Case Study: Mississippi

21,000 ft deep formation
3.5” tubing restricted rate
30% H2S corrosive environment
330° f high temperatures



The operator was in chapter 7 bankruptcy when Ely came on the job, and the simple statistics of the well promised a very challenging treatment. The formation was nearly four miles deep and extremely hot, and the high hydrogen sulphide content (30%) created a dangerous and corrosive environment. To complicate matters, the well had already been completed with 3.5” tubing, causing high friction pressure.

On the bright side, the local infrastructure allowed for the processing of sulphur from existing hydrogen sulphide, and successful wells in the area made more money from this sulphur than from the hydrocarbons.

Our data and our experience with the play told us that only a vast, complex fracture system that opened up ample surface area in the formation would yield the results we needed. We pulled out all the stops.

The well was treated with complex fluids containing bauxite at pressures approaching 19,000 PSI, and immediately began producing 15 million cubic feet per day. Successfully treating this type of well brought the operator out of bankruptcy, and we spent several years treating wells in the area with consistent results.