Application of a High Temperature High Density Oil Base Drilling Fluid in Well Dabei-12X in Tarim Oilfield
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摘要: 大北12X井是2018年塔里木油田的一口高温高压评价井，位于库车坳陷克拉苏构造带大北段大北12号构造东高点，该区块库姆格列木群膏盐岩段（4267～5287 m）普遍为高压～超高压，局部存在高压盐水层、漏层。钻井过程中，易出现井壁失稳、漏失、盐水侵等复杂技术难题。针对该区域的地质特点和作业要求，分析了高温高压作业条件下油基钻井液体系的技术难点，优选出抗高温高密度油基钻井液体系配方，并且通过室内实验，模拟高温高压井段作业可能出现的风险，进行了系统的工况模拟评价。实验结果表明，抗高温高密度油基钻井液体系性能稳定，破乳电压为1562 V、高温高压滤失量为1 mL，体系抗30%体积分数的近饱和NaCl盐水污染，污染后体系表观黏度变化小于10%，滤失量小于2 mL，破乳电压为1002 V。体系抗温稳定能力强，室内实验170℃老化10 d后体系流变性能稳定，沉降因子为0.522。现场应用表明，抗高温高密度油基钻井液体系能够解决塔里木油田库车坳陷克拉苏构造带高温高压超高压盐膏层作业难题。四开井段，钻井液密度为2.43 g/cm3，油基钻井液保持了良好的钻井液流态，较低的黏度、切力及ECD等优良参数，未造成黏度、切力过高引起井漏等复杂情况。该井钻遇盐膏层厚度达2135 m，油基钻井液抗石膏污染能力强，流变性能稳定。Abstract: The Well Dabei-12X, located at the east high of the Dabei 12# structure in the Kuche depression, is a high temperature high pressure (HTHP) appraisal well drilled in Tarim oilfield in 2018. This well penetrated the gypsum and salt zones of the Kumugeliemu formation (4267-5287 m) in which high pressure and ultra-high pressure prevail. Also exist in this section are high-pressure saltwater zones and mud loss zones. In previous drilling operation, borehole wall collapse, mud losses and saltwater invasion have been occurring all the time. Based on the geologic characteristics and operational requirements in this area, the technical difficulties in using oil base drilling fluids at HTHP were analyzed and a high temperature high density oil base drilling fluid was formulated. Laboratory experiments were performed to simulate the possible risks in drilling the HTHP sections. Experimental results showed that the high temperature high density oil base drilling fluid had stable properties; the electric stability was 1562 V, and the HTHP filter loss was 1 mL. When contaminated with 30% (Vol.%) nearly saturated saltwater, percent change in the apparent viscosity of the oil base drilling fluid was less than 10%, the filter loss was less than 2 mL and the electric stability was 1002 V. The oil base drilling fluid had good high temperature stability; after being aged at 170 ℃ for 10 d, the rheology of the drilling fluid was still stable. The settling factor of the drilling fluid was 0.522. Field application indicated that this oil base drilling fluid can be used to solve the problems encountered in drilling the HTHP and ultra-high-pressure salt/gypsum zones in the Kelasu structural belt in Kuche depression, Tarim Basin. The density of the drilling fluid in the fourth interval was 2.43 g/cm3 and the drilling fluid still retained good flow property, low viscosity, low gel strengths and ECD, no mud losses resulted from high viscosity and high gel strengths were encountered. In drilling the 2135 m salt/ gypsum zones, the rheology of the mud was very stable because of the high resistance of the mud to salt and gypsum contamination.
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