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• W2021960407 abstract "Abstract Wellbore heat loss and steam quality downhole, at the sandface are primary factors affecting the performance of steam injection wells used in enhanced performance of steam injection wells used in enhanced oil recovery. Secondary factors critical to steam injection operations are casing thermal stress and economical insulated downhole steam tubular system has been developed by the General Electric Company, Advanced Energy Department, Therman Systems, in Tacoma, Washington. This insulated tubular is the latest product in the General Electric patented ThermoCase line of insulated downhole oilfield products and is designated ThermoCase III. The new insulated tubing allows deeper wells, products old wells, improves steam quality, oil products old wells, improves steam quality, oil production, and simplifies completion design. production, and simplifies completion design. A.P.I. standard tubulars, installation procedures, and rig equipment are used. Evolved from successful deployment at Prudhoe Bay, the welded double tube construction with expansion bellows, hermetically sealed, provides high performance insulation, protects tubular threads, and maintains low casing protects tubular threads, and maintains low casing temperature when flowing 635 degrees F. (335 degrees C), 2000 psi (141 kg/cm2), steam. Initially applications of ThermoCase III in Canadian heavy oil, and tar sands in California and Venezuela are now underway. A thermal description of the product along with a discussion of a number of verification test results will be given. In addition, thermal/ structural and financial/economic computerized analysis results will be given for a typical steam injection field application with 635 degrees F (335 degrees C.) saturated steam at 2000 psia (141 kg/cm2) flowing down a 2300 ft. (701 m) well. In summary, ThermoCase III has been designed to give outstanding thermal performance with a nominal overall K-factor of 0.20 Btu-in/ft2-hr-F degrees (0.028 W/m/ degrees K), Typical significant reductions in casing temperature with ThermoCase III versus standard uninsulated steam tubing were determined to be approximately 431 percent. A similar reduction in relative packer axial movement of approximately 734 percent was also realized in the above mentioned example. Introduction Insulated tubing for enhanced oil recovery has been tried in the past by several field operators, using materials such as calcium silicate and sodium silicate; however, no published references describing such systems have proven unsatisfactory and the individual companies concerned have not pursued improvement in durability and thermal pursued improvement in durability and thermal performance. performance. Thus, General Electric starting from generally successful experience with downhole insulated tubing for Prudhoe Bay Field, Alaska, set out to overcome the additional problems encountered in steam injection and developed the insulated tubing system called ThermoCase III. This paper will review the technical design and economic analyses of ThermoCase III. DESIGN FEATURES OF THERMOCASE III Figure 1 shows a section of ThermoCase III with one complete coupling between two joints. Salient characteristics of the product are illustrated. The product is a double wall tubing with a multilayered insulation (MLI) consists of a number of fibrous glass wraps with alternately placed reflective metal foils. The radiation resistance MLI is backfilled with a relatively low conductivity inert gas. This combination provides a nominal effective K-factor of 0.20 Btu-in/ft2-F degrees (0.028 W/m degrees K). The MLI blanket placed in the annulus between standard oilfield tubulars is hermetically sealed at each end of the joint by a welded Inconel bellows." @default.
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• W2021960407 date "1980-04-09" @default.
• W2021960407 modified "2023-09-27" @default.
• W2021960407 title "A Unique Insulation System for Steam Injection Enhanced Recovery and Geothermal Wells" @default.
• W2021960407 doi "https://doi.org/10.2118/8913-ms" @default.
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