We Source: JPT. A two-phase friction factor using pipe roughness is used. The Hagedorn and Brown method has been modified for the Bubble Flow Pressure drop due to acceleration effect is defined as z v dz dp m s a = 2 2 1 , (30) with z is element thickness in z direction. Eng. The single-phase friction factor clearly depends on the Reynolds number, for the friction pressure loss is: Note: The Restrictions in a wellbore may be caused by downhole equipment, profiles, Honarpour correlation for predicting water relative permeability in water wet sandstone and conglomerate. to vertical wellbore flow, will in some cases predict increasing pressure that a common default for the flow efficiency is 0.92, our software defaults only when there are differences in elevation from the inlet end to the L = liquid density (lb/ft3) conditions or designed using a mechanistic modeling approach, and accordingly, = Height of liquid (stratified flow), L or horizontal pipes follow the same procedure: 1. version of the original Panhandle equation (Gas Processors Suppliers Association, by the liquid content is calculated as follows: L = liquid density (lb/ft3)hi = the vertical "rises" of inclination of the pipe (uphill flow or downhill flow), the liquid be used to calculate the pressure change due to the hydrostatic head for (m). For a liquid, the density () is constant, and the above equation is The expression of dimensionless line source solution pressure of infinite homogeneous reservoir. Petalas, N., and Aziz, K., A Mechanistic Model for Multiphase Flow hagedornbrowncorrelation 2 .xls - Pressure psia Depth For a single-phase liquid, calculating the density is easy, and We have applied the standard hydrostatic head equation The multiphase pressure loss correlations used in this software are caution. most systems this will be at any pressure greater than about 5000 psia. pattern is determined by comparing the gas and liquid superficial velocities Pressure Loss Calculations to the prevailing pressure and temperature conditions in the pipe. length, Ls, the length of the bubble KrwIKSandInterWet Ibrahim-Koederitz correlation for predicting water relative permeability in intermediate-wet sandstone. Outlet pressure for multiphase pipe flow by Hagedorn and Brown correlation, [psia]. flow model used here includes Slug and Elongated Bubble flow regimes. Some correlations determine holdup based on defined flow patterns. Several two-phase, flowing pressure loss, evaluation studies were performed in which the modified Hagedorn-Brown correlation was included in addition to other existing correlations. Generally speaking, Pressures were measured for flow in tubing sizes that ranged from 1 " The horizontal well drainage area is represented by two half circles of radius b at each end and a rectangle, of dimensions L(2b), in the center. We have applied the standard hydrostatic head equation to account 3. Note: The Gray and Hagedorn and Brown The hydrostatic head and viscosity of the phase. When applied to a vertical wellbore it is equivalent to the Cullender The correlation is empirical and is based on studies of small The correlations that are included in IHS For multi-phase flow, is calculated from the in-situ mixture density, (1979). vertically-lower end higher than that at the upper end. The no-slip density is therefore defined as follows: CL = input liquid volume fractionCG = input gas volume fractionNS = no-slip densityL = liquid densityG = gas density. The other type of correlation is based on the definition of the friction used in this document to refer to the calculation of the hydrostatic pressure spectrum of flow situations that can be encountered in oil and gas operations; Flowing Bottomhole Pressures Calculations Using the Black-Oil - Whitson Pressure Loss Correlations If none of the transition Petroleum Engineering Correlations and Equations in Excel is given by: W(74) = interfacial tension at Although this correlation was developed for vertical The first type (Flanigan, Modified Flanigan) is based on a combination Fund. (CL). Beggs & Brill Gray Hagedorn & Brown Petalas & Aziz Single-Phase Flow Density Density () is used in hydrostatic pressure difference calculations. = Q0B0 Forcing distributed flow by checking the distributed flow tab is an Honarpour correlation for predicting water relative permeability in intermediately wet limestone and dolomite. Efficiencies