Volume 36 Issue 1
Feb.  2019
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ZHANG Lufeng, ZHOU Fujian, ZHANG Shicheng, WANG Jie, WANG Jin. Evaluation of Drilling Fluid Damage to Matrices of Tight Sandstone of Keshen Gas Reservoir in Tarim Basin[J]. DRILLING FLUID & COMPLETION FLUID, 2019, 36(1): 126-132. doi: 10.3969/j.issn.1001-5620.2019.01.024
Citation: ZHANG Lufeng, ZHOU Fujian, ZHANG Shicheng, WANG Jie, WANG Jin. Evaluation of Drilling Fluid Damage to Matrices of Tight Sandstone of Keshen Gas Reservoir in Tarim Basin[J]. DRILLING FLUID & COMPLETION FLUID, 2019, 36(1): 126-132. doi: 10.3969/j.issn.1001-5620.2019.01.024
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Evaluation of Drilling Fluid Damage to Matrices of Tight Sandstone of Keshen Gas Reservoir in Tarim Basin

doi: 10.3969/j.issn.1001-5620.2019.01.024

  • The Unconventional Natural Gas Institute of China University of Petroleum, State Key Laboratory of Oil and Gas Resource and Prospecting, China University of Petroleum, Beijing 102200

  • Received Date: 2018-10-08
  • Publish Date: 2019-02-28
    Abstract
  • Micrometer-and nanometer-sized pores are very developed in the matrices of the tight sandstone of Keshen gas reservoir in Tarim Basin, and capillary force plays an important role in formation damage by drilling fluid invasion during drilling, leading to reduced reservoir productivity. Using conventional steady state method to evaluate damage to low permeability tight sandstone by drilling fluid requires high displacing pressure and long stabilization time and is therefore unacceptable. Hence, a mathematic model for permeability calculation was established on the basis of transient pressure transmission method, and the model was solved using Laplace transformation. Based on the solutions to the model, the patterns of damage of the tight sandstone matrices in Keshen gas field by drilling fluids was quantitatively analyzed using pressure transmission permeability tester. Experimental results showed that average percent formation damage by oil base drilling fluids was 31.24%, with water base drilling fluids, on the other hand, this value was 23.67%. The research outcome provides a new clue for evaluating the damaging potential of fluids to be injected into the hole.

     

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