Drilling Fluid Technology for Ultra-High Temperature Fractured Bedrock Reservoirs
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摘要: 昆特依气田位于柴达木盆地北缘昆特依凹陷潜伏I号构造，其基岩储层裂缝发育且含风化壳，地层中存在薄弱层段与天然漏失通道，同时面临超高温（约200 ℃）和异常高压（压力系数达1.63）的复杂地质条件。为解决超高温基岩地层钻井液存在的泥饼虚厚、承压能力低、易漏失等难题，通过协同设计核心处理剂，优化出超高温强封堵、防漏失钻井液体系：以 “磺酸盐共聚物SC-200+羧羟基烷烯共聚物Redu240” 构建抗高温胶体稳定骨架，结合 “纳米SiO2+白沥青NFA-25” 实现多尺度裂缝封堵，达成 “滤失控制+裂缝封堵+井壁稳定” 一体化功能。实验证实，该体系耐温达200 ℃，老化后表观黏度、塑性黏度变化率均小于3%，高温高压滤失量小于12 mL，可抗 15%NaCl 污染，同时老化后砂床滤失量仅4.2 mL，封堵滤失量8.6 mL，具备优异封堵裂缝能力与地层承压能力，对于超高温裂缝性地层钻井中防漏失与井壁稳定效果明显。现场应用于K2-3井（井深7150 m，井底温度199.5 ℃），基岩段实现“零漏失”作业，全井段未发生任何因井漏或钻井液性能引发的井下复杂情况，复杂时效为0，显著减少了因漏失导致的非生产时间，为该地区超深井安全高效钻井提供了可靠的技术支撑。Abstract: The Kunteyi gas field is located in the #1 buried structure of the Kunteyi sag on the northern margin of the Qaidam Basin, the bedrock reservoirs of which are developed with fractures and have a weathering crust, and the formations of which have weak segments and natural channels for mud losses, together with complex geological conditions such as ultra-high temperatures (approximately 200 ℃) and abnormal high pressures (pressure coefficient up to 1.63). To address the drilling fluid challenges confronted in drilling ultra-high temperature bedrock reservoir formations, such as thick and loose mud cakes, low pressure-bearing capacity and ease of lost circulation etc., an ultra-high temperature drilling fluid with high plugging capacity for the prevention of lost circulation was developed through synergistic design of core additives. In the drilling fluid “SC-200+Redu240” are used to construct a high-temperature colloidally stable framework, and “nano-silica + white asphalt NFA-25” used to achieve plugging of the multiscale fractures and finally an integrated function of “filtration control + fracture plugging + wellbore stability” is realized. Experimental results confirm that this drilling fluid functions normally at temperatures up to 200 ℃. After aging, the rates of change in the apparent viscosity and plastic viscosity are both less than 3%, the high-temperature high-pressure filtration rate is less than 12 mL, and the drilling fluid can resist contamination by 15%NaCl. Additionally, the sand-bed filtration rate of the drilling fluid after aging is only 4.2 mL, and the filtration rate for fracture plugging is 8.6 mL, indicating that the drilling fluid has excellent fracture plugging capacity and formation pressure-bearing capacity. This drilling fluid exhibits remarkable effects in lost circulation control and wellbore stabilization in drilling ultra-high temperature fractured formations. In field application of this drilling fluid in the well K2-3 (well depth 7170 m, and bottomhole temperature 199.5 ℃), “zero mud loss” was achieved in drilling the bedrock section, and no downhole complex situation caused by lost circulation or drilling fluid properties occurred throughout the whole drilling process, with a complex time efficiency of zero. The application of this drilling fluid technology significantly reduced the non-productive time due to lost circulation, providing reliable technical support for the safe and efficient drilling of ultra-deep wells in this area.
