Page 210 - Formulas and Calculations for Petroleum Engineering

Chapter 4

Production engineering formulas

and calculations

Chapter Outline
4.1 Acid penetration distance (acidizing) 204 4.28 Filter cake on the fracture (acidizing) 216
4.2 Additional pressure drop in the skin zone 4.29 Flow coefficient during drawdown 217
4.3 Additive crystalline salt amount to increase 4.30 Flow rate through orifice 217
the density—Method I (single-salt systems) 205 4.31 Flow through fracture in response to pressure
4.4 Additive crystalline salt amount to increase gradient 217
the density—Method II (single-salt systems) 206 4.32 Formation fluid compressibility (acidizing) 218
4.5 Additive crystalline salt and water amount to 4.33 Fracture area of a hydraulically fractured formation 218
increase the density—Method I (two-salt systems) 206 4.34 Fracture coefficient of a hydraulically fractured
4.6 Annulus pressure loss due to friction during reservoir 219
hydraulic fracturing (laminar flow) 207 4.35 Fracture fluid coefficient for reservoir-controlled
4.7 Annulus pressure loss due to friction during hydraulic liquids 219
fracturing (turbulence flow) 207 4.36 Fracture fluid coefficient for viscosity-controlled
4.8 Approximate ideal counterbalanced load 208 liquids 220
4.9 Average downstroke load (sucker-rod pump) 208 4.37 Fracture geometry (acidizing) 220
4.10 Average fracture width (acidizing) 208 4.38 Fracture gradient (hydraulic fracturing) 220
4.11 Average permeability of a hydraulically fractured 4.39 Fracture-fluid invasion of the formation (acidizing) 221
formation 209 4.40 Frictional pressure drop (Economides and Nolte) 221
4.12 Average specific weight of the formation (hydraulic 4.41 Gas velocity under sonic flow conditions (through
fracturing) 209 choke) 222
4.13 Average upstroke load (sucker-rod pump) 210 4.42 Hydraulic fracture efficiency 222
4.14 Average wellbore fluid density (completion and 4.43 Hydraulic horse power for a hydraulic fracturing
workover fluids) 210 operation 223
4.15 Capacity ratio of a hydraulically fractured surface 210 4.44 Ideal fracture conductivity created by acid reaction
4.16 Choke discharge coefficient 211 (acidizing) 223
4.17 Close-ended displacement volume of pipe 211 4.45 Incremental density in any wellbore interval
4.18 Convective mass transfer for laminar flow (completion and workover fluids) 223
(acidizing) 212 4.46 Initial rate following a hydraulic fracturing
4.19 Convective mass transfer for turbulent flow operation 224
(acidizing) 212 4.47 Injection pressure for hydraulic fracturing 224
4.20 Correct counterbalance (sucker-rod pump) 213 4.48 Lifetime of a hydraulically fractured well 225
4.21 Corresponding reciprocal rate (post-fracture 4.49 Mass of rock dissolved per unit mass of acid
production—Constant bottomhole flowing (acidizing) 225
conditions) 213 4.50 Mass transfer in acid solutions by Fick’s law
4.22 Damaged/undamaged zone productivity comparison (acidizing) 225
(acidizing) 214 4.51 Maximum treatment pressure (hydraulic fracturing) 226
4.23 Density of brine (completion and workover fluids) 214 4.52 Mechanical resistant torque (PCP) 226
4.24 Dimensionless fracture width for linear vertical 4.53 Minimum polished rod load (sucker rod pump) 226
fracture 214 4.54 Peclet number for fluid loss (acidizing) 227
4.25 Downhole operating pressure (hydraulic fracturing) 215 4.55 Perforation friction factor 227
4.26 Entrance hole size (perforation) 215 4.56 Perforation friction pressure 228
4.27 Equivalent skin factor in fractured wells 216 4.57 Perforation hole size (perforation) 228

Formulas and Calculations for Petroleum Engineering. https://doi.org/10.1016/B978-0-12-816508-9.00004-4
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