Drill-in Fluid Technology for Offshore Ultra-High Low-Permeability Reservoirs
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摘要: 南海西部东方F气田黄流组二段为超高温低孔低渗段储层，温度高达205℃。前期钻探使用的低渗透钻开液作业存在高温降解问题，影响了现场作业并带来水锁伤害问题。为此，室内研选出超高温条件下具有良好协同抗温作用的温敏聚合物提黏剂、增黏降滤失剂、抗超高温改性淀粉材料，构建了一套新型抗超高温低渗透储层钻开液体系。该体系210℃高温稳定，150℃滤失量小于10 mL，岩心污染渗透率恢复值大于90%，滤饼易破胶、易解除。同时，优选出的配套超高温防水锁剂不起泡，能将体系滤液的气-液表面张力和油-液界面张力分别降低至27.7 mN/m和5.9 mN/m。新型抗超高温低渗透储层钻开液体系在东方F气田X2调整井进行了成功应用，作业期间体系黏度和切力稳定、滤失量小、井径规则、作业顺利，测试投产效果好，该井表皮系数仅为0.13。新型抗超高温低渗透储层钻开液技术对于降低海上此类储层的钻探开发风险和保障产能具有重要意义。Abstract: The second member of the Huangliu Formation in the Dongfang F gas field in the western South China Sea is a reservoir with ultra-high temperature, low porosity and low permeability, the temperature which is as high as 205℃. The solid-free drilling fluid used in the previous drilling operations degraded at elevated temperatures, negatively affected field operations and caused water lock damage to the reservoir. To deal with this problem, a temperature-sensitive polymer viscosifier, a viscosity increasing filter loss reducer, and an ultra-high temperature modified starch were selected to formulate a new high temperature solid-free drill-in fluid. The three additives work synergistically in the new drilling fluid to resist the action of ultra-high temperature. The drill-in fluid is stable at 210℃, the filtration rate is less than 10 mL at 150℃, the permeability recovery of the core contaminated with the drill-in fluid is greater than 90%, and the filter cake is easy to break and remove. Meanwhile the selected supporting ultra-high temperature water lock inhibitor does not foam, and can reduce the gas-liquid surface tension and oil-liquid interfacial tension of the drill-in fluid filtrate to 27.7 mN/m and 5.9 mN/m respectively. The new ultra-high temperature solid-free drill-in fluid has been successfully applied on the X2 adjustment well in the Dongfang F gas field. During the operation, the viscosity and gel strength of the system were stable, the filtration rate was small, the hole diameter was regular, the operation was smooth, and the test and production effect was good. The skin factor of this well was only 0.13. The new ultra-high temperature solid-free drill-in fluid is of great significance for reducing the drilling and development risks of such offshore reservoirs and for ensuring the production capacity.
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表 1 海上常用低渗透钻开液体系的抗温性能
T老化/
℃AV/
mPa·sPV/
mPa·sYP/
PaFLHTHP/
mLφ6/φ3 η0/
mPa·s老化前 43 21 22 11 18/15 43 000 150 48 24 24 17 19/17 49 000 170 41 22 19 35 18/15 38 886 190 40 22 18 71 15/12 25 000 210 7 7 0 0/0 0 注：老化时间为16 h。 
