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The flowback rate of water during drainage of coalbed methane (CBM) wells significantly influences the gas yield. The difference in the coal wettability of aqueous solutions with different degrees of mineralization is a key factor influencing the flowback rate. To clarify the coal wetting characteristics and mechanism of action of aqueous solutions with different degrees of mineralization, the contact angle between aqueous solutions with different degrees of mineralization and coal, surface tension, and zeta potential were tested. The Derjaguin−Landau−Verwey− Overbeek theory and diffuse double layer theory were used to reveal the mechanism of actions of the degree of mineralization, type of ions in solution, and complex solutions on the wettability of the coal surface. Results show that, as the degree of mineralization increases, the surface tensions of five solutions (NaHCO 3 , CaCl 2 , NaCl, Na 2 SO 4 , and Na 2 SO 4 + KCl) on the coal surface increase. The coal−water contact angle shows logarithmic growth; the absolute value of zeta potential decreases in a logarithmic manner, and the water-film thickness in the system decreases in a negative exponential manner. The coal wettability of aqueous solutions is mainly dependent on the electrostatic force and the van der Waals force (VDWF). The degree of mineralization changes the molecular electrostatic force in the system, which is the primary cause of changes in the coal wettability of aqueous solutions. As the degree of mineralization increases, the absolute value of the zeta potential of the coal−water interface declines, the electrostatic force decreases, and the energy barrier is lowered, which enlarges the contact angle and lowers the wettability. Compared with univalent Na + , the interfacial electrostatic force of divalent Ca 2+ reduces. The increment of the proportion of VDWF is the foundational cause for the increasing wettability. Addition of KCl solution can enlarge the coal−water contact angle, which is conducive to flowback of water. The results provide a theoretical basis for understanding the wetting mechanism of coal by water with different degrees of mineralization.
The flowback rate of water during drainage of coalbed methane (CBM) wells significantly influences the gas yield. The difference in the coal wettability of aqueous solutions with different degrees of mineralization is a key factor influencing the flowback rate. To clarify the coal wetting characteristics and mechanism of action of aqueous solutions with different degrees of mineralization, the contact angle between aqueous solutions with different degrees of mineralization and coal, surface tension, and zeta potential were tested. The Derjaguin−Landau−Verwey− Overbeek theory and diffuse double layer theory were used to reveal the mechanism of actions of the degree of mineralization, type of ions in solution, and complex solutions on the wettability of the coal surface. Results show that, as the degree of mineralization increases, the surface tensions of five solutions (NaHCO 3 , CaCl 2 , NaCl, Na 2 SO 4 , and Na 2 SO 4 + KCl) on the coal surface increase. The coal−water contact angle shows logarithmic growth; the absolute value of zeta potential decreases in a logarithmic manner, and the water-film thickness in the system decreases in a negative exponential manner. The coal wettability of aqueous solutions is mainly dependent on the electrostatic force and the van der Waals force (VDWF). The degree of mineralization changes the molecular electrostatic force in the system, which is the primary cause of changes in the coal wettability of aqueous solutions. As the degree of mineralization increases, the absolute value of the zeta potential of the coal−water interface declines, the electrostatic force decreases, and the energy barrier is lowered, which enlarges the contact angle and lowers the wettability. Compared with univalent Na + , the interfacial electrostatic force of divalent Ca 2+ reduces. The increment of the proportion of VDWF is the foundational cause for the increasing wettability. Addition of KCl solution can enlarge the coal−water contact angle, which is conducive to flowback of water. The results provide a theoretical basis for understanding the wetting mechanism of coal by water with different degrees of mineralization.
Deep coalbed methane reservoirs generally exhibit characteristics such as extremely low permeability, significant heterogeneity, high in situ stress, and dense geological discontinuities. Notably, these geological discontinuities cleats, bedding planes, and natural fractures, as mechanically weak planes, significantly contribute to the creation of extremely complex and tortuous hydraulic fracture (HF) networks near the wellbore, but impede the propagation of HFs to the far-field region. This will lead to insufficient stimulated reservoir volume, thereby limiting the CBM production. Under this background, a series of physical simulation experiments of temporary plugging and diverting fracturing (TPDF) were carried out on large-size coal blocks under true triaxial stress conditions. Combining high-energy industrial computed tomography scanning technology, first, the morphology of fracture propagation of the sample before TPDF is divided into two fracture propagation modes. Then, TPDF experiments were conducted to analyze the behavior of fracture propagation under different modes. Finally, a mode of TPDF tailored for adjusting the HF network geometry in deep CBM reservoirs was explored innovatively. The effects of concentration and particle size of the temporary plugging agent (TPA) on pressure increment, plugging location and fracture diversion behavior during TPDF were examined in particular. Experimental results indicate that optimizing the concentration and particle-size of TPA based on the resulting fracture geometry is crucial for adjusting the fracture network geometry (simplifying the growth behavior of HF near the wellbore while increasing fracture complexity in the far-field region) during conventional fracturing (before using the TPA). When a complex fracture network is created under the condition of formation with high-dense natural fractures (NFs) near the wellbore region, using small-particle-size TPA (e.g., 70/140 mesh) is optimal for adjusting the fracture geometry, as it can effectively plug the NFs and allow them to continue extending toward the far-field region. Meanwhile, a higher concentration of TPA is beneficial for plugging the interval of HF closer to the wellbore, and then causing the creation of complex fracture networks. When a long single HF is generated under the condition of a formation with low-dense NFs, using the medium-particle-size TPA (e.g., 40/70 mesh) is optimal for enhancing the fracture complexity near the wellbore region. Using TPA of excessively large particle sizes (e.g., 20/40 mesh) tends to plug the HFs at their entrances, causing HFs to be reinitiated from the unstimulated segment of the wellbore. This study can provide crucial theoretical guidance for optimizing the scheme design of TPDF in deep CBM reservoirs.
This study builds upon the research progress in the theories of CBM desorption, diffusion, and seepage flow to explore the production mechanisms of deep coalbed methane (CBM) in the Daing-Jixian block, aiming to achieve scientific and reasonable control of gas wells. Theoretical analysis suggests that CBM adsorption belongs to liquid–solid interfacial adsorption, encompassing four stages: liquid phase adsorption—liquid phase desorption—composite desorption—gas phase desorption. Most of the desorbed gas is driven by a pressure differential in a Darcy's flow process. By calculating the Knudsen number (Kn) under various temperature, pressure, and fracture diameter conditions, the flow state can be identified. Whole-diameter CT scanning reveals a multi-scale pore-fracture system ranging from millimeters to micrometers to nanometers. Calculations show that during the gas well drainage and depressurization process, fractures of millimeter scale and larger exhibit Darcy's flow, while micron-scale fractures maintain Darcy's flow status above a reservoir pressure of 5 MPa; other scales primarily exhibit non-Darcy flow without significant macroscopic movement. In summary, starting from the fundamental mechanisms of the original multiscale tri-level pore-permeability system of the coal reservoir, through the post-fracturing transformation forming three diversion zones of high, medium, and low conductive regions, and transitioning from primarily free gas to desorbed gas in three production stages, an ideal comprehensive production model schematic for the study area has been established, providing theoretical support for on-site production management.
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