Well-Performance Relationships in Heavy-Foamy-Oil Reservoirs
- Rahul Kumar (University of Tulsa) | Jagannathan Mahadevan (University of Tulsa)
- Document ID
- Society of Petroleum Engineers
- SPE Production & Operations
- Publication Date
- February 2012
- Document Type
- Journal Paper
- 94 - 105
- 2012. Society of Petroleum Engineers
- 4.6 Natural Gas, 5.6.8 Well Performance Monitoring, Inflow Performance, 5.2.1 Phase Behavior and PVT Measurements
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- 1,040 since 2007
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Inflow performance in some heavy-oil reservoirs is not well understood because the fluid properties differ from conventional behavior. In this work, we develop an expression for inflow performance as a function of properties of foamy oils (e.g., density, viscosity, solution gas/oil ratio, and formation volume factor). We define two parameters, the endpoint entrained-gas fraction and the apparent bubblepoint, adapted from previous studies, to account for the extent of entrained-gas fraction in the liquid. The fluid properties are modified to account for the entrained gas and then incorporated in the equations describing flow from a reservoir at pseudosteady state.
The results of our study show that the entrained gas and the apparent bubblepoint impact the fluid properties and, therefore, the inflow performance at the bottomhole conditions. In the presence of entrained gas, the density of the fluid decreases and the formation volume factor increases. Both these properties show an inflection below the bubblepoint pressure, and the solution gas/oil ratio shows a constant value until the apparent bubblepoint is reached. The inflow-performance curve, therefore, displays an inflection as opposed to the monotonically changing curve normally observed with conventional oils. The outflow-performance curve is lowered when the effect of entrained gas is included, caused by lower density; hence, the nodal systems analysis predicts a greater production rate for a foamy-oil reservoir compared with a conventional reservoir.
|File Size||843 KB||Number of Pages||12|
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