Well Model
The well model file is saved with the ".owm" extension in keyword format. Each keyword must be on a separate line; data starts on a new line and ends with the "/" character.
1.Well description
Well description (key - value)
WELLNAME -- Well name (in 'quotes')
COMPANY -- Company name (in 'quotes')
FIELD -- Field name (in 'quotes')
BUSH -- Well pad/platform (in 'quotes')
ENGINEER -- Engineer (in 'quotes')
DATE -- Date (without quotes in format DD.MM.YYYY without time)
COMMENT -- Engineer (in 'quotes', in one line)
*/
WELLDESCRIPTION
[Parameter type] [Parameter value]
WELLNAME 'well_123'
COMPANY 'OIS-Bright'
FIELD 'Chatylkinskoye'
BUSH '13-3'
ENGINEER 'Ivanov I.I.'
DATE 10.08.2023
COMMENT 'Arbitrary comment in one line'
/
2.PVT file list
Fluid models from these files are linked to wells by model name. The fluid model type (black oil or compositional) is specified in the ".ofm" file. Each file name must be on a separate line
PVTLIST
'FluidModel.ofm'
/
3.Equipment Catalog
EQLIST
Equipment.eqp
/
4.Well data (key - value)
FLUIDTYPE - fluid type: OILWATER || DRYWETGAS; in Petex terms OILWATER=Oil&Water, DRYWETGAS=Dry&WetGas (added only to filter linked PVT models!)
PVTMODEL - PVT model type - BLACKOIL || FULLCOMP - Black Oil, Fully Compositional
PURPOSE - well purpose: OIL - oil || INJ - water injection || GAS - gas || GASINJ - gas injection
LIFTTYPE - lift method: UNDEF - none || NFL - natural flow || SRP - SRP || ESP - ESP, ESPCP - PCP || RDPCP - RDPCP || GL - gas lift || DGL - dual string gas lift
FLOWTYPE - flow type: TUBING - tubing flow (by default) || ANNULAR - annular flow
INJTEMP - injected fluid temperature, °C
ALTITUDE - rotary table altitude, m (values above sea level are positive)
DEPENDINCL - calculated (dependent) deviation survey parameter: TVD - TVD (by default) || ANGLE - zenith angle
PARALLEL - number of parallel calculation cores (by default 0 - all available cores are used)
BOTTOMTEMPMODE - bottomhole temperature calculation mode: RESERVOIR - taken equal to reservoir temperature (by default) || FROMIPR - calculated from the temperature IPR
*/
WELLPROPS
FLUIDTYPE OILWATER
PVTMODEL BLACKOIL
PURPOSE OIL
LIFTTYPE ESP
FLOWTYPE TUBING
INJTEMP 20
ALTITUDE 111.5
DEPENDINCL TVD
PARALLEL 0
BOTTOMTEMPMODE RESERVOIR
/
5.Completions
NAME - reservoir/completion name
DEPTH - completion depth (MD), m
TEMPRES - reservoir temperature, °C
PVT - PVT region name
PVTCOMP - compositional PVT model name without extension in 'quotes' from the list PVTCOMPLIST
*/
COMPLETIONS
[NAME] [DEPTH] [TEMPRES] [PVT] [PVTCOMP]
'pl_1' 2056.0 70.0 'PVT1' 'PVT'
'pl_2' 2560.0 70.0 'PVT1' 'PVT'
/
6.IPR
6.1.Vogel IPR
[COMPLETION name] [Productivity index (PI), m³/day/atm.] [Reservoir pressure, atm] [Saturation pressure, atm] [Water cut, %]
*/
IPRVOGEL
'pl_1' 1.5 200.0 120.0 17.1
'pl_2' 0.9 195.1 120.0 35.4
/
6.2.Forchheimer IPR
[COMPLETION name] [Coefficient A] [Coefficient B] [Reservoir pressure, atm]
*/
IPRFORCHHEIMER
'pl_1' 1.4 0.6 200.0
'pl_2' 0.8 0.1 195.1
/
6.3.IPR C and N
[COMPLETION name] [C coefficient] [N coefficient] [Reservoir pressure, atm]
*/
IPRCANDN
'pl_1' 1.4 0.9 200.0
'pl_2' 0.8 0.5 195.1
/
6.4.Forchheimer IPR with pseudo pressure
[COMPLETION name] [Coefficient A] [Coefficient B] [Reservoir pressure, atm]
*/
IPRFORCHHEIMERPSEUDO
'pl_1' 1.4 0.6 200.0
'pl_2' 0.8 0.1 195.1
/
6.5.IPR no flow boundaries
[COMPLETION name] [Permeability, mD] [Formation thickness, m] [Wellbore radius, m] [Horizontal anisotropy] [Vertical anisotropy] [Horizontal wellbore length, m] [Formation length, m] [Formation width, m] [Distance from boundary to well center (length), m] [Distance from boundary to well center (width), m] [Distance from boundary to well center (depth), m] [Skin factor] [Reservoir pressure, atm] [Saturation pressure, atm] [Water cut, %]
*/
IPRNOFLOWBOUND
'pl_1' 10.0 30.0 0.1 1.0 0.1 1000.0 5000.0 5000.0 2500.0 2500.0 15.0 0.0 320.0 100.0 0.0
