Deep Hydraulic Pumping-Reno Field
- R.G. Hollis (Shell Oil Co., Denver, Colo.)
- Document ID
- Society of Petroleum Engineers
- Journal of Petroleum Technology
- Publication Date
- November 1966
- Document Type
- Journal Paper
- 1,395 - 1,399
- 1966. Society of Petroleum Engineers
- 2.4.3 Sand/Solids Control, 1.10 Drilling Equipment, 1.2.3 Rock properties, 5.6.8 Well Performance Monitoring, Inflow Performance, 4.1.2 Separation and Treating, 3.1.3 Hydraulic and Jet Pumps, 2 Well Completion, 4.2.3 Materials and Corrosion, 4.1.6 Compressors, Engines and Turbines, 2.2.2 Perforating, 3.1 Artificial Lift Systems, 5.2.1 Phase Behavior and PVT Measurements, 1.6 Drilling Operations, 5.4.1 Waterflooding, 4.3.4 Scale, 4.1.5 Processing Equipment, 1.14 Casing and Cementing, 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc)
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Hydraulic pumps set deeper than all other pumps in the world are producing at rates up to 3,400 BOPD in the Reno field, Wyo. The magnitude of producing rates, operating pressures and well depths provides interesting production engineering problems. This report is concerned with equipment design and layout for surface and bottom-hole pumping systems, and includes recommendations for optimum surface pumping equipment for future batteries. Operating problems associated with high-volume pumping from 15,000 ft are discussed, and plans are outlined for increasing production rates to more than 4,300 BOPD/well.
Wells in the Reno field, located near Buffalo, Wyo., are particularly suited for casing-free hydraulic pumping because of their depth, high productivity and low GOR. Production problems have generally been handled by increasing the capacity of the production equipment and decreasing pressure drops in the system. The cost of hydraulic pumping equipment has been on the order of $100,000/ well for tae four completed wells. A study made in an attempt to reduce the cost of production equipment for future wells revealed the capital cost could not be significantly reduced for these 1,200+ B/D wells, but fewer, larger power oil pumps and. engines were recommended for future batteries to reduce operating costs, especially where fuel must be purchased. Since safety of the surface high-pressure oil-pumping system is important, the layout and design of the power oil system were carefully planned.
Recovery of 5,750 ft of oil during drill-stem test No.1 from Government Well 41X-24 in Jan" 1965, signaled the discovery of the Reno field. In Feb., 1966, the four completed wells in the Reno field produced an average of 8,465 BOPD from 15,000 ft. Casing-free hydraulic pumps are used for artificial lift. Development of the field is progressing with six rigs drilling in the area.
Fig. 1 is a schematic drawing of a typical well completed in the Minnelusa (Tensleep) formation. Two of the zones are very fine to fine grain sandstone with dolomitic cement, and the third zone is micro-crystalline dolomite with porosity due to vugs. Table 1 shows reservoir and PVT data of interest. The reservoir originally had a static BHP of 6,600 psi and a low 450 psi bubble point. The crude bad a 34.9° API gravity and a GOR of less than 100 at a 30 psig separation pressure.
The discovery well, perforated in only the two sandstone zones, bad an initial flowing rate of 800 BOPD, but then declined to a rate of approximately 530 BOPD (no water) with a 30 psig tubing pressure. Based on gradient curves, the flowing BHP was estimated to be 5,000 psi, indicating a PI of 0.3. Due to the low GOR, the well could not flow at rates much above 500 BOPD; therefore, artificial lift was installed to maximize production and aggressively determine the well's inflow performance relationships.
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