Careful procedure cuts corrosion in CO/sub 2/ injectors
In one West Texas CO/sub 2/ injection project, Unocal Corp., using state-of-the-art connection and testing procedures, has developed a method of installing downhole CO/sub 2/ injection equipment that virtually eliminates tubing-casing communication and its resulting downhole corrosion. In addition, the internal plastic coating of the tubulars is monitored and protected during field handing procedures. The system involves the use of a helium connection test combined with meticuluous attention to detail in the field handling and connection of the tubulars. Corrosion of injection equipment is a common problem in CO/sub 2/-miscible injection operations. The two basic mechanisms by which this corrosion occurs are from internal corrosion caused by holidays in the injection tubing coating as well as from external corrosion caused by CO/sub 2/ invading the tubing-casing annulus through minute seepages in the downhole injection equipment. This article is a discussion of the development and implementation of the procedures that led to the solution of this problem.
- Research Organization:
- Unocal Corp., Andrews, TX (US)
- OSTI ID:
- 6681589
- Journal Information:
- Oil Gas J.; (United States), Vol. 86:38
- Country of Publication:
- United States
- Language:
- English
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Related Subjects
36 MATERIALS SCIENCE
OIL WELLS
CARBON DIOXIDE INJECTION
PLASTICS
SURFACE COATING
WELL CASINGS
CORROSION PROTECTION
WELL INJECTION EQUIPMENT
BOREHOLES
ENHANCED RECOVERY
FIELD TESTS
IMPLEMENTATION
INJECTION WELLS
TECHNOLOGY ASSESSMENT
TEXAS
CAVITIES
DEPOSITION
EQUIPMENT
FEDERAL REGION VI
FIELD PRODUCTION EQUIPMENT
FLUID INJECTION
MATERIALS
MISCIBLE-PHASE DISPLACEMENT
NORTH AMERICA
PETROCHEMICALS
PETROLEUM PRODUCTS
RECOVERY
SYNTHETIC MATERIALS
TESTING
USA
WELLS
020300* - Petroleum- Drilling & Production
022000 - Petroleum- Transport
Handling
& Storage
360604 - Materials- Corrosion
Erosion
& Degradation