Some New Aspects of the Gas Lift
- E.O. Bennett (Marland Oil Co.) | K.C. Sclater (Marland Oil Co.)
- Document ID
- Society of Petroleum Engineers
- Transactions of the AIME
- Publication Date
- December 1926
- Document Type
- Journal Paper
- 115 - 146
- 1926. Original copyright American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc. Copyright has expired.
- 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 4.2 Pipelines, Flowlines and Risers, 4.6 Natural Gas, 4.3.4 Scale, 4.1.6 Compressors, Engines and Turbines, 5.4.2 Gas Injection Methods, 1.10 Drilling Equipment, 1.7.5 Well Control, 4.2.3 Materials and Corrosion, 3.1.6 Gas Lift, 5.2.1 Phase Behavior and PVT Measurements, 4.1.2 Separation and Treating, 5.1.2 Faults and Fracture Characterisation, 4.1.5 Processing Equipment, 2.4.3 Sand/Solids Control
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This paper is not intended as a theoretical treatise on the gas lift for oilwells, but is written with the object of pointing out a few new ideas whichhave been found practicable and economical for use in this much discussed butlittle used method of producing oil wells. Most of the ideas discussed wereworked out in the Panhandle field of Texas where the problems confrontinggas-lift operation are more numerous and difficult than those found in most oilfields of the United States. One of the principal reasons for the oilindustry's slowness to adopt gas-lift methods is due to the poor results firstobtained in trying to use methods of air lift for raising water in producingoil.
There are so many variables which enter into the design of a gas lift thateach well must be considered as an individual problem and analyzed accordingly.A careful study of results obtained by varying the controllable conditions willfurnish data for increasing the efficiency of an installation that cannot besuccessfully worked out by theoretical equations. The term"submergence" will not be used in this paper. "Submergence" hasbeen used to denote the depth of the lower end of the tubing or flow line belowthe static fluid level in the well. "Working submergence" has been usedto denote the submergence of the tubing or flow line during actual liftingoperations. Both of these have been quantitatively expressed in feet of fluidas required by their definition. The consensus of opinion of many productionengineers is that the term "working submergence" for water lifting withair is inadequate and meaningless when used in petroleum production, since"submergence" never actually exists in a flowing oil well. Theessential factors to be defined are the pressure involved and the rate of flowof fluid into the hole under these pressures. The pressures of importance arethe pressure in the formation, commonly called the "rock pressure," thegas-working pressure, and the pressure on the pay sand due to the fluid belowthe bottom of the tubing plus the working pressure required for the injectionof extraneous gas into the well. The differential pressure causing the flow offluid into the well bore is the difference between the static rock pressure andthe summation of the two variable pressures imposed upon the sand.
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