Reservoir Modeling and Simulation of a Middle Eastern Carbonate Reservoir
- M.J. Sibley (Texaco E&P Technology Dept.) | J.V. Bent (Texaco E&P Technology Dept.) | D.W. Davis (Saudi Arabian Texaco)
- Document ID
- Society of Petroleum Engineers
- SPE Reservoir Engineering
- Publication Date
- May 1997
- Document Type
- Journal Paper
- 75 - 81
- 1997. Society of Petroleum Engineers
- 2.2.2 Perforating, 5.1.1 Exploration, Development, Structural Geology, 5.8.7 Carbonate Reservoir, 3.3.1 Production Logging, 5.5.11 Formation Testing (e.g., Wireline, LWD), 5.1.2 Faults and Fracture Characterisation, 5.6.1 Open hole/cased hole log analysis, 3 Production and Well Operations, 5.1.5 Geologic Modeling, 1.6 Drilling Operations, 5.5.8 History Matching, 4.1.5 Processing Equipment, 5.2.1 Phase Behavior and PVT Measurements, 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 4.1.2 Separation and Treating, 5.1 Reservoir Characterisation, 4.3.4 Scale, 5.5 Reservoir Simulation, 1.6.9 Coring, Fishing
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A giant Middle Eastern reservoir was modeled and history matched during reservoir simulation. The model was used to help predict reservoir performance under various scenarios and to evaluate the impact on production rates, ultimate recovery, and economics. Implementation of an infill, extension, and pressure-maintenance plan is in progress. This model overcame shortcomings of previous models of this reservoir through detailed integration of geologic, geophysical, and engineering data. Among the data incorporated were slabbed core, thin-sections, core analyses, seismic, isotope, openhole logs, thermal-decay-time (TDT) logs, repeat formation tests (RFT's), field-pressure surveys, oil and water production data, and production tests. Significant modifications were made to internal and external reservoir architecture, and a diagenetic barrier (DB) was discovered that is the primary barrier to aquifer support. Results of the study include increased booked reserves and production rates, additional infill wells, two reservoir extension area discoveries, and the design and implementation of a pressure-maintenance program.
By the late 1980's, more than 600 million bbl of oil had been produced from this Lower Cretaceous limestone reservoir on the Arabian peninsula. Production had reduced reservoir pressures to the extent that most of the central reservoir area was projected to reach bubblepoint within a few years. Curtailment of production was being considered to prevent possible reservoir damage. To evaluate more favorable alternatives, a reservoir model was created by alarge team of geoscientists and then passed to a group of reservoir engineers to perform reservoir simulation. Repeated simulation attempts, even with substantial model modifications, failed to history match rapid initial pressure depletion, delayed water production, and major vertical-pressure variations. A decision was made to create a new reservoir model.
This time a small integrated team was used throughout the entire modeling process. Composition of the core team varied with time, but at a maximum consisted of two geologists, a geophysicist, two reservoir engineers, and a production engineer. Support personnel and specialists were consulted as needed. Adoption of the "integrated work team approach," coupled with use of advanced computer hardware and software, enabled the new model to be developed and used for prediction cases in less than 18 months. The previous attempt at completing the model with the "linear approach" required 3 years of work and did not yield an acceptable history match.
|File Size||1 MB||Number of Pages||7|