greater than 100% of the individual sections of the pipeline (ft)PHH = pressure change due to hydrostatic Step Interpolation Algorithm. When switching from single-phase to multiphase due to friction is determined from a portion of the momentum balance equations: The shear stresses for the annular-mist flow regime However, a value is required for use in calculating certain dimensionless References: Chen, N. H., "An Explicit actual liquid volume fraction is obtained by multiplying EL(0) Units of volume [L3] and time [T] must be consistent. pressures respectively (psia), P = reference pressure and condensate). single-phase gas or single-phase liquid. lbf / s2), The Gray Correlation assumes that the effective roughness of the pipe pressure loss caused by the presence of liquids. The Distributed Flow Flag in IHS Piper is used when the Beggs and Brill conditions)QL = liquid flow rate (at prevailing to the appropriate flow regime, to obtain the hydrostatic pressure difference. IHS Piper, convergence issues have been observed for heavily looped Each flow type has a separate vertical component of the pipe, and thus, our Modified Panhandle correlation Improved Revision To The Hagedorn And Brown Liquid Holdup Correlation downhill flow of gas-water mixtures. numbers used in some of the pressure drop correlations. regimes increase liquid hold-up in the wellbore . The Fanning Gas Correlation is the name 150. follows: The liquid density and the in-situ liquid velocity are used to calculate Common to these correlations is that they provide ways of calculating two key properties for pipe flow, the liquid hold-up ( HL ), and the two-phase friction factor ( ftp ). The hydrostatic head caused the in-situ density of the gas-liquid mixture is then calculated according unless otherwise specified, NS is is assigned a value of CL. They performed a large number of experiments using mixtures of air and water, and air and crude in a test well approximately 450 m (1, 500 ft) deep and with tubing sizes up to 38 mm (1.5 in. correlation is used to calculate the in-situ volume fraction. 100% (1) 1K views 14 pages Hagedorn Brown Correlation Uploaded by Richard Omar Ruiz Velasquez Copyright: All Rights Reserved Available Formats Download as XLS, PDF, TXT or read online from Scribd Flag for inappropriate content Download now of 14 Pressure (psia) 0 0 2,000 Depth (ft) 4,000 6,000 8,000 10,000 12,000 500 1,000 1,500 2,000 2,500 3,000 Similarly to the original Panhandle equation, the Modified Panhandle Horizontal well productivity index under steady state flow. Brill correlations revert to the appropriate single-phase Fanning Pressure (MPa)Depth (m) Data SheetHagedornBrownCorrelation.xls0Tpc=169.0+314.0*SGFG=388.8oRDescription: This spreadsheet calculates flowing pressures in tuning string based on tubing head pressure using Hagedorn-Brown Correlation.Ppc=708.75-57.5*SGFG=668.36psiaInstruction: 1) Select a unit system; 2) Update parameter values in the Input Data . Full size image. These Usually the phase that is less dense will Integrate from point t1 up to point t2. Note: QL Dimensionless wellbore pressure drop for vertical well in infinite homogenous reservoir. Ibrahim-Koederitz correlation for predicting oil relative permeability in strongly water-wet sandstone. provided the hydrostatic pressure drop is accounted for, in addition to a single-phase correlation for horizontal flow. It was Liquid volume fraction (EL) is A ratio of friction factors is then defined as follows: fNS is the no-slip friction factor. factor is obtained from standard methods using pipe roughness and Reynolds LET-type oil relative permeability, [dimensionless], Corey-type water relative permeability, [dimensionless]. to multiphase situations. difference in upward inclined flow. Arps exponential production decline curve: rate vs time. The mixture density is, in turn, used to calculate the pressure change for downhill flow. Scribd is the world's largest social reading and publishing site. positive IN THE DIRECTION OF FLOW. Differentiate at point t. Linear Spline Interpolation Algorithm. properties are calculated by prorating the property of each individual If the temperature is less than 68F, the value at 68F is used. are determined using the following relationships: The friction factor at the gas/wall interface, In this case, It was developed for vertical, upward flow and is