TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractIn the moderate-permeability environment of the Hassi Messaoud field of central Algeria, proppant fracturing has significantly increased production, prolonging the economic life of many wells. Unfortunately, the logistics of mobilizing a workover rig to prepare the wellbore for stimulation has extended the stimulation cycle time. Additionally, many wells have tubular problems that require intervention such as squeeze cementing or tubular replacement before the stimulation process can begin. The availability of coiledtubing equipment in the field provides the means to stimulate the wells without a workover rig. Furthermore, when coupled with a mechanical isolation system, the coiled-tubing fracturing technique protects the production tubing from high treating pressure and abrasive proppants. In the past, the lack of a reliable isolation system has limited the success of these jobs.Reservoir conditions throughout the field allow low-rate stimulations but induce high bottomhole pressures, which make the use of conventional packers difficult. In many environments the bottomhole treating pressure creates differential pressures across the elements of a packer in excess of 9,000 psi. Several attempts to use existing packer technology yielded unsuccessful fracture treatments, and costly fishing operations were necessary to restore the wells to production. To provide an economical solution to the problems encountered by conventional mechanical packers, a new isolation system was designed. This paper provides case histories of several wells stimulated with coiled-tubing fracturing in the extreme environment of high-pressure, deep wells in the Hassi Messaoud field and examines the engineering challenges in developing a robust isolation system.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractMultilateral wells provide optimal recovery of reservoir pay and can become more prolific with stimulation or cleanout treatments. Downhole tools exist that index and allow the coiled tubing string to find and enter additional legs; however, they function using flow rate modulation. Any additional tool component beneath the multilateral tool that requires high pressure will suffer in performance because of the indexing multilateral tool. This technical paper addresses the performance of a new system that allows the indexing tool to find the lateral and then effectively treat the reservoir through the stimulation tool at the end. The entire cycle can be repeated for all laterals in the wellbore.The results of field tests using this multilateral jetting system were similar to what was seen in yard tests perform at test facilities in Rosharon TX. Field tests showed that operating parameters produced clear indications that the system was operating correctly. All legs were efficiently and effectively treated to improve well production. Additionally, this system reduced the number of trips into the well from three to one, resulting in a 50 % reduction of time at the client's well site.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractMultilateral wells provide optimal recovery of reservoir pay and can become more prolific with stimulation or cleanout treatments. Downhole tools exist that index and allow the coiled tubing string to find and enter additional legs; however, they function using flow rate modulation. Any additional tool component beneath the multilateral tool that requires high pressure will suffer in performance because of the indexing multilateral tool. This technical paper addresses the performance of a new system that allows the indexing tool to find the lateral and then effectively treat the reservoir through the stimulation tool at the end. The entire cycle can be repeated for all laterals in the wellbore.The results of field tests using this multilateral jetting system were similar to what was seen in yard tests perform at test facilities in Rosharon TX. Field tests showed that operating parameters produced clear indications that the system was operating correctly. All legs were efficiently and effectively treated to improve well production. Additionally, this system reduced the number of trips into the well from three to one, resulting in a 50 % reduction of time at the client's well site.
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