company, 13777 Midway Road, Dallas, Texas
75244-4390; e-mail: [email protected]
4PanCanadian Petroleum Limited, 150 9th Avenue S.W., P.O.
Box 2850, Calgary, Alberta, Canada T2P 2S5; e-mail: [email protected]
This research project was done as the final part of a Masters degree
program in reservoir evaluation and management at the Petroleum Engineering
Department of Heriot-Watt University in Edinburgh, Scotland. Many individuals
provided assistance so that this study could be completed within the available
period of three months. The Petroleum Engineering Department is acknowledged
for providing computer facilities and probe-permeameter equipment. Philip
Ringrose and Gillian Pickup are thanked for helpful information and discussions
on geopseudo upscaling. We gratefully acknowledge PanCanadian Petroleum
Limited, who operates the Countess YY Pool, for organizing and financing
this project, for access to the data and the core facility, and for permission
to publish this work. We especially thank Eugene Peters and Garth Syhlonyk
for sharing their knowledge on the Countess YY pool and incised valley
reservoirs in general. Reviews of the manuscript by Bob Dalrymple, Eugene
Peters, Janok Bhattacharya, I. M. Yarus, and an anonymous reviewer are
very much appreciated.
Abstract
Core observations and probe-permeameter data are acquired to perform
a geopseudo upscaling exercise, which simulates the effects of small-scale
sedimentary structures on fluid flow. Applying this method and incorporating
small-scale sedimentary structures in 2-D fluid flow simulations have proved
to make a significant difference in individual-well oil recovery (up to
8%) depending on the facies types involved in a wells drainage area. Incorporating
variations in sand-body dimensions and connectivities has proved to have
a major impact on field oil recovery (30% difference between extreme 2-D
cases), whereas variations in incised valley size have the greatest impact
on original oil-in-place values (21% between extreme 2-D cases).
A layercake model of an incised valley reservoir results in optimistic
performance compared to a geopseudo upscaled model (11% higher oil recovery
for a 2-D case). In a highly favorable scenario, an incised valley reservoir
indeed may behave like a layercake, but it is more likely that it will
not perform as well.
Not taking into account small-scale sedimentary structures, uncertainty
in reservoir architecture, and incised valley size in reservoir simulation
studies can introduce substantial errors in reserves estimation and production
forecasting. Lessons learned from this 2-D study will be used in a future
full-field three-dimensional waterflood simulation of the Countess YY pool.
The objective of this study is to analyze the effects of different
modeling
approaches and various scales of geological heterogeneity on waterflood
recovery and volumetrics of an incised valley reservoir.
Seismic
, well-log,
and core data are integrated with an incised valley facies model to create
cross sections used to perform two-phase 2-D (two-dimensional) fluid-flow
simulations.
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