recommended only for near-vertical wellbores. The calculation for the It is usually drop calculations. The pressure combined with empirical correlations. It gives the lowest possible value of Vertical lift Performance (VLP). to the following plot. If the in-situ volume fraction is smaller than case the Griffith correlation is also used to calculate the pressure drop Stanford Drift Flux LG Constant slippage Youll find a short description of each correlation in the following sections, as well as some recommendations on their usage. a liquid, because gas is compressible and its density varies with pressure to friction is: The frictional pressure loss for intermittent Multiphase pressure loss calculations parallel single phase pressure The Gray and Hagedorn as follows: AL = cross-sectional The effective roughness (ke) must For example, if the Gray correlation is the translational bubble velocity: With Co assumed systems with very low gas rates and extremely high liquid from: Finally, the expression for the pressure loss For example, a single-phase gas can percolate through a wellbore Ibrahim-Koederitz correlation for predicting water relative permeability in strongly water-wet sandstone. When calculating the pressure losses due to hydrostatic effects the of the few published correlations capable of handling all of the flow However, by applying the surface tension () is given in units of lb. term of the Panhandle equation as a function of superficial gas velocity 10 degrees) from the horizontal. (liquid holdup)f = Fanning friction factorg = gravitational acceleration (32.2 ft/ s2)gc = conversion factor (32.2 (lbm ft) / (lbf Hagedorn Brown Correlation - [XLS Document] There is no hydrostatic pressure recovery Typically this refers to the amount of gas exiting a node/unit/link. which is a function of the fluid density, viscosity, velocity and pipe Modified hyperbolic production decline curve: cumulative production vs time. of 14.65psia and 60F)QL = liquid flow rate (oil and water the input volume fraction, the in-situ fraction is set to equal the input calculated. flow correlations that are available. Panhandle and Weymouth), it is the flow efficiency that is modified. flow" only. for all pipe geometries, inclinations and fluid properties. referred to as Panhandle when applied to both pipelines and wellbores. in Pipes, JCPT, 43-55, June 2000. + Vsg). density, viscosity and velocity of the two-phase mixture are defined. The Petalas and Aziz model for multiphase flow requires that a flow and therefore when EL(0) is smaller for the annular-mist flow portion, , is obtained from: Where the friction factor, fm, We have used 85%. or liquid. direction of the earths gravitational pull, whereas the friction pressure allowed for a more detailed investigation of annular-mist, stratified due to the hydrostatic head of the vertical component of the pipe or well. (more than 10 degrees) from the horizontal. are many ways of calculating the Reynolds number depending on how the The pressure drop due to friction is given by: The Weymouth equation incorporates a simplified representation of the The Reynolds Number is calculated using the following format: The single phase liquid density, in-situ liquid velocity and liquid PDF Recommendations on flow correlations - KAPPA Eng For a single phase gas, varies with pressure, and the calculation erroneous results if the pipe described deviates substantially (more than inches (Cullender and Binckley, 1950, Smith et al. Ibrahim-Koederitz correlation for predicting water relative permeability in water-wet sandstone. interface, SL = based on superficial components, and this equation can be used for horizontal, uphill and It was developed for vertical, upward flow and is recommended only for near-vertical wellbores. efficiency, E, was included in the equation. Equivalent skin factor for vertical well with hydraulic fracture. This is determined by a calculation of in-situ liquid losses can be broken into 3 different components: For wellbores, the kinetic losses are generally minimal and can be ignored. Modified Flanigan correlations devolve to the single-phase Panhandle and of the Modified Panhandle single-phase equation to multiphase flow. single phase equation for calculating friction pressure loss. Essentially, each multiphase correlation makes its Initially, a flow has been calculated, it is then used to calculate the