Advanced Squeeze Technology Turns P&A Candidate into a $230,000 Per Year Producer

Operator's Challenge

A New Mexico operator's well was producing 15 BOPD until uphole casing leaks began producing enough water to kill the well. Holes were determined to be between 3,500 ft and 3,600 ft. Injection rates were 2.8 bbl/min at 600 psi. Squeeze treatments using class C cement and Flo-Chek® service squeezes were attempted but were not successful. The operator shut the well in for 13 months before making more attempts. The operator decided that if another squeeze were unsuccessful, the well would be abandoned. The void behind the pipe was so extensive that normal squeeze procedures would be ineffective.

Halliburton's Solution

Halliburton reviewed the situation with the operator and determined that foam cement was the best option. The foam squeeze procedure included the following steps: set an EZ Drill® bridge plug at 3,450 ft and an EZ Drill poppit type packer at 3,150 ft, establish circulation with 20 bbl of Super Flush™ 102 fluid, pump a 5 bbl fresh water spacer, and mix and pump 150 sk of foam cement at 9 to 10 lb/gal. When cement is evident at the surface, shut in the annulus, pump cement away, and displace cement. Finally, sting out of the tool, reverse out as required, and allow the cement to set overnight. On drillout the next day, injection rate had been reduced to ¼ bbl/min at 1,300 psi. This made the well economical, but the job was completed with a 20 sk Micro Matrix™ cement block squeeze. An 800 psi standing pressure was achieved, and the well was placed back on production.

Economic Value Created

This squeeze treatment was to have been the operator's last attempt before abandoning the well. Now, production is 35 BOPD―worth over $230,000 per year―and almost no water. Counting the cost of the Halliburton service, total economic value to the operator in the first year was over $200,000.