Volume 35 Issue 2
Mar.  2018
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Article Navigation >  DRILLING FLUID & COMPLETION FLUID  > 2018  >  35(2): 131-137
LI Ning, YOU Lijun, ZHANG Zhen, TIAN Jian, ZHANG Shaojun, KANG Yili, ZHANG Dujie. Self-imbibition Behavior of water phase in Tight Sandstones gas reservoir Taking into Account Contact Area and Differential Pressure[J]. DRILLING FLUID & COMPLETION FLUID, 2018, 35(2): 131-137. doi: 10.3969/j.issn.1001-5620.2018.02.022
Citation: LI Ning, YOU Lijun, ZHANG Zhen, TIAN Jian, ZHANG Shaojun, KANG Yili, ZHANG Dujie. Self-imbibition Behavior of water phase in Tight Sandstones gas reservoir Taking into Account Contact Area and Differential Pressure[J]. DRILLING FLUID & COMPLETION FLUID, 2018, 35(2): 131-137. doi: 10.3969/j.issn.1001-5620.2018.02.022
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Self-imbibition Behavior of water phase in Tight Sandstones gas reservoir Taking into Account Contact Area and Differential Pressure

doi: 10.3969/j.issn.1001-5620.2018.02.022

  • 1. Research Institute of Oil and Gas Engineering, PetroChina Tarim Oilfield Division, Korla, Xinjiang 841000;

  • 2. State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University, Chengdu, Sichuan 610500

  • Received Date: 2017-10-12
  • Publish Date: 2018-03-30
    Abstract
  • During drilling process, water phase invades into reservoirs through capillary force and positive differential pressure, causing water phase trapping in tight sandstone gas reservoirs, and resulting in wrong logging data explanation of pay zones to water zones, hindering timely discovering and accurately appraising of tight sandstone gas reservoirs. To understand the self-imbibition behavior of water phase in tight sandstone gas reservoir, plug cores from a typical tight sandstone gas reservoir were used to simulate selfimbibition by end contact of plug core with water when water comes into contact with reservoir rocks at the moment when the reservoir is first drilled, self-imbibition by soaking of rocks when fractures are flooded with water, and forced imbibition by capillary force under the action of positive differential pressure. The influences of contact area and differential pressure on capillary self-imbibition of water to tight sandstone are analyzed. The simulation test results show that imbibition rate is affected by imbibition area and the development of fracture. The more developed the fractures and the greater the contact area, the higher the imbibition rate, and the imbibition process is easier to reach equilibrium. Positive differential pressure accelerates capillary imbibition in rocks whose physical properties in turn affect the imbibition process. When the physical properties of rocks are low to a certain extent, the imbibition behavior is mainly affected by capillary force. For the dense part of a tight gas reservoir matrix, positive differential pressure has minor effect on imbibition. When fractures are developed in the dense part of the tight gas reservoir matrix, the contact area for flow is increased, and a high positive differential pressure enhances the imbibition rate. It is thus concluded that water invasion into tight sandstone reservoirs during drilling and completion can be prevented mainly by plugging fractures and by controlling differential pressure to minimize water-rock contact and the amount of water entering into reservoir rocks.

     

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