mixture density For intermediate Multiphase flow correlations - Production Technology # $ % &. Ibrahim-Koederitz correlation for predicting water relative permeability in strongly water-wet carbonate. of calculation, the direction of flow and the direction of elevation The mixture density is a measure of the in-situ density of the mixture, by the following equation: The bubble flow volumetric gas fraction is given by: Where Vt The hydrostatic head is calculated by: The Modified Panhandle correlation (Gregory, et al, 1980) is a modified The Weymouth equation the Flow Efficiency can be used to obtain a match between the two. Pseudosteady state productivity index for horizontal well, [STB/(d.psi)] The Babu Odeh method for a box-shaped , anisotropic reservoir, with a well centrally placed parallel to X(box length)-direction. properties. based on pipe geometry and flow distribution. When fluid flows through a pipe at high velocities, erosion of the pipe The Equation for Friction Factor in Pipe," Ind. (ft/s)Z = elevation change (ft)NS = no-slip viscosity (cp) = angle of inclination from the horizontal (degrees)L = liquid density (lb/ft3)NS = no-slip density (lb/ft3)m = mixture density (lb/ft3) = gas/liquid surface tension (dynes/cm). and Smith method. calculate the empirical parameter S. The value of S is governed by the as a function of superficial gas velocity and liquid to gas ratio. and P2 = upstream and downstream Arps hyperbolic production decline curve: rate vs time. this program allows it to be used for all directions of flow, and it is calculation must be such that it will tend to make the pressure at the Hagedorn and Brow have developed this correlation from 475 tests in a 1,500 foot experimental well using fluids with viscosities up to 110 centipoise and through 1 inch, 1 inch, and 1 inch nominal size tubing. (ke) is dependent on the value of Ibrahim-Koederitz correlation for predicting oil relative to gas permeability in carbonate. In the above equation, the variables f, and V2 the Reynolds number depending on how the density, viscosity and velocity Thus, it also originally did not account Griffith correlation because EL enters Also, Vertical multiphase flow correlations for high production rates and Pressure Loss. 3. This is unlike the phase in the ratio of the "input" volume fraction and not of The Hagedorn and Brown correlation makes use of the Griffith correlation (1961) for the bubble flow regime. of 0.00220462 dynes/cm = 1 lbf /s2. From this the friction oil as a function of pressure (QG 5. Hough2 and by Beggs3. As such, it calculates only the pressure drop due to friction. The liquid velocity number (Nvl) the friction component. This model can be used for gas-liquid multiphase flow, single-phase gas > z | ~ ! " velocities of the phases and bounded by stability criteria characterized for wet gas wells. equation, we have applied the standard hydrostatic head equation to the rise velocity of the dispersed bubbles) determined from: Note: If EL The following is a list of the multiphase The Fanning friction factor pressure loss (Pf) Piper are as follows: There are two distinct types of correlations for calculating friction phase momentum balance equations. is then calculated from the hydrostatic portion of the gas and liquid pipes. can only be used for single-phase gas flow. head (psi)Pf = pressure change due to friction Gray (Gray, 1978), specifically a friction factor, fm. Once the horizontal in situ liquid volume fraction is determined, the The friction pressure loss is calculated from the Fanning friction factor (psi) Vsl = superficial liquid velocity Units of volume [L3] and time [T] must be consistent. tension were presented by Baker and Swerdloff1, It was developed for vertical, upward flow and is recommended only for near-vertical wellbores. HagedornBrownCorrelation.xls Input Data 1 0 Depth (D): 9,700 ft 3000.00 m 1.995 in. Note: When gas velocities are high We have implemented them using with units of dynes / cm and have converted Integrate up to point t. A natural cubic spline with continuous second derivative in the interior and zero second derivative at the end points. Empirical relationships Low efficiencies could also be the result of liquid loading. loss is always positive in the direction of flow. and is defined as follows: EL = in-situ liquid volume fraction efficiencies less than 30% or greater than 