Re-injection feasibility study of fracturing flow-back fluid in shale gas mining
| Autor: | Sheng-wei Shi, Ding-yu Kang, Jiajia Du, Xin-jian Chen, Xue Chen, Chengtun Qu, Tao Yu |
|---|---|
| Rok vydání: | 2018 |
| Předmět: | |
| Zdroj: | IOP Conference Series: Earth and Environmental Science. 121:052032 |
| ISSN: | 1755-1315 1755-1307 |
| Popis: | Fracturing flow-back fluid in shale gas mining is usually treated by re-injecting into formation. After treatment, the fracturing flow-back fluid is injected back into the formation. In order to ensure that it will not cause too much damage to the bottom layer, feasibility evaluations of re-injection of two kinds of fracturing fluid with different salinity were researched. The experimental research of the compatibility of mixed water samples based on the static simulation method was conducted. Through the analysis of ion concentration, the amount of scale buildup and clay swelling rate, the feasibility of re-injection of different fracturing fluid were studied. The result shows that the swelling of the clay expansion rate of treated fracturing fluid is lower than the mixed water of treated fracturing fluid and the distilled water, indicating that in terms of clay expansion rate, the treated fracturing flow-back fluid is better than that of water injection after re-injection. In the compatibility test, the maximum amount of fouling in the Yangzhou oilfield is 12mg/L, and the maximum value of calcium loss rate is 1.47%, indicating that the compatibility is good. For the fracturing fluid with high salinity in the Yanchang oilfield, the maximum amount of scaling is 72mg/L, and the maximum calcium loss rate is 3.50%, indicating that the compatibility is better. |
| Databáze: | OpenAIRE |
| Externí odkaz: |
|