Perforation Friction Pressure of Fracturing Fluid Slurries

Abstract

Perforation Friction Pressure of Fracturing Fluid Slurries J.D. Willingham; J.D. Willingham Halliburton Services Search for other works by this author on: This Site Google Scholar H.C. Tan; H.C. Tan Halliburton Services Search for other works by this author on: This Site Google Scholar L.R. Norman L.R. Norman Halliburton Services Search for other works by this author on: This Site Google Scholar Paper presented at the Low Permeability Reservoirs Symposium, Denver, Colorado, April 1993. Paper Number: SPE-25891-MS https://doi.org/10.2118/25891-MS Published: April 26 1993 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Willingham, J.D., Tan, H.C., and L.R. Norman. "Perforation Friction Pressure of Fracturing Fluid Slurries." Paper presented at the Low Permeability Reservoirs Symposium, Denver, Colorado, April 1993. doi: https://doi.org/10.2118/25891-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu toolbar search search input Search input auto suggest filter your search All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE Rocky Mountain Petroleum Technology Conference / Low Permeability Reservoirs Symposium Search Advanced Search AbstractEven though pressure drop across perforations for clean fracturing fluids can generally be accurately predicted, it is not well understood for fracturing slurries. In this paper, two wellbore models-one transparent and one high pressure-were used to study the perforation friction pressure behavior of sand laden fluids. The transparent model constructed with cast acrylic allowed visual observation of fluid exchange in the "rat-hole" and flow patterns of the slurries in the wellbore and through the perforations. Critical velocity at which sand begins to screenout at the perforations was also determined. Tests were performed in the high pressure model varying gel concentration, sand concentration, proppant size, and perforation diameter to gather pressure drop data. The effect of the ratio of perforation diameter to the average proppant size on the sand screenout tendency at the perforation was also investigated.A correlation to predict the change of perforation coefficient due to proppant erosion was developed from the laboratory data. This paper presents a field procedure to better estimate the change of perforation coefficient during proppant stages for calculating the change of perforation friction.Incorporating this change of perforation pressure drop during proppant stages in the real-time bottomhole treating pressure calculation will enhance interpretation of the treatment analysis.IntroductionDuring a fracturing treatment, fluid containing proppant is pumped down a tubular string, through perforations, and into a fracture. Without a bottomhole tool or reference string, the bottomhole treating pressure is calculated from the following equation.(1)where:BHTP = Bottomhole Treating Pressure (psi) Pw = Wellhead pressure (psi) Ph = Hydrostatic pressure (psi) Pf = Fluid friction pressure in tubular goods (psi) Ppf = Friction loss across the perforations (psi)Using an on-site computer system to perform real-time fracturing pressure analysis to predict fracture propagation requires reliable estimates of the BHTP.P. 479^ Keywords: viscosity, hydraulic fracturing, perforation diameter, fracturing fluid, perforation, wellbore, flow rate, diameter, ib mgal gel, mgal gel Subjects: Hydraulic Fracturing, Perforating, Fracturing materials (fluids, proppant), Completion Installation and Operations, Completion Operations This content is only available via PDF. 1993. Society of Petroleum Engineers You can access this article if you purchase or spend a download.