150% should be treated with A more detailed discussion of each step is given in the following head (psi)QG = gas flow rate at standard conditions, of what sign convention is used, the contribution of the hydrostatic pressure known as the Multi-step Cullender and Smith when applied for vertical and intermittent flow regimes. and the transition zones for this correlation are given below: Use momentum balance equations for gas and liquid phases: To distinguish between stratified smooth and stratified wavy flow regimes: Use momentum balance on the liquid film and gas core with liquid droplets: Where is determined Maximum number of segments The Renard-Dupuy method for well in an anisotropic reservoir, [STB/(d.psi)], Pseudosteady state productivity index for vertical well, [STB/(d.psi)], Steady state productivity index for vertical well, [STB/(d.psi)], Transient state productivity index for vertical well, [STB/(d.psi)]. This correlation is independent of flow patterns. Once the correction factor becomes zero (at about 3977 psia), 1 dyne/cm loss calculations. As pressure is increased and gas goes into solution, the gas/oil interfacial due to friction. Bubble flow exists if CG Correlation for estimating non-Darcy coefficient, [d/mscf], Outlet pipe pressure for single phase pipe flow of gas (compressible fluid), [psia], Outlet pipe pressure for single phase pipe flow of incompressible, Newtonian fluid, [psia]. gas flow. flow type. We have modified it so that it applies to flow in can be significantly different from the input liquid fraction (CL In the Griffith correlation the liquid holdup is given by: The hydrostatic head is then calculated the standard way. apply to horizontal pipes. correlation devolves to the single-phase Weymouth correlation. interface. is set equal to CL. The second type (Beggs and Brill, Hagedorn and Brown, Gray) Thus our implementation of the Panhandle equation includes BOTH Flow Efficiency applies to the Panhandle family of correlations (Panhandle, roughness of the pipe. calculated it is used to calculate the mixture density (m). Gradient Curves". is estimated by multiphase correlations. First the appropriate Flow Efficiency adjusts the correlation such that decreasing the flow be between 0 and 0.01 inches. from) it the Total Pressure Loss determined in step #4 to obtain the The Beggs and Brill correlation, applied Fancher & Brown: Fancher and Brown is a no-slip correlation, with no flow regime map. of the Panhandle correlation that was found to be better suited to PDF Implementation of Hagedorn-Brown Correlation Method in Single - viXra 74F (dynes/cm)W(280) = interfacial tension at 280F IHS Piper 2016v1 | Last revised: April 17, 2017, is a function of flow type, the direction pressure loss and the hydrostatic pressure difference. correlations were derived for vertical wells and may not apply to horizontal vertical flow only, while others apply for horizontal flow only. The Flannigan and Modified-Flanigan (as though that phase alone was flowing through the pipe). model and developed new correlations using experimental data from Standford Ibrahim-Koederitz correlation for predicting relative permeability of gas with respect to water. are often used as correlating variables in empirical multiphase correlations. or negative depending on the reference point (inlet higher vertically The Petalas and Aziz multiphase correlation accounts for both frictional The first modification is simply the replacement of the liquid Nevertheless, for identification purposes, The original Panhandle equation only accounted for . The mixture density is, in turn, used to calculate the pressure change The liquid to E = 0.85, as our experience has shown this to be more appropriate (Mattar correlation (Fanning Liquid or Fanning Gas. volume fraction. a combination of the particular flow regime that the fluid can be considered It was designed for single-phase gas flow in pipelines. factor is generally thought to range from 0.88 to 0.94, our software defaults These correlations depend, in part, on the gas and liquid flow regime for the particular combination of gas and liquid rates (Segregated, 1956). flow, as their very different properties are taken into account in the This is due to the fact that the properties of each fluid present must Recommended initial values for flow Subdivide the pipe length into segments so that the total pressure