| HPHT and Complex Well Completion |
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In addition to instructing courses in completions design and casing/tubing stress analysis (using both conventional Working Stress and Reliability Based Design Procedures), APA has been involved in numerous complex completion designs for onshore and offshore wells. These wells cover the full range conditions: high pressure; high temperature (HPHT); critical sour; offshore (platform and deepwater subsea); complex (multi-string, multi-packer) designs. Landmarks WELLCAT group of programs is used for all drilling and production temperature simulations, and for casing and tubing stress analysis. The following list illustrates the range of projects APA has been involved with.
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FIELD
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PROJECT DESCRIPTION/SERVICES PROVIDED BY RPS-APA
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| Onshore California |
Casing and tubing stress analyses for onshore HPHT wells. APA has also provided equipment selection and qualification, completion fluid selection, detailed operations procedures and contingencies, well test design, and ongoing technical support and supervision of field operations. |
| Gulf of Mexico |
Various Complete casing and tubing design, and completion design, including sand control, SMART well completion equipment (electro-hydraulic controlled sliding sleeve for control of stacked completions), and riser design for various subsea and SPAR development and exploration projects in the Gulf of Mexico, in water depths up to 8,500 ft, and bottomhole pressures > 21,000 psi. Detailed completion programs included interface with subsea contractors to develop tubing hanger installation procedures, and horizontal subsea tree commissioning procedures. Supervised offshore completion and well start-up |
| Sable, Offshore Canada |
Detailed HPHT Well Intervention and Operating Manual for Sable offshore wells. This manual includes the identification of well intervention hazards; safety barrier philosophy; well kill procedures; completion and wellhead operations and equipment; subsurface safety valve operations; wireline (slickline electric) operations/equipment; coil tubing and nitrogen operations; and portable test equipment and operations. |
| Singa, Indonesia |
Design of casing and tubing for an onshore 13,500 ft deep sour gas well with a reservoir pressure of 11,000 psi, and a reservoir temperature of 485EF. Due to the extremely high temperatures experienced while drilling, APA provided ongoing support to modify the drilling program (casing tensions, circulating rates, mud selection, etc.) while the well was being drilled. |
| Hibernia, Offshore Canada |
Tubing weight and grade selection for production, water injection, and gas injection wells. Tubing ranged in size from 4.5” to 7", landed in PBR’s as deep as 21,000 ft (extended reach wells). Gas injection wells were designed for >133 MMscf/d with an injection temperature of 365EF. Study results also served as the basis for connection qualification testing and selection. |
Groningen, Netherlands
Arun, Indonesia |
Big bore (9 5/8"monobore) completions design and safety study. Review of operational and re-entry procedures and SSV requirements |
| Nigeria, Bangladesh India |
Completion design, equipment specification, programming, and supervision for offshore platform based directional wells. A number of wells were multi-packer dual completions with one well designed for simultaneous production and water injection operations |
| Foothills and Northwest Territories, Canada |
Various facets of completions design for deep, HPHT, critical sour gas wells. Downhole hydrate control requirements including chemical injection and heater string options. Coupling selection and landing condition specification to minimise seal movement and facilitate use of non-upset couplings that are weak in compression. Packer failure analysis and audit. |
| Japan |
Installation of sand control devices under pressure for high productivity, highly depleted gas storage wells drilled using Underbalanced Drilling Technology. |
| North West Shelf & Timor Gap, Australia |
Multilateral Completion Technology review and application assessment for wells requiring Level III, IV or V junction systems, with the possibility of partial isolation, and sand control systems. |
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