Secondary Recovery Operations in the Tijerina No. 3 Unit Reservoir
- N.A. Olansen (The Texas Co.)
- Document ID
- Society of Petroleum Engineers
- Journal of Petroleum Technology
- Publication Date
- May 1955
- Document Type
- Journal Paper
- 23 - 26
- 1955. Original copyright American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc. Copyright has expired.
- 5.1.1 Exploration, Development, Structural Geology, 4.1.9 Tanks and storage systems, 1.2.3 Rock properties, 5.2 Reservoir Fluid Dynamics, 1.10 Drilling Equipment, 4.1.5 Processing Equipment, 5.4.2 Gas Injection Methods, 2.4.3 Sand/Solids Control, 5.2.1 Phase Behavior and PVT Measurements
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The purpose of this paper is to present the production history of the Tijerina No. 3 Reservoir from its initial development in April, 1945, through April. 1954, including primary development, unitization, and secondary recovery by high pressure gas injection. Particular attention is given reservoir performance as influenced by the migration of fluids in a continuous but erratic sand of low permeability. It is interesting to note that, from material balance calculations, apparently little or no injected gas goes into solution with the remaining reservoir oil, even though reservoir pressure has been increased an average of 700 psi.
Location and Geology
The Tijerina No. 3 Reservoir is located in the southwest portion of the Tijerina-Canales-Blucher field, approximately 2 miles northeast of the town of Premont. Jim Wells County, Tex. It is the deepest member of a series of lower Oligocene (Frio) Sands productive in the field, lying at an approximate depth of 7,200 ft subsea. Structurally, the reservoir is a permeability trap lying on an erratic monocline, with an average southeast dip of 170 ft per mile. There is no faulting present to break the continuity of the sand. A structure map drawn on the top of the sand is shown in Fig. 1. The productive limits of the reservoir are defined by shale outs and dry tests except in an area to the northwest; where, due to the lack of geological control, the location of the strand line is assumed. The oil column is bounded in this area by a small gas cap, the original gas-oil contact having been established at 7,058 ft subsea by drill stem and production tests run during development. There is no evidence of a water-oil contact in the reservoir. The sand is described as being firm, fine-grained, medium to hard, with scattered shale streaks occurring near the strand line. It possesses a low and erratic permeability as substantiated by PI's which ranged from 0.020 to 0.114 in five wells when measured in April, 1948. A typical electric log is shown in Fig. 2.
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