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Abstract This paper discusses two high-temperature-resistant polymers (Polymers A and B) that have been developed as thermally stable, dual-functional viscosifiers and fluid-loss additives. Polymer A was designed for monovalent brines, while Polymer B works for divalent brines. These polymers enable the formulation of brine-based drill-in fluids that are stable at high to ultra-high temperatures, which is a significant improvement when compared to conventional biopolymer-based drill-in fluids. When combined, the two polymers work synergistically to further reduce fluid loss in monovalent brines. The two thermally stable polymers were readily incorporated into various drill-in fluid formulations containing either monovalent or divalent brines over a broad range of densities. These drill-in fluids exhibited exceptional thermal stability and showed no stratification after static aging at 400°F for three days or at 375°F for seven days. A minimal change in fluid behavior was observed when comparing the rheological properties of the un-aged and aged samples. The samples provided excellent fluid-loss control, even after aging. A synergistic effect was observed between Polymers A and B when used in monovalent brines to further reduce the HPHT fluid loss with no negative impact on fluid rheology. Core flow tests showed that both fluids were non-damaging after acid-breaker treatment. It is anticipated that these polymers will extend the envelope to which water-based drill-in fluids can be successfully used to drill high- and ultra-high-temperature reservoirs. Recent successful field trial of the divalent brine-based fluid as a testing fluid further proved the robustness of these fluids for these reservoirs.
- Europe (1.00)
- North America > United States > Texas (0.29)
- North America > United States > Louisiana (0.29)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > HP/HT reservoirs (1.00)
Abstract Novel polymers have been designed and developed as thermally stable dual function viscosifiers and fluid-loss additives for high density brine-based drill-in fluids. These polymers allow for the formulation of clay- and biopolymer-free drill-in fluids that are stable at temperatures up to 450°F. This is a significant improvement compared to conventional drill-in fluids, which use biopolymers and have temperature limits of 300°F. Clay-free drill-in fluid samples were prepared in 14.2-lbm/gal CaBr2 brine and conditioned by hot rolling at 150°F for 16 hours, followed by static aging at 400°F for 72 hours. The samples prepared with the novel polymers show no color change or stratification after static aging. There was minimal change upon comparison of the rheological properties of the nonaged and aged samples. The samples provided excellent fluid-loss control even after aging, with a measured high-pressure/high-temperature (HP/HT) fluid loss less than 10 mL after 30 minutes at 350°F. This is in stark contrast to biopolymer-containing samples in which solids settling and dark coloration were observed after static aging at 300°F for only 16 hours. This paper presents full testing results of the new HP/HT drill-in fluids, including formulation, fluid properties, and formation damage assessment.
- Asia (0.93)
- North America > United States > Louisiana (0.30)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > HP/HT reservoirs (1.00)