Title
Results of the brugge benchmark study for flooding optimization and history matching
Author
Peters, E.
Arts, R.J.
Brouwer, G.K.
Geel, C.R.
Cullick, S.
Lorentzen, R.J.
Chen, Y.
Dunlop, K.N.B.
Vossepoel, F.C.
Xu, R.
Sarma, P.
Alhutali, A.H.
Reynolds, A.C.
TNO Bouw en Ondergrond
Publication year
2010
Abstract
In preparation for the SPE Applied Technology Workshop (ATW) held in Brugge in June 2008, a unique benchmark project was organized to test the combined use of waterflooding-optimization and history-matching methods in a closed-loop workflow. The benchmark was organized in the form of an interactive competition during the months preceding the ATW. The goal set for the exercise was to create a set of history-matched reservoir models and then to find an optimal waterflooding strategy for an oil field containing 20 producers and 10 injectors that can each be controlled by three inflow-control valves (ICVs). A synthetic data set was made available to the participants by TNO, consisting of well-log data, the structure of the reservoir, 10 years of production data, inverted time-lapse seismic data, and other information necessary for the exercise. The parameters to be estimated during the history match were permeability, porosity, and net-to gross-(NTG) thickness ratio. The optimized production strategy was tested on a synthetic truth model developed by TNO, which was also used to generate the production data and inverted time-lapse seismic. Because of time and practical constraints, a full closed-loop exercise was not possible; however, the participants could obtain the response to their production strategy after 10 years, update their models, and resubmit a revised production strategy for the final 10 years of production. In total, nine groups participated in the exercise. The spread of the net present value (NPV) obtained by the different participants is on the order of 10%. The highest result that was obtained is only 3% below the optimized case determined for the known truth field. Although not an objective of this exercise, it was shown that the increase in NPV as a result of having three control intervals per well instead of one was considerable (approximately 20%). The results also showed that the NPV achieved with the flooding strategy that was updated after additional production data became available was consistently higher than before the data became available.
Subject
Benchmark study
Control valves
Flooding strategy
History matching
History-matched reservoir models
Net present value
Optimized production
Production data
Production strategy
Synthetic datasets
Thickness ratio
Time-lapse seismic data
Waterflooding
Well log data
Oil fields
Petroleum reservoir evaluation
Petroleum reservoirs
Production engineering
Seismology
Well flooding
Well logging
Nucleopolyhedrovirus
To reference this document use:
http://resolver.tudelft.nl/uuid:52034894-1c1b-466e-b2fc-af08dd08a95d
TNO identifier
409303
ISSN
1094-6470
Source
SPE Reservoir Evaluation and Engineering, 13 (3), 391-405
Bibliographical note
Ook gepresenteerd op: SPE Reservoir Simulation Symposium 2009, 2-4 February 2009, The Woodlands, TX, USA
Document type
article