Field Processing, Gathering and Transporting Sour Natural Gas at High Pressures From Pine Creek, Alberta
- C.C. Frye (Hudson&Apos;S Bay Oil & Gas Co. Ltd., Calgary, Alta.) | H.W. Becker (Hudson&Apos;S Bay Oil & Gas Co. Ltd., Calgary, Alta.) | A. Masuda (Hudson&Apos;S Bay Oil & Gas Co. Ltd., Calgary, Alta.) | A.V. Deugau (Hudson&Apos;S Bay Oil & Gas Co. Ltd., Calgary, Alta.)
- Document ID
- Society of Petroleum Engineers
- Journal of Petroleum Technology
- Publication Date
- May 1963
- Document Type
- Journal Paper
- 539 - 544
- 1963. Original copyright American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc. Copyright has expired.
- 5.1 Reservoir Characterisation, 5.8.3 Coal Seam Gas, 4.6 Natural Gas, 4.3.4 Scale, 5.3.2 Multiphase Flow, 4.2.3 Materials and Corrosion, 5.2 Reservoir Fluid Dynamics, 4.1.3 Dehydration, 4.1.5 Processing Equipment, 5.6.4 Drillstem/Well Testing, 4.2 Pipelines, Flowlines and Risers, 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 4.1.6 Compressors, Engines and Turbines, 4.3.1 Hydrates, 4.1.2 Separation and Treating, 5.2.1 Phase Behavior and PVT Measurements
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Natural gas containing 25.65 per cent hydrogen sulfide and 4.75 per cent carbon dioxide is gathered from eight wells and transported 26 miles at a flow rate of 160 MMcf/D and at operating pressures of from 2,200 to 1,800 psig. Dry desiccant dehydrators at each wellsite maintain the dew point of the gas below 17F. Telemetering facilities permit control of field operations from a central instrument console. Corrosion control measures, design considerations and material specifications pertaining to these special conditions are discussed.
Natural gas containing 25.65 per cent H2S and 4.75 per cent CO2 is produced from the Pine Creek field, Alta. It is dehydrated at wellheads, gathered at 2,200 psig and transported 26 miles to the Windfall field where it is delivered to the inlet of, injection compressors at 1,800 psig. The daily average volume of gas transported is 160 MMcf. The project is believed to be unique in its combination of percentage of hydrogen sulfide, operating pressure and transportation distance. This paper describes the project and presents details of some of the design features, corrosion control program and centralized automatic operational control.
The Pine Creek field project is one phase of a joint operation of two fields - the other being the Windfall field. The two fields lie about 30 miles north of Edson, Alta. and 20 miles west of Whitecourt, Alta., respectively, as shown on the map (Fig. 1). They are owned by the same interests and operated according to a plan for maximum economic recovery of products. The Windfall Leduc D-3 reservoir contains a rich condensate-bearing gas containing 15.5 per cent H2S. The gas from the Pine Creek field contains only very small quantities of butane and heavier products. The Windfall reservoir is being cycled to obtain maximum condensate recovery using gas from the Pine Creek field as the displacing fluid, while producing the residue sales gas for both fields from the Windfall field.
The Pine Creek field development and gas-gathering facilities are shown on the map (Fig. 2). The producing formation is the Leduc D-3 reef at a depth of 11,300 ft. The original reservoir pressure was 4,590 psia at 7,400 ft subsea and the temperature is 245F. Eight wells are equipped with dry desiccant dehydrators with the following capacity ratings: three at 35 MMcf/D; three at 20 MMcf/D; and two at 10 MMcf/D.
Dry desiccant dehydrators were designed to reduce the water content of the saturated wellhead stream to 2.5 lb of water/MMcf at 2,000 psig. This specification was necessary to prevent hydrates and corrosion forming in the pipeline which will operate at temperatures as low as 20F. A typical flow diagram is shown in Fig. 3, and Fig. 4 is a photograph of one of the wellhead installations. Some of the design details given below are subject to modification in the field.
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