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4 ppg) are being pumped. <gallery widths="300px" heights="200px"> | 4 ppg) are being pumped. <gallery widths="300px" heights="200px"> | ||
File:Vol4prt Page 359 Image 0001.png|'''Fig. 3—Wellbore and near-wellbore hydraulics.''' | File:Vol4prt Page 359 Image 0001.png|'''Fig. 3—Wellbore and near-wellbore hydraulics.''' | ||
</gallery> | </gallery> If the BHTP is computed or measured successfully, the near-wellbore pressure drop must be subtracted to determine the pressure in the fracture near the wellbore, ''p''<sub>''f''</sub>. The pressure in the fracture near the wellbore is the value that must be known and analyzed to determine the width, height, and length of the fracture with either net pressure theory or P3D fracture propagation models. The near-wellbore pressure drop is composed of two parts: the perforation friction and tortuosity. By running a step-down test before the main fracture treatment, the near-wellbore pressure drop often can be estimated accurately. One problem is that the perforation friction and the tortuosity pressure drop can change during the treatment as the propping agent is introduced. The propping agent can erode perforations or plug some of the pathways that are causing the tortuosity pressure drops. At the end of the treatment, the pressure data need to be analyzed as the pumps are shut down to determine if the near-wellbore pressure drop has changed during the treatment. | ||
If the BHTP is computed or measured successfully, the near-wellbore pressure drop must be subtracted to determine the pressure in the fracture near the wellbore, ''p''<sub>''f''</sub>. The pressure in the fracture near the wellbore is the value that must be known and analyzed to determine the width, height, and length of the fracture with either net pressure theory or P3D fracture propagation models. The near-wellbore pressure drop is composed of two parts: the perforation friction and tortuosity. By running a step-down test before the main fracture treatment, the near-wellbore pressure drop often can be estimated accurately. One problem is that the perforation friction and the tortuosity pressure drop can change during the treatment as the propping agent is introduced. The propping agent can erode perforations or plug some of the pathways that are causing the tortuosity pressure drops. At the end of the treatment, the pressure data need to be analyzed as the pumps are shut down to determine if the near-wellbore pressure drop has changed during the treatment. | |||
== Nomenclature == | == Nomenclature == | ||
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[[PEH:Hydraulic_Fracturing]] | [[PEH:Hydraulic_Fracturing]] | ||
== Page champions == | |||
[www.linkedin.com/in/renealcalde Rene Alcalde] | |||
== Category == | == Category == | ||
[[Category:2.5 Hydraulic fracturing]] [[Category:YR]] | [[Category:2.5 Hydraulic fracturing]] [[Category:YR]] | ||
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