Synthesis and Evaluation of Modified Sulfomethylated Phenolic Resin MSP-1
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摘要: 在分析磺甲基酚醛树脂应用现状和存在问题的基础上，从钻井液处理剂作用原理和分子结构设计的观点出发，在磺甲基酚醛树脂的分子结构上引入了吸附基团，成功地研制出了新型改性磺甲基酚醛树脂MSP-1。从室内评价结果来看，改性磺甲基酚醛树脂MSP-1在15%的盐水中降滤失效果与SMP-1相当，同时在30%盐水中有更好的降滤失效果，而且不必与SMK配伍评价，180 ℃老化后高温高压滤失量仅有17 mL；同时由于MSP-1含有强吸附基团，增加了酚醛树脂在膨润土上的吸附量，使得改性后的产品在15%盐水中基本不起泡，而且在钻井液中黏度效应较低，具有良好的推广应用前景。
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关键词:
- 磺甲基酚醛树脂SMP /
- 改性磺甲基酚醛树脂 MSP-1 /
- 高温高压滤失量 /
- 黏度效应
Abstract: This paper analyzes the status quo of the application and deficiency of the original sulfomethylated phenolic resin as a filtration reducer in water based drilling fluids. Based on the analysis, a new modified sulfomethylated phenolic resin, MSP-1, has been developed through molecular design to replace the old sulfomethylated phenolic resin. In the molecules of MSP-1 adsorption groups are introduced to render MSP-1 special functions to overcome the problems encountered in field use. Laboratory evaluation results show that in 15% brine drilling fluids, the performance of MSP-1 is comparable to the old sulfomethylated phenolic resin SMP-1, while in 30% brine drilling fluids, MSP-1 performs better than SMP-1. Without the use of the thinner SMK (a sulfomethylated tannin extract), MSP-1 alone can reduce the high temperature high pressure filtration rate of a 30% brine drilling fluid to only 17 mL after aging at 180 ℃. Since there are strong adsorption groups in the molecules of MSP-1, the amount of MSP-1 adsorbed onto the surfaces of clay particles is increased, almost eliminating the foaming effect of SMP-1 in 15% brine drilling fluids and greatly reducing the viscosity effect of MSP-1 in drilling fluids. These advantages of MSP-1 have rendered it good prospects for promotion and application. -
表 1 改性磺甲基酚醛树脂MSP-1的钻井液性能
评价配方
180 ℃、16 hAV/
mPa·sFLAPI/
mLFLHTHP/
mL起泡率/
%4%膨润土+4%评价土+
5%SMC+5%MSP-1+
15%NaCl+2.5%Na2CO332 3.2 23 6 4%膨润土+4%评价土+
5%SMC+5%MSP-1+
30%NaCl+2.5%Na2CO334 3.2 17 
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表 2 不同树脂在密度为1.5 g/cm3 KCl 聚磺钻井液中的性能（150 ℃）
树脂 实验条件 AV/
mPa·sPV/
mPa·sYP/
PaGel/
Pa/PaFLAPI/
mLFLHTHP/
mL4%MSP-1 室温 101.5 86 15.5 1.5/8 150 ℃、16 h 95.5 74 21.5 2.5/15 1.0 24 4%SMP-1 室温 92.5 71 21.5 1.5/10 150 ℃、16 h 92.0 68 24.0 5.0/22 1.5 68 4%JD-6 室温 96.0 75 21.0 3.0/12 150 ℃、16 h 96.0 75 21.0 3.5/18 1.2 39
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表 3 在密度1.5 g/cm3 30%含盐钻井液中的性能（150 ℃）
树脂 实验条件 AV/
mPa·sPV/
mPa·sYP/
PaGel/
Pa/PaFLAPI/
mLFLHTHP/
mL5%MSP-1 室温 78.0 86 11.0 1.5/7.5 150 ℃、16 h 105.0 83 22.0 3.5/14.0 1.6 13.5/2 5%SMP-2 室温 64.0 55 9.0 1.0/5.0 150 ℃、16 h 127.5 89 38.5 8.5/31.0 0.8 38.0/4 5%JD-6 室温 66.0 56 10.0 1.5/7.5 150 ℃、16 h 113.5 86 27.5 5.5/21.0 1.8 25.0/4
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表 4 不同树脂在高温高密度钻井液中 抗膨润土污染的性能（180 ℃）
添加剂 AV/
mPa·sPV/
mPa·sYP/
PaGel/
Pa/PaFLHTHP/
mL15%MSP-1 45.0 40 15.0 1.50/3.5 16.0 15%MSP-1+5%膨润土 50.0 44 7.0 2.00/5.0 13.0 15%MSP-1+7%膨润土 61.0 53 8.0 2.25/6.0 12.0 15%JD-6 48.0 41 17.0 2.50/7.0 7.2 15%JD-6+1%膨润土 53.0 44 9.0 2.50/7.5 17.0 15%JD-6+3%膨润土 56.5 46 10.5 3.00/8.5 23.0 15%JD-6+7%膨润土 68.0 57 11.0 3.00/9.0 25.0 15%SMP-1 101.0 69 32.0 14.00/47.5 9.8 15%SMP-2 80.0 61 19.0 6.00/31.5 8.8 注：高温高压滤失量实验条件为180 ℃、压差3.5 MPa。
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表 5 120 ℃下加入MSP-1的钻井液性能及对比
配方 实验
条件AV/
mPa·sPV/
mPa·sYP/
PaGel/
Pa/PaFLAPI/
mLFLHTHP/
mL井浆 老化前 35.0 28 7.0 2.0/17.0 4.6 老化后 34.5 29 5.5 3.0/19.0 6.0 19.6/3 井浆+
5%MSP-1老化前 38.0 30 8.0 2.5/14.5 3.4 老化后 31.5 24 7.5 4.0/21.0 3.8 12.0/2 井浆+
5%SMP-1老化前 30.0 22 8.0 2.5/17.0 5.8 老化后 25.0 15 10.0 4.0/13.0 9.8 29.0/6 井浆+
5%JD-6老化前 35.0 27 8.0 2.0/15.0 3.4 老化后 28.5 22 6.5 2.5/21.0 3.8 11.8/2 注：实验条件为120 ℃老化16 h。
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表 6 在150 ℃条件下加入MSP-1的钻井液性能及对比
配方 实验
条件PV/
mPa·sYP/
PaGel/
Pa/PaFLAPI/
mLFLHTHP/
mL泥饼厚
度/mm井浆+3%
SPNH老化前 37 9.0 2.5/23.0 2.4 老化后 21 7.5 1.0/11.0 2.6 6.2 1.5 井浆+3%
SPNH+
5%MSP-1老化前 37 11.5 5.5/28.0 1.8 老化后 23 4.5 2.0/7.5 1.8 5.8 1.5 井浆+3%
SPNH+
5%SMP-1老化前 30 8.5 1.0/17.5 2.8 老化后 22 3.5 0.5/7.0 2.0 6.8 2.5 井浆+3%
SPNH+
5%JD-6老化前 37 10.0 2.0/20.0 2.0 老化后 22 3.5 1.5/8.0 1.4 10.4 3.0 注：实验条件为150 ℃老化16 h。
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