Category

Production Engineering

115 items

Acid penetration distance (acidizing)

Average fracture width (acidizing)

Viscous force acting on the rod over the narrow annular region

Additional pressure drop in the skin zone

Correct counterbalance (sucker-rod pump)

Additive crystalline salt amount to increase the density - Method I (single-salt systems)

Flow rate through orifice

Additive crystalline salt amount to increase the density - Method II (single-salt systems)

Frictional pressure drop (Economides and Nolte)

Additive crystalline salt and water amount to increase the density - Method I (two-salt systems)

Mass transfer in acid solutions by Fick's law (acidizing)

Annulus pressure loss due to friction during hydraulic fracturing (laminar flow)

Perforation skin factor

Annulus pressure loss due to friction during hydraulic fracturing (turbulence flow)

Pseudo skin factor due to partial penetration (Brons and Marting method)

Approximate ideal counterbalanced load

Shape factor expressed as skin factor for vertical wells

Average downstroke load (sucker-rod pump)

Suspension property of static fluids (completion and workover fluids)

Average permeability of a hydraulically fractured formation

Wellbore pressure loss due to friction during hydraulic fracturing (turbulence flow)

Average specific weight of the formation (hydraulic fracturing)

Average upstroke load (sucker-rod pump)

Average wellbore fluid density (completion and workover fluids)

Capacity ratio of a hydraulically fractured surface

Choke discharge coefficient

Close-ended displacement volume of pipe

Convective mass transfer for laminar flow (acidizing)

Convective mass transfer for turbulent flow (acidizing)

Corresponding reciprocal rate (post-fracture production-Constant Bottomhole flowing conditions)

Damaged/undamaged zone productivity comparison (acidizing)

Density of brine (completion and workover fluids)

Dimensionless fracture width for linear vertical fracture (Geertsma & Klerk)

Downhole operating pressure (hydraulic fracturing)

Entrance hole size (perforation)

Equivalent skin factor in fractured wells

Filter cake on the fracture (acidizing)

Flow coefficient during drawdown

Flow through fracture in response to pressure gradient

Formation fluid compressibility (acidizing)

Fracture area of a hydraulically fractured formation

Fracture coefficient of a hydraulically fractured reservoir

Fracture fluid coefficient for reservoir-controlled liquids

Fracture fluid coefficient for viscosity-controlled liquids

Fracture geometry (acidizing)

Fracture gradient (hydraulic fracturing)

Fracture-fluid invasion of the formation (acidizing)

Gas velocity under sonic flow conditions (through choke)

Hydraulic fracture efficiency

Hydraulic horse power for a hydraulic fracturing operation

Ideal fracture conductivity created by acid reaction (acidizing)

Incremental density in any wellbore interval (completion and workover fluids)

Initial rate following a hydraulic fracturing operation

Injection pressure for hydraulic fracturing

Lifetime of a hydraulically fractured well

Mass of rock dissolved per unit mass of acid (acidizing)

Maximum treatment pressure (hydraulic fracturing)

Mechanical resistant torque (PCP)

Minimum polished rod load (sucker rod pump)

Peclet number for fluid loss (acidizing)

Perforation friction factor

Perforation friction pressure

Perforation hole size (perforation)

Perforation length in formation

Perforation penetration ratio (formation of interest/reference formation)

Pore growth function (acidizing)

Pressure drop across perforations in gas wells

Pressure drop across perforations in oil wells

Pressure loss due to perforations during hydraulic fracturing

Pressure loss due to perforations during hydraulic fracturing - 2

Principal stress due to petro-static pressure (hydraulic fracturing)

Productivity index (for generating composite IPR curve)

Productivity ratio

Productivity ratio calculation of a hydraulically-fractured formation

Pseudo-skin factor due to partial penetration (Yeh and Reynolds correlation)

Pseudo-skin factor due to partial penetration (Odeh correlation)

Pseudo-skin factor due to partial penetration (Papatzacos correlation)

Pseudo-skin factor due to perforations

Quantifying formation damage and improvement

Recommended underbalanced environment for perforation

Reynolds number for acid flow into the fracture (acidizing)

Reynolds number for fluid loss (acidizing)

Sand weight needed to refill a hydraulically fractured reservoir volume

Single-phase gas flow (subsonic)

Single-phase liquid flow through choke

Skin factor

Skin factor by Hawkins method

Skin factor due to partial penetration

Skin factor due to reduced crushed-zone permeability

Skin factor for a deviated well

Slope of Semilog plot for bottom-hole flowing pressure vs time for drawdown test

Sucker rod - Peak polished rod load

Tangential annular flow of a power law fluid

Temperature at choke outlet

The z component of the force of the fluid on the wetted surface of the pipe

Total skin in partially depleted wells for a buildup test

Velocity distribution in the annular slit of a falling-cylinder viscometer

Velocity distribution in the narrow annular region in annular flow with inner cylinder moving axially

Velocity distribution of flow through an annulus

Velocity of fluid in annulus

Velocity of fluid in pipe

Volume capacity of pipe

Volume of fluid loss per unit area measured in a dynamic test (acidizing)

Volume of fluid loss per unit area measured in a static test (acidizing)

Volume of rock dissolved per unit volume of acid (acidizing)

Water quantity that dilutes the original brine with assumed density (two-salt systems)

Weight of crystalline CaCl2 and CaBr2 salt addition to brine (two-salt systems)

Well flowing pressure (line-source solution by including skin factor)

Well flowing pressure under Pseudo-steady state flow for non-circular reservoirs

Wellbore pressure loss due to friction during hydraulic fracturing (laminar flow)

Wellbore storage

Wellbore storage due to fluid level

Wellhead pressure (multiphase flow across the choke)

Workover operations (maximum allowed tubing pressure)

Young Modulus by using sonic travel time (acidizing)