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Produced Water White Paper 45 resulted in incremental profits of $1.7-2.3 million over a two-year period. Green et al. (2001) report that following a series of gel treatments at four Kansas wells, which cost $14,000 to $18,000 per well, including polymer and well servicing costs, total oil production increased by about 30 barrels per day (bpd) while water production dropped by about 1,000 bpd. Lifting costs associated with the lower fluid volume were reduced about $300/month/well. With less stress on the lifting equipment, well servicing costs were also reduced about $2,400/year/well. Through mid-2000, about 37,500 bbl of incremental oil were economically recovered, representing about $1.60 per incremental bbl to date — and several years of production is still anticipated. The gel polymer treatments extended the lease economic life at least seven years. 5.1.2 Options for Keeping Water from Getting to the Surface Lifting water to the surface represents a substantial expense for operators. The process of lifting and managing the water at the surface puts the water in a location where it can harm the land surface and surface or ground water resources. A variety of technologies have been developed that attempt to manage water either in the well bore itself or at a remote location like the sea floor. Although these technologies do not minimize the volume of water entering the well, they do minimize the volume of water that comes to the surface. Thus, they are also included under the water minimization discussion in this chapter. 5.1.2.1 Dual Completion Wells Oil production can decline in a well because water forms a cone around the production perforations, limiting the volume of oil that can be produced. This situation can be reversed and controlled by completing the well with two separate tubing strings and pumps. The primary completion is made at a depth corresponding to strong oil production, and a secondary completion is made lower in the interval, at a depth with strong water production. The two completions are separated by a packer. The oil collected above the packer is produced to the surface, and the water collected below the packer is injected into a lower formation (Shirman and Wojtanowicz 2002; Wojtanowicz et al. 1999). This technology has also been called a downhole water sink. In another version of the process, the water can be separately produced to the surface for management there. Swisher (2000) reports on the performance of a dual-completion well compared to three wells with conventional completions in a north Louisiana field. Although the dual- completion well cost about twice as much to install, it took the same or fewer number of months to reach payout as the other wells. At payout, it was producing 55 bpd of oil compared to about 16 bpd from the other three wells. The net monthly earnings at payout for the dual completion well were nearly $26,000 compared to $5,000 to $8,000 for the other wells. Wojtanowicz (2003) offers some additional examples from more complicated geological settings.PDF Image | Produced Water from Production of Crude Oil
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