Gas Flow Potential Diagnostic Tools Result in a Successful Liner Cementing Job and $6,000 in Slurry Savings

Operator's Challenge

A west Texas operator was preparing to cement a liner in a high-profile well with TD below 15,000 ft. The operator expected gas flow to be a problem and had decided to incur the expense of rotating the liner. The operator solicited proposals from Halliburton and another service company. Halliburton's price per sack of cement was about half the other company's but the operator had favorable experience with the other service company on similar wells. Well specifications included setting a 5-in liner in a 6 ⅛-in hole. Liner top was at 11,650 ft Bottom of 7-in casing in the upper portion of the hole was at 12,000 ft. Pore pressure was 8,650 psi and BHST was 225ºF.

Halliburton's Solution

Halliburton entered the well parameters into the GASFLO™ program, which calculated the gas flow potential. Well data was also entered into the CJOBSIM™ cementing job simulator. The resulting customized slurry and job design was presented to the operator's project manager and engineering manager. The operator personnel immediately recognized that Halliburton's approach was tailored to the well conditions rather than to a "one solution fits all" approach. The slurry design consisted of Premium cement containing SSA-1™ silica flour, Halad®-413 additive, GasStop™ additive, SCR-100™ retarder, and CFR-3™ dispersant, mixed at 16.1 lb/gal. The ADC™ mixing system was used to mix the slurry into the MX-5000™ batch mixer. The result―the liner top held pressure with no gas leakage.

Economic Value Created

Not only did the operator save $6,000 on the cost of the slurry, significant economic value also was created because the operator did not need to contend with gas leakage.

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