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Key words:
- Bedrock /
- Fracture /
- Ultra-high temperature /
- Lost circulation prevention /
- Plugging
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表 1 不同降滤失剂复配比例对抗超高温有机盐钻井液性能的影响
SC-200/% Redu240/% 实验条件 AV/mPa·s PV/mPa·s YP/Pa FLAPI/mL FLHTHP/mL 0 0 老化前 30.0 22.0 8.0 3.8 210 ℃、16 h 24.5 19 5.5 16.0 全滤失 2 2 老化前 82.0 70.0 12.0 1.8 210 ℃、16 h 71.0 60.0 11.0 1.4 24.6 2 3 老化前 94.0 80.0 14.0 1.6 210 ℃、16 h 83.0 71.0 12.0 1.5 20.4 2 4 老化前 108.0 90.0 18.0 1.3 210 ℃、16 h 99.0 84.0 15.0 1.2 16.2 3 2 老化前 93.0 78.0 15.0 1.6 210 ℃、16 h 82.0 69.0 13.0 1.3 22.4 3 3 老化前 109.0 92.0 17.0 1.1 210 ℃、16 h 101.0 86.0 15.0 0.9 17.8 3 4 老化前 119.0 99.0 20.0 0.8 210 ℃、16 h 110.0 93.0 17.0 0.4 14.8 注：基浆：300 mL 清水+0.3%Na2CO3+2%Visco1+30%Weigh2+2%IND30+1.2%胺基抑制剂WX+2%RH220+2%PGCS-1+0.3%抗氧化剂；FLHTHP在190 ℃测定。 
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表 2 不同纳米SiO2与NFA-25复配比例对抗超高温有机盐钻井液性能的影响
配方 纳米SiO2/% NFA-25/% 实验条件 AV/mPa·s PV/mPa·s YP/Pa FLHTHP/mL 1# 2 3 老化前 112.5 92.0 20.5 12.6 210 ℃、16 h 105.0 86.5 18.5 13.8 2# 2 4 老化前 116.0 93.0 23.0 11.8 210 ℃、16 h 111.5 89.0 22.5 13.2 3# 3 3 老化前 118.0 95.0 23.0 11.2 210 ℃、16 h 114.0 91.0 23.0 12.4 4# 3 4 老化前 122.0 96.0 26.0 10.0 210 ℃、16 h 118.5 93.2 24.5 10.5 5# 4 3 老化前 120.5 95.5 25.0 10.8 210 ℃、16 h 115.5 92.0 23.5 11.6 6# 4 4 老化前 125.0 99.5 25.5 10.6 210 ℃、16 h 123.0 99.0 24.0 11.2 注：0#：基浆+3%SC-200+4%Redu240；FLHTHP在190 ℃测定。
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表 3 优化后钻井液的抗NaCl污染评价（210 ℃、16 h）
NaCl/% AV/mPa·s PV/mPa·s YP/Pa FLHTHP/mL 性能变化特征 0（空白） 117.7 93.2 24.5 10.5 基准状态，性能稳定 5 123.0 97.5 25.5 11.2 黏度微升（+3.8%），滤失量增幅≤6.7% 10 128.0 101.0 27.0 12.0 黏度可控（+8.1%），滤失量仍≤15 mL 15 135.0 106.5 28.5 13.8 黏度超阈值（+13.9%），滤失量仍满足要求 注：FLHTHP在190 ℃测定。
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表 4 优化前后钻井液体系的高温砂床实验与封堵性能评价
样品 砂床滤失量/mL 砂床侵入深度/mm 封堵滤失量*/mL 封堵层渗透率*/mD 优化体系（老化后） 4.2 1.5 8.6 1.2 0#基浆（老化后） 全滤失 >50 全滤失 >5.0 性能改善说明 滤失量降低>80%，
防漏效果显著侵入深度减少>97%，
封堵层致密高温高压下仍具
良好封堵能力渗透率降低>76%，
封堵效率高注：*实验条件为190 ℃、3.5 MPa。
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表 5 K2-3井四开部分井段钻井液的性能（210 ℃、16 h）
井深/m ρ/（g·cm−3） FV/s PV/mPa·s YP/Pa φ6 φ3 FLAPI/mL FLHTHP/mL pH 6807 1.66 95 94 12 6 3 0.8 8.6 9 6827 1.67 132 109 13 6 4 0.6 8.8 9 6869 1.66 121 106 15 8 6 0.6 8.6 9 6942 1.62 116 97 13 7 4 0.7 9.0 9 7010 1.62 120 90 11 5 3 0.8 9.2 9 7107 1.62 104 86 12 6 4 0.8 9.4 9 7130 1.62 116 94 13 5 3 0.6 8.4 9 7150 1.65 98 95 13 6 4 0.6 8.6 9 注：FLHTHP在190 ℃测定。
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