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表 2 2.5%抗超高温降滤失剂的初选评价
降滤
失剂实验
条件PV/
mPa·sYP/
PaFLAPI/
mLFLHTHP/
mLφ6/φ3 η0/
mPa·sKG-Filcon 老化前 21 20 18/15 43 000 老化后 22 18 3.0 71.0 15/12 25 100 KG-CPSY 老化前 22 15 15/13 36 200 老化后 21 15 5.0 28.0 13/11 17 000 KG-THERM 老化前 24 15 15/13 31 000 老化后 23 18 4.5 30.0 13/11 21 000 KG-UTSTA 老化前 24 18 15/13 40 000 老化后 21 20 3.7 17.8 15/13 38 000 KG-FLUCON 老化前 24 18 15/13 42 000 老化后 21 20 3.6 17.0 15/13 39 000 注：老化条件为190℃、16 h。
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表 3 抗超高温聚合物增黏剂的优选实验
聚合物 实验
条件AV/
mPa·sPV/
mPa·sYP/
Paφ6/φ3 FLAPI/
mL1%KG-TNJ 210℃、16 h 18 13 5 1/1 15.0 1%DrilFILHT 210℃、16 h 7 6 1 0.5/0.5 5.0 1%Drilloss F 210℃、16 h 6 6 0 0.5/0.5 9.0 1%PC-UTS 210℃、16 h 12 11 1 1.0/0.5 16.0 1.5%KG-TNJ 210℃、16 h 20 13 7 0.5/0.5 21.0 1.5%DrilFILHT 210℃、16 h 12 11 1 0.5/0.5 5.0 1.5%Drilloss F 210℃、16 h 9 9 0 0.5/0.5 7.0 1.5%PC-UTS 210℃、16 h 18 15 3 0.5/0.5 21.0 注：流变性在50℃测定。
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表 4 高温聚合物的复配效果实验数据
复配聚合物 实验条件 AV/mPa·s PV/mPa·s YP/Pa φ6/φ3 FLAPI/mL FLHTHP/mL 1%KG-TNJ+2.5%KG-UTSTA 210℃、16 h 26 18 8 3/2 3.0 6.8 1%PC-UTS+2.5%KG-UTSTA 210℃、16 h 22 17 5 2/1 3.0 8.2 1%KG-TNJ+2.5%KG-FLUCON 210℃、16 h 39 26 13 3/2 2.5 7.0 注：流变性在50℃测定 ；FLHTHP在150℃、3.5 MPa测定。
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表 5 防水锁剂优选数据记录表
防水锁剂 10 min起泡率/
%γ滤液/
mN·m−1σ滤液油液/
mN·m−1未添加 未添加 65.5 41.5 2.5%KHV 320.0 39.2 5.4 2.5%LK-20 278.0 40.6 5.1 2.5%JNV 427.0 38.2 6.4 2.5%S-30 217.0 42.0 7.5 2.5%ULRRE30 152.0 37.1 9.4 2.5%1338 282.0 39.7 15.7 2.5%HLN-S 2.0 41.7 11.2 2.5%KCS 13.0 29.8 7.2 2.5%KCS-F 0.6 27.7 5.9 注：老化条件为210℃、16 h； 表面张力和油液界面张力在80℃测定。
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表 6 低渗透钻开液超高温长时间老化稳定性（210℃、72 h ）
老化状态 PV/
mPa·sYP/
Paφ6/φ3 FLAPI/
mLFLHTHP/
mLη0/
mPa·s动态老化 23 20 4/3 3.3 12.0 31 532 静置老化 28 21 8/5 2.9 11.4 38 161 注：流变性在50℃ 测定；FLHTHP在150℃、3.5 MPa测定。
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表 7 低渗透钻开液的高温高压流变性（ρ=1.20 g/cm3）
T测定/℃ AV/mPa·s PV/mPa·s YP/Pa 120 36 18 18 150 32 15 17 190 30 12 18 210 28 11 17 注：老化条件为210℃、16 h，流变性在5 MPa测定。
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表 8 抗超高温低渗透钻开液的储层保护性能
岩心深度/
mK油相/mD 渗透率恢复/
%污染前 污染后 4210.0 7.257 6.713 92.5 4250.0 8.628 8.006 92.8
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表 9 储层钻开液在不同深度的流变性参数
井深/
mρ/
g·cm−3PV/
mPa·sYP/
Paφ6/φ3 FLAPI/
mLFLHTHP/
mLη0/
mPa·s3876 1.16 23 10 4/3 3.3 12.0 31 478 3952 1.16 24 10 4/3 3.5 11.8 31 698 4029 1.17 24 11 5/4 3.6 11.6 31 759 4188 1.17 25 11 5/4 3.8 11.5 31 827 4296 1.18 26 12 6/5 3.9 11.3 31 962 注：钻井液密度为1.16～1.17 g/cm3，FLHTHP在150℃、3.5 MPa下测定。
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