Development of Marginal/Mature Oil Fields: A Case Study of the Sinclair Field
- P. Resnyanskiy (University of Alberta) | T. Babadagli (University of Alberta)
- Document ID
- Society of Petroleum Engineers
- Journal of Canadian Petroleum Technology
- Publication Date
- April 2010
- Document Type
- Journal Paper
- 29 - 35
- 2010. Society of Petroleum Engineers
- 5.1.1 Exploration, Development, Structural Geology, 5.3.2 Multiphase Flow, 4.3.4 Scale, 5.1 Reservoir Characterisation, 3.3 Well & Reservoir Surveillance and Monitoring, 2.4.3 Sand/Solids Control, 5.5 Reservoir Simulation, 6.5.2 Water use, produced water discharge and disposal, 1.6.9 Coring, Fishing, 5.6.1 Open hole/cased hole log analysis, 5.5.8 History Matching, 5.1.5 Geologic Modeling, 5.4.7 Chemical Flooding Methods (e.g., Polymer, Solvent, Nitrogen, Immiscible CO2, Surfactant, Vapex), 1.2.3 Rock properties, 5.7.2 Recovery Factors, 5.4.1 Waterflooding, 2.5.2 Fracturing Materials (Fluids, Proppant)
- mature fields, Sinclair field, marginal fields
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Development of marginal/mature fields has become popular because of a significant decline in new field discoveries and high oil prices. In particular, small size fields of this kind are more challenging because of limited options for development. This paper presents a study on the Sinclair field located in Alberta, Canada. The field has 19 wells, six of which are horizontal, and have been in production for more than 20 years. Despite the quality of oil (40°API, 1.5 cp) and rock properties (20% average porosity, water-wet sandstone), the current production is less than 100 bbl/D for the whole field. The field is now undergoing waterflooding. The main challenges are the thin pay zone (~4 m), severe water production and a puzzling recovery factor of approximately 10%.
The current study consists of three phases: numerical reservoir modelling and history match to understand the reasons for low oil production and to analyze the hydrodynamic characteristics of the field, characterization of reservoir and interwell connectivity using static and production data and proposing an enhanced oil recovery technique supported by field scale numerical simulation. After modelling and history matching stages, potential reserves locations are estimated for possible dilute surfactant injection. Based on interwell connectivity, different injection schemes that use some producers as injectors are tested. The obtained results are subject to further evaluation and analysis to derive the economic viability of the field.
|File Size||1 MB||Number of Pages||7|
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