Wells are classified as High Pressure/High Temperature (HPHT) when BHT (Bottom Hole Temperature) exceeds 250°F (121°C).

Although cementing of all wells is very important and should follow a certain engineering methodology to ensure success, there are some differences related to cementing conditions and the consequences of failures of HPHT wells as compared to normal wells. This paper reviews those differences along with the specific methodology to design, execute and evaluate cementing operations in HPHT wells.

Success factors, such as accurate well data, BHT prediction, optimized fluids and job execution criteria are discussed.

Tools utilized to optimize factors affecting cementing HPHT wells are presented, such as temperature simulator, job design simulator, American Petroleum Institute (API) and specific laboratory testing, Right-Angle-Set cement slurry, mud removal, mixing energy, on-site QC (Quality Control) checks, contingency planning and post-job proper evaluation.

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