Development and Application of Micro-Nano Organic Plugging Agent for Ultra-Deep Well Drilling Fluids
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摘要: 以有机材料为水解单体，AMPS、DMAA和BA为聚合单体，通过预水解反应和自由基聚合反应两步法制备了一种抗超高温微纳米有机封堵剂（TSF）。通过热重分析显示，TSF的初始热分解温度为240℃，热稳定性优异；220℃老化前后粒径维持在342～825 nm之间，具有分散稳定性；玻璃化转变温度为192℃，能够由玻璃态转变为黏弹橡胶态，具有形变封堵性和黏结固壁性。TSF加量为4%时，220℃老化16 h后，可使钻井液基浆高温高压滤失量降低43.1%，对5 μm和10 μm陶瓷砂盘的高温高压滤失量分别降低37.1%和34.5%，表明TSF封堵降滤失效果优异；在220℃高温下无H2S气体产生，表明TSF在超高温下具有较高的安全性；220℃老化后基浆泥饼渗透率降低50.8%，黏结固壁作用可将岩心柱抗压强度提升12.6～17倍，表明TSF通过自适应充填来提高其对超深井地层孔缝的封堵及固壁性能，并在特深井A中成功应用。Abstract: An ultra-high temperature micro-nano organic plugging agent TSF is developed through a two-step reaction (pre-hydrolysis followed by free radical polymerization) with organic hydrolysable monomers and polymerization monomers such as AMPS, DMAA and BA. Thermogravimetric (TG) analysis shows that the initial thermal decomposition temperature of TSF is 240℃, indicating that TSF has excellent thermal stability. Before and after aging at 220℃, the particle sizes of TSF remain between 342 nm and 825 nm, indicating that TSF has dispersion stability. TSF has a glass transition temperature of 192℃, and can transform from the glassy state to the viscoelastic rubbery state, meaning that it has both plugging capacity through deformation and borehole wall strengthening capacity through adhesion. At 4% TSF treatment, a base drilling fluid, after aging at 220℃ for 16 hours, can have its HTHP filter loss reduced by 43.1%, and have its HTHP filter losses tested on 5 μm and 10 μm ceramic sand discs reduced by 37.1% and 34.5%, respectively. These data show that TSF has excellent filtration control capacity through plugging. At 220℃, TSF produces no H2S, indicating that TSF has good safety performance at ultra-high temperatures. After aging at 220℃, the drilling fluid produced mud cakes whose permeability was reduced by 50.8%. Borehole wall strengthening effect through adhesion of TSF can increase the compressive strengths of core columns by 12.6-17 times, showing that TSF can enhance its ability to plug the fractures in the formations in ultra-deep wells through self-adaptability and to strengthen the borehole wall. These characteristics of TSF have been successfully applied in drilling the ultra-deep well A.
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表 1 不同封堵剂TSF加量对钻井液基浆性能的影响
TSF/
%实验条件 AV/
mPa·sPV/
mPa·sYP/
PaFLAPI/
mL0 老化前 7.5 6.0 1.5 23.4 180℃、16 h 10.5 8.0 2.5 45.0 200℃、16 h 10.0 8.5 1.5 56.0 220℃、16 h 9.0 8.0 1.0 65.0 2 老化前 8.0 6.5 1.5 18.4 180℃、16 h 10.0 8.0 2.0 35.8 200℃、16 h 10.0 9.0 1.0 45.0 220℃、16 h 9.0 7.5 1.5 56.4 4 老化前 8.5 7.0 1.5 14.6 180℃、16 h 11.0 9.0 2.0 25.6 200℃、16 h 12.0 10.0 2.0 26.8 220℃、16 h 10.0 9.0 1.0 30.4 6 老化前 9.5 7.5 2.0 12.3 180℃、16 h 12.0 10.0 2.0 22.3 200℃、16 h 13.5 11.0 2.5 23.1 220℃、16 h 11.0 9.5 1.5 30.3 
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表 2 A井使用井段钻井液性能
井深/
mT/
℃ρ/
g·cm−3FV/
sPV/
mPa·sYP/
PaGel/
Pa/PaFLHTHP/
mL7858 145 1.45 44 17 5.0 2.0/8.0 11.2 7946 150 1.45 45 17 7.0 2.5/10.0 12.0 8057 155 1.45 42 17 8.0 3.0/11.0 12.0 8185 165 1.45 41 22 6.5 3.0/11.0 10.4 8265 165 1.45 42 20 5.5 2.5/9.0 10.0 8409 170 1.48 39 20 6.0 4.5/13.0 8.4 8512 170 1.52 56 22 8.0 3.5/10.5 7.8 8720 175 1.52 45 23 12.5 6.5/12.5 8.0 8899 178 1.45 40 20 4.0 2.0/5.0 9.0 8996 180 1.45 40 20 6.5 2.0/6.0 13.2 9100 180 1.45 41 24 8.0 3.0/5.0 14.8 9201 180 1.45 40 19 6.0 2.0/5.5 14.0 9340 185 1.45 40 24 6.0 2.0/5.0 12.0 9501 185 1.49 44 29 10.0 3.5/6.5 8.9 9755 190 1.49 43 28 10.0 3.0/6.0 11.8 9840 190 1.49 42 25 9.0 3.0/6.0 11.4 9900 195 1.49 41 20 9.0 2.5/5.5 11.0 9949 195 1.42 41 21 8.0 2.0/5.0 12.0 9968 198 1.42 44 26 8.0 2.0/5.0 11.0 9977 198 1.42 44 26 8.0 2.0/5.0 11.0 10 006 200 1.38 50 22 9.0 2.5/4.0 12.0
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