Synergistic Effect of Thermally Stable Polymers for HPHT Brine-Based Drill-in Fluids
- Hui Zhou (Halliburton) | Kay A. Galindo (Halliburton) | Weibin Zha (Halliburton)
- Document ID
- Society of Petroleum Engineers
- SPE Middle East Oil & Gas Show and Conference, 6-9 March, Manama, Kingdom of Bahrain
- Publication Date
- Document Type
- Conference Paper
- 2017. Society of Petroleum Engineers
- 2.2 Installation and Completion Operations, 5.4 Improved and Enhanced Recovery, 2.6 Acidizing, 4.1 Processing Systems and Design, 5 Reservoir Desciption & Dynamics, 2.2.3 Fluid Loss Control, 4.1.2 Separation and Treating, 5.4.10 Microbial Methods, 1.6.9 Coring, Fishing, 2 Well completion, 4 Facilities Design, Construction and Operation, 1.6 Drilling Operations
- HP/HT, fluid loss control additives, drill-in fluids, viscosifiers, formation damage
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- 166 since 2007
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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.
|File Size||1 MB||Number of Pages||10|
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