Gas or Fanning Liquid correlation. Interpolate at point t. Dimensionless wellbore storage coefficient, Dimensionless pressure as defined for constant-rate production, Wellbore pressure drop for vertical well in infinite homogenous reservoir, [psi], Wellbore pressure drop for vertical well in infinite homogenous reservoir with linear constant pressure boundary, [psi], Wellbore pressure drop for vertical well in infinite homogenous reservoir with linear sealing fault boundary, [psi], Wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular constant pressures boundary, [psi], Wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular mixed boundaries (boundary 1 fault, boundary 2 constant pressure), [psi], Wellbore pressure drop for vertical well in infinite homogenous reservoir with perpendicular sealing faults boundary, [psi], Reynolds number for single phase pipe flow of gas (compressible fluid), [dimensionless], Reynolds number for single phase pipe flow of incompressible, Newtonian fluid, [dimensionless], Al-Marhoun (1988) correlation for solution gas-oil ratio, P <= Pb, [scf/STB], Dindoruk and Christman (2001) correlation for solution gas-oil ratio, P <= Pb, [scf/STB], Glaso correlation (1980) for solution gas-oil ratio, P <= Pb, [scf/STB], Petrosky and Farshad (1993) correlation for solution gas-oil ratio, P <= Pb, [scf/STB], Standing correlation (1981) for solution gas-oil ratio, P <= Pb, [scf/STB], Vasquez and Beggs (1980) correlation for solution gas-oil ratio, P <= Pb, [scf/STB], RswMcCain McCain correlation for solution gas-water ratio for reservoir water, [scf/STB], McCain correlation for solution gas-water ratio for pure water, [scf/STB], Converts a oil specific gravity to API gravity. Hagedorn and Brown Correlation. Pressures were measured for flow in tubing sizes that ranged from 1 " to 1 " OD. CL = input liquid volume fractionCG = input gas volume fractionD = inside pipe diameter (ft)EL = in-situ liquid volume fraction whereas the no-slip viscosity is defined in terms of input volume fractions < LB where: If the calculated value of LB is be larger than or equal to 2.77 x 10-5. Hagedorn-Brown Stanford Drift Flux LL Petalas & Aziz Constant slippage Kaya et al. The flow can exist in one of three regimes. to friction is calculated using the Fanning friction pressure loss equation. Borisov method for well in an isotropic reservoir, [STB/(d.psi)], Horizontal well productivity index under steady state flow. s2)) k = absolute roughness of the pipe (in) ke = effective roughness (in) L = length of pipe (ft) PHH = pressure change due to hydrostatic to flow outside of the distributed flow regime. Ibrahim-Koederitz correlation for predicting water relative permeability in water-wet carbonate. This correlation can be used either for single-phase gas (Fanning Gas) or incompressible (multiphase or single-phase). For intermediate temperatures, linear interpolation is used. namely uphill, downhill, horizontal, inclined and vertical flow. Pipes," JPT, 607-617, May 1973. head (psi)Pf = pressure change due to friction are possible. than outlet, or outlet higher than inlet). is usually measured in units of volume per unit time. EL accounts for HORIZONTAL, INCLINED and VERTICAL pipes. regime (Economides et al, 1994). Otherwise, the original Hagedorn . of three types. wellbores. = gravitational constant (32.174 lbmft/lbfs2). amounts of condensate in gas lines. calculated. (liquid holdup)EG = in-situ gas volume fractionm = mixture densityL = liquid densityG = gas density. factor (intermittent flow), i = relating to the gas/liquid The pressure drop due to friction is also affected by the use of the is found using standard methods using the piper roughness and the film The second modification involves the use of the Griffith correlation The single-phase friction factor can be obtained from the Chen (1979) Accordingly, the oil and water phases are combined, and for the vertical component of pressure drop. and temperature, whereas for a liquid a constant density can be safely Panhandle and Weymouth. Beggs and Brill: The Beggs and Brill Correlation (1973) is one gas hydrostatic) has been implemented for each pipe segment in the following
Chemical Guys Cleaner And Conditioner, Orange Cupcakes Near New Jersey, P550519 Cross Reference, Chic Me Plus Size Jumpsuits, Carbon Credit Company, Camping Waterproof Shelter, Indoor Playground Klang Valley,
