Ultra-High Temperature CaCl2 Weighted Fracturing Fluid Technology for Ultra-Deep High-Pressure Reservoir Stimulaiton
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摘要: 随着深层、超深层、超高压储层勘探的持续突破，对加重压裂液提出更高要求。由于氯化钾加重压裂液密度有限，溴盐加重压裂液密度较高，但价格昂贵，且胍胶类加重压裂液和清洁表活剂类加重压裂液耐温有限，难以适应万米深层的改造需求。针对这一难题开展了超高温氯化钙加重压裂液技术研究。通过加重盐的选择、耐高温耐高盐聚合物的合成、延迟可控交联剂的研制等关键技术的攻克，形成了耐超高温220 ℃的低成本氯化钙加重压裂液技术，并进行了全面的性能评价。密度范围涵盖1.15～1.35 g/cm3，各配方在经过180～220 ℃、2 h剪切后黏度大于50 mPa·s，交联时间可控，180 ℃携砂2 h无沉降，降阻率50%以上。塔科1井井温205 ℃，经多轮次检测，压裂液性能稳定，成功应用308 m3。氯化钙加重压裂液技术的成功应用，为超深层超高压储层改造提供了宝贵经验。Abstract: The continual breakthrough in exploring deep, ultra-deep and ultra-high pressure reservoirs has raised higher demands on heavy fracturing fluids. Fracturing fluid additives presently in use have various shortages, for example, KCl can raise the density of fracturing fluids to only a low density, bromides can raise the density of fracturing fluids to much higher densities, they are quite expensive though. Weighted guar gum fracturing fluids and weighted clear surfactant fracturing fluids, on the other hand, have poor high-temperature stability. To meet the requirements of stimulating reservoirs that are more than ten-thousand meters in depths, a technical study was conducted on ultra-high temperature weighted calcium chloride (CaCl2) fracturing fluid. By selecting the salts for weighting, synthesizing polymers that are stable at high temperatures and high salinities, and developing delayed/controllable crosslinkers, all of which are key to the formulation of an ideal fracturing fluid, a cost-effective CaCl2-weighted fracturing fluid which is resistant to ultra-high temperatures up to 220 ℃, was developed. The density of the fracturing fluid ranges from 1.15 g/cm3 to 1.35 g/cm3. The results of a comprehensive performance evaluation of the fracturing fluid show that after shearing for 2 hours at 180 – 220 ℃, the fracturing fluid, with varying compositions, has a viscosity that is greater than 50 mPa·s. The crosslinking time of the fracturing fluid is controllable. After standing for 2 hours at 180 ℃, no sand settling occurs. The rate of drag reducing of this fracturing fluid is greater than 50%. This fracturing fluid has been applied many times in the well Take-1, a well with bottomhole temperature of 205 ℃, the properties of the fracturing fluid were stable, and 308 m3 fracturing fluid was successfully used. The successful application of this weighted fracturing fluid technology provides a valuable experience for ultra-deep ultra-high pressure reservoir stimulation.
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表 1 不同分子量聚合物形成的加重压裂液基液黏度
聚合物分子量 η基液/ mPa·s 耐温能力/℃ 500 54 150 700 81 220 900 132 220 1200 198 230 注：聚合物浓度为0.8%，配制基液密度为1.35 g/cm3。 
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表 3 不同温度、时间下快速破胶所需破胶剂用量
T/℃ 破胶剂用量/% 2/h 4/h 6/h 8/h 90 0.50 0.42 0.45 0.41 120 0.46 0.40 0.37 0.32 150 0.43 0.37 0.33 0.28 200 0.37 0.34 0.30 0.22
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表 4 不同密度加重压裂液的残渣含量
ρ/（g·cm−3） T/℃ 破胶时间/h 残渣含量/（mg·L−1） 1.20 180 4 352 1.25 180 4 378 1.30 180 4 435 1.35 180 4 590 注：稠化剂使用浓度0.8%。
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表 5 加重压裂液破胶液对岩心基质伤害率
井号 干岩心气测
渗透率/mD改造液
类型伤害率/
%伤害
程度阳探1井 0.8337 氯化钙加重压裂液 18.60 弱 阳探1井 0.5407 氯化钙加重压裂液 23.70 弱 克深11井 0.3460 氯化钾加重压裂液 23.86 弱
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