An Amphiphilic Flow Pattern Regulator for Oil-Based Drilling Fluids Used in Ultra-High Temperature Deep Wells
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摘要: 深井及超深井钻探过程中，油基钻井液在超高温且长时循环工况下易出现切力衰减、悬浮性能不足等流变性恶化问题，进而导致重晶石沉降、卡钻、井塌等复杂情况或事故。基于此，以妥尔油脂肪酸、脂肪烷基多胺和马来酸酐为原料，通过高温酰胺化反应制备出一种抗超高温的两亲性低聚物类流型调节剂，并对其流变调节性能和机理进行了详细探究。实验结果表明，该流型调节剂可显著改善油基钻井液的流变性与沉降稳定性；230 ℃下，0.5% 的流型调节剂可使油包水乳液动切力从 0.5 Pa 提升至 4.5 Pa，破乳电压由 323 V 增至 509 V；油基钻井液体系动切力从 6.5 Pa 提高至 22.5 Pa，破乳电压由 1014 V 升至 1315 V。现场井浆经热滚 1 d并恒温静置 5 d后，该流型调节剂仍可使钻井液保持良好的切力、沉降稳定性和乳液稳定性，为抗超高温油基钻井液体系研发提供了技术参考。Abstract: In deep and ultra-deep well drilling, after long period of circulation at ultra-high temperatures, oil-based drilling fluids will experience rheology deterioration problems, such as gel or suspending capacity decline, a causative factor for barite sag, stuck pipe and wellbore collapse etc. To deal with this problem, an ultra-high temperature amphiphilic oligomer flow pattern modifier was developed through high temperature amidation reaction with raw materials such as tall oil fatty acids, fatty alkyl polyamines and maleic anhydride. Laboratory experiments were conducted to carefully investigate the performance and mechanisms of the oligomer flow pattern modifier, and the experimental results show that the oligomer flow pattern modifier can be used to significantly improve the rheology and settling stability of oil-based drilling fluids. At 230 ℃, 0.5% oligomer flow pattern modifier can increase the yield value of a water-in-oil emulsion from 0.5 Pa to 4.5 Pa, and the emulsion stability voltage from 323 V to 509 V. It can increase the yield value of an oil-based drilling fluid from 6.5 Pa to 22.5 Pa, and the emulsion stability voltage from 1,014 V to 1,315 V. A mud sample was taken from a well, it was first hot rolled for 1 d, and then allowed for standing for 5 d. The mud sample was then treated with the oligomer flow pattern modifier, and it still acquired good gel strengths, settling stability and emulsion stability. This oligomer flow pattern modifier provides a technical reference for the development of ultra-high temperature oil-based drilling fluid.
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表 1 不同流型调节剂加量下乳液性能变化
流型
调节剂/%条件 AV/
mPa·sPV/
mPa·sYP/
PaGel/
Pa/PaES/
V0 老化前 11.0 10.0 1.0 0.5/0.5 324 230 ℃、16 h 18.5 18.0 0.5 0.5/1.0 323 0.2 老化前 15.0 11.0 4.0 2.5/4.5 470 230 ℃、16 h 24.0 22.0 2.0 0.5/1.5 291 0.5 老化前 19.0 14.0 5.0 4.0/6.5 697 230 ℃、16 h 31.5 27.0 4.5 3.5/10.5 509 0.8 老化前 20.5 16.0 4.5 3.5/5.0 824 230 ℃、16 h 23.5 21.5 2.0 0.5/3.0 323 
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表 2 不同流型调节剂加量下钻井液的性能
流型调节剂/% 条件 AV/
mPa·sPV/
mPa·sYP/
PaGel/
Pa/PaES/
V沉降情况 0 老化前 38.0 32.5 5.5 3.5/5.0 865 无 230 ℃老化16 h 51.5 45.0 6.5 3.0/8.0 1014 软沉，易搅动 230 ℃恒温静置3 d 45.5 42.0 3.5 3.5/8.0 1013 玻璃棒不到底，硬沉，不易搅动 230 ℃恒温静置5 d 44.0 43.0 1.0 2.0/5.0 848 玻璃棒不到底，硬沉，不易搅动 0.5 老化前 70.5 46.0 24.5 10.0/14.0 1472 无 230 ℃老化16 h 89.5 67.0 22.5 8.5/22.5 1315 无沉降，易搅动 230 ℃恒温静置3 d 50.5 44.5 6.0 4.5/9.5 1180 玻璃棒可触底，软沉，易搅动 230 ℃恒温静置5 d 41.0 38.0 3.0 2.5/5.5 901 玻璃棒可触底，软沉，易搅动 1.0 老化前 60.5 46.0 14.5 6.5/9.5 959 无 230 ℃老化16 h 67.0 59.0 8.0 5.0/11.5 1001 无沉降，易搅动 230 ℃恒温静置3 d 47.5 42.5 5.0 4.0/8.5 1507 玻璃棒可触底，软沉，易搅动 230 ℃恒温静置5 d 40.5 38.5 2.0 2.5/5.0 1255 玻璃棒可触底，软沉，易搅动
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表 3 流型调节剂加量对现场井浆长效稳定性的影响
流型调节剂/
%实验
条件AV/
mPa·sPV/
mPa·sYP/
PaGel/
Pa/PaES/
V沉降情况 0 老化前 59.5 54 5.5 2.5/3.5 745 - 200 ℃老化1 d 55.0 53 2.0 2.0/3.0 644 - 200 ℃恒温静置3 d 54.0 49 5.0 2.0/3.0 842 玻璃棒不到底，约6 cm软沉，搅拌阻力较大 2 老化前 68.5 55 13.5 7.0/8.0 1266 - 200 ℃老化1 d 58.5 53 5.5 3.5/4.5 808 - 200 ℃恒温静置3 d 58.5 50 8.5 3.5/4.5 1035 玻璃棒靠壁，约4 cm软沉，易搅拌 4 200 ℃老化1 d 51.5 45 6.5 2.5/3.5 791 - 200 ℃恒温静置3 d 63.5 55 8.5 4.0/5.0 808 玻璃棒触底靠壁，软沉，易搅拌 200 ℃恒温静置5 d 61.0 52 9.0 3.5/4.5 1133 玻璃棒触底靠壁，软沉，易搅拌 5 200 ℃老化1 d 52.0 46 6.0 3.0/4.0 902 - 200 ℃恒温静置3 d 65.0 54 11.0 4.0/5.0 862 玻璃棒触底不靠壁，软沉 200 ℃恒温静置5 d 61.0 50 11.0 4.5/5.5 1194 玻璃棒触底靠壁，软沉，易搅拌
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