High-performance Brine-based Drilling Fluid System for Extended-reach Horizontal Wells
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摘要: 针对大位移井钻井过程中水基钻井液井眼清洁困难、摩阻扭矩高、井壁稳定性差的技术瓶颈，研制了一套高性能卤水基钻井液体系。该体系基于氯化钾-甲酸盐复合卤水，通过引入自主研发的星型聚胺抑制剂HIB和纳米复合减阻剂SLIP，并优化流型调节与多级封堵技术，实现了抑制、润滑、携岩及稳定性能的协同提升。与常规KCl聚合物体系及商业聚胺体系、润滑剂的全面对比表明：HIB通过“吸附-包覆-疏水”机制，其抑制性（岩屑滚动回收率为93.6%，16 h线性膨胀率为1.0%）显著优于常规聚胺抑制剂；SLIP通过“微球滚动-吸附成膜”机制，极压润滑系数（0.064）及抗磨承载能力（10 kg）优于现有润滑剂。室内评价表明，该体系经150 ℃高温老化后动塑比不小于0.5 Pa/mPa·s，API滤失量小于4 mL，砂床承压大于 MPa，抗污染能力强，岩心渗透率恢复大于86.3%。在国内多个海域区块12口大位移井的应用表明，起下钻摩阻降低30%以上，复杂事故率下降65%，为大位移井安全高效钻井提供了可靠的技术选择。Abstract: To address the technical bottlenecks of difficult hole cleaning, high friction and torque, and poor wellbore stability in water-based drilling fluids during extended-reach well drilling, a high-performance brine-based drilling fluid system was developed. Based on a potassium chloride-formate composite brine, the system incorporated the self-developed star-shaped polyamine inhibitor HIB and nano-composite friction reducer SLIP, and optimized flow-pattern regulation and multi-stage plugging technologies, achieving synergistic improvements in inhibition, lubrication, cuttings-carrying capacity, and stability performance. Comprehensive comparisons with conventional KCl polymer systems, commercial polyamine systems, and lubricants showed that HIB exhibited significantly better inhibition than conventional polyamine inhibitors via an “adsorption–coating–hydrophobicity” mechanism, with a cuttings rolling recovery rate of 93.6% and a 16 h linear swelling rate of 1.0%. SLIP outperformed existing lubricants through a “microsphere rolling–adsorption film-forming” mechanism, with an extreme-pressure lubrication coefficient of 0.064 and an anti-wear load-bearing capacity of 10 kg. Laboratory evaluations showed that, after high-temperature aging at 150 ℃, the system maintained a yield point/plastic viscosity ratio of ≥0.5, an API filtration loss of <4 mL, a sand-bed pressure-bearing capacity of >7 MPa, strong contamination resistance, and a core permeability recovery value of >86.3%. Field applications in 12 extended-reach wells in several offshore blocks in China demonstrated that tripping friction was reduced by more than 30% and the rate of complex incidents decreased by 65%, providing a reliable technical option for the safe and efficient drilling of extended-reach wells.
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表 1 不同体系处理后的Zeta电位与接触角
处理条件 ζ/mV 接触角/（°） 空白（去离子水） −32.4 18 7% KCl溶液 −18.7 25 3%HUIB(市售) −5.2 43 1.5%HIB(自制) +8.1 72 
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表 2 不同润滑剂纯剂的润滑性能对比（150 ℃老化后）
润滑剂 极压润滑系数 抗磨承载/kg 钢球磨痕大小/mm 去离子水 0.320 0 0.85 PF-LUBE 0.032 6 0.62 LUBE-167 0.011 4 0.58 SLIP 0.005 16 0.32
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表 3 不同体系高温高压流变性能对比（150 ℃、3.5 MPa）
配方 老化
条件模拟环空的
中等剪切速率
φ100读数模拟沉沙池的
低剪切速率
φ3读数低剪切黏度
保持率/%A 老化前 15.5 4.2 − 150 ℃、16 h 14.5 3.9 92.9 B 老化前 12.0 2.5 − 150 ℃、16 h 11.0 1.8 72.0 C 老化前 13.8 3.2 − 150 ℃、16 h 13.0 2.6 81.3
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表 4 不同体系裂缝封堵承压能力对比
配方 裂缝宽度/
mm承压能力/
MPa封堵层厚度/
mm滤液侵入深度/
mmA 0.5 >8.0 1.5 2.0 1.0 7.8 2.0 3.5 1.5 7.7 2.5 5.0 2.0 7.6 3.0 6.5 B 0.5 6.5 0.8 8.0 1.0 5.8 1.0 12.0 1.5 4.2 − 突破 2.0 − − 突破 C 0.5 7.2 1.2 4.0 1.0 6.8 1.5 6.0 1.5 6.5 2.0 8.5 2.0 5.5 2.2 15.0 注：① 采用裂缝封堵仪测试，裂缝宽度0.5～2.0 mm，测试压差逐级升高，直至发生突破或达到仪器量程上限（8.0 MPa）；② 封堵层厚度为稳定承压后裂缝内形成的封堵带厚度；③ 滤液侵入深度为封堵完成后裂缝壁面滤液渗透距离；④ “突破”表示在该裂缝宽度下体系无法形成有效封堵，承压能力低于起始测试压力（2.0 MPa）；⑤ “—”表示未测试或无法形成有效封堵层。
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表 5 不同钻井液体系流变与热稳定性能
配方 条件 PV/
mPa·sYP/
PaYP/PV/
Pa/mPa·sFLAPI/
mLA 滚前 27.0 11.5 0.43 3.6 150 ℃、16 h 24.0 12.0 0.50 3.2 B 滚前 20.0 8.0 0.40 4.4 150 ℃、16 h 21.0 7.0 0.35 5.0 C 滚前 24.0 11.0 0.46 3.8 150 ℃、16 h 22.0 10.0 0.45 4.2
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表 6 不同抑制剂对页岩的抑制性能对比
配方 抑制剂/% 滚动回收率/% 16 h线性膨胀率/% 空白(清水) − 70.6 8.5 A 1.5 93.6 1.0 B 3.0 91.1 2.0 C 7.0 88.2 3.5
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表 7 不同钻井液体系润滑性能对比（150 ℃老化后）
配方 极压润滑系数 抗磨承载/kg 四球磨斑直径/mm A 0.064 10 0.805 B 0.115 5 0.847 C 0.088 7 1.117
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表 8 不同钻井液体系抗污染性能对比（150 ℃老化后）
配方 污染物 AV/
mPa·sYP/PV/
Pa/mPa·sFLAPI/
mL极压润滑
系数A 无 36.0 0.50 3.2 0.064 20%水 33.0 0.48 3.5 0.072 10%NaCl 36.0 0.45 3.6 0.078 1%CaCl2 34.0 0.42 3.8 0.082 20%劣质土 54.0 0.43 4.2 0.096 B 无 28.0 0.33 5.0 0.115 20%劣质土 58.0 0.25 8.5 0.180 C 无 32.0 0.45 4.2 0.088 20%劣质土 60.0 0.30 6.8 0.145
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