/
6.6.IPR transverse vertical fractures
[COMPLETION name] [Permeability, mD] [Formation thickness, m] [Wellbore radius, m] [Horizontal anisotropy] [Vertical anisotropy] [Horizontal wellbore length, m] [Formation length, m] [Formation width, m] [Distance from boundary to well center (length), m] [Distance from boundary to well center (width), m] [Distance from boundary to well center (depth), m] [Skin factor] [Fracture half-length, m] [Dimensionless fracture conductivity] [Number of fractures] [Reservoir pressure, atm] [Saturation pressure, atm] [Water cut, %]
*/
IPRTRANSVERTFRAC
'pl_2' 10.0 30.0 0.1 1.0 0.1 1000.0 5000.0 5000.0 2500.0 2500.0 15.0 0.0 800.0 6.2 2 320.0 100.0 0.0
/
7.Table of points for matching to actual data
The first row is the COMPLETION name
The second and subsequent rows:
[Liquid flow rate, m³/day (or gas flow rate thsd m³/day)] [Bottomhole pressure, atm]
*/
MATCHPOINTS
'pl_1'
10.0 90.0
15.0 75.0
/
8.Correlation types: HAGEDORNBROWN, AZIZ, BEGGSBRILL, ORKISZEWSKI, DUNSROS, ANSARI
VERTFLOW - vertical correlation name
HORFLOW - horizontal correlation name
ANGLE - switch angle, °
*/
FLOWCORR
VERTFLOW HAGEDORNBROWN
HORFLOW BEGGSBRILL
ANGLE 45.0
/
9.Coefficients for thermal calculations
TEMPMODEL BALANCE -- BALANCE || APPROX || IMPROVED - Enthalpy balance, Rough Approximation, or Improved Approximation (by default APPROX)
OVERALLCOEF - Overall heat transfer coefficient [W/(m²*K)]
CASINGCOEF - Casing heat transfer coef. [W/(m²*K)]
TUBINGCOEF - Tubing heat transfer coef. [W/(m²*K)]
CEMENTCOEF - Cement heat transfer coef. [W/(m²*K)]
ROCKCOEF - Rock heat transfer coef.
ROCKTHERMCONDUCTIVITY - Thermal conductivity of rock [W/(m*K)]
CPOIL - Heat capacity of oil [J/(kg*K)] (by default 2220)
CPGAS - Heat capacity of gas [J/(kg*K)] (by default 2130)
CPWATER - Heat capacity of water [J/(kg*K)] (by default 4180)
*/
HEATTRANSFER
TEMPMODEL BALANCE
OVERALLCOEF 15.5
CASINGCOEF 25.0
TUBINGCOEF 25.0
CEMENTCOEF 0.42
ROCKCOEF 1.4
ROCKTHERMCONDUCTIVITY 1.0
CPOIL 2219
CPGAS 2135.27
CPWATER 4186.8
/
10.Temperature gradient (table)
[TVD, m] [temperature, °C] -- ground temperature must be specified (TVD = 0)
*/
THERMALGRAD
0.0 5.0
2000.0 73.0
/
11.Specifying the choke and its parameters.
CHOKETYPE - choke specification method (DIAM || DPCHOKE).
DIAM - choke diameter value [mm].
DPCHOKE - choke pressure drop value [atm].
CHOKEMODEL - choke model type (ELF || Venturi || Sachdeva), required column.
*/
CHOKE
CHOKETYPE DPCHOKE
DPCHOKE 1.92
CHOKEMODEL Venturi
/
12.Specifying choke parameters for the Venturi model
INLETDIAM - inlet diameter [mm] (by default 8)
Note — the choke diameter specified with DIAM in the CHOKE and CHOKEPERFORMANCE keywords is used as the vena contracta diameter (Diameter VC)
HEIGHT - geometric head difference DZ [mm] (by default 0)
DISCHARGE - discharge coefficient [n/a] (by default 1)
OFFSETDP - piezometric head difference [atm] (by default 0)
*/
CHOKEVENTURI
INLETDIAM 8
HEIGHT 10
DISCHARGE 1.1
OFFSETDP 0.0
/
13.Specifying parameters for virtual metering based on the choke model
CHOKEPREDICTION - calculated parameter (FLOWRATE || PRESSUREDROP || CHOKESETTING)
CHOKEMODEL - choke model type (ELF || Venturi || Sachdeva), required column, exactly as in the keyword CHOKE
GOR - gas-oil ratio, m³/m³
WCT - water cut, %
WGR - water-gas ratio, m³/m³
CGR - condensate-gas ratio, m³/m³
PRESSIN - inlet pressure, atm (InletPressure)
PRESSOUT - outlet pressure, atm (OutletPressure)
TEMPIN - inlet temperature, °C (Inlettemperature)
FLOWRATE - liquid flow rate, m³/day (or water injection rate, m³/day, or gas production/injection rate, thsd m³/day)
DIAM - choke diameter, mm
*/
CHOKEPERFORMANCE
CHOKEPREDICTION FLOWRATE
CHOKEMODEL ELF
GOR 75
WCT 10
WGR 1.35e-3
CGR 2.84e-5
PRESSIN 20
PRESSOUT 15
TEMPIN 26.7
FLOWRATE 450
DIAM 20
/
14.Specifying parameters for ESP Design
PUMPDEPTH - ESP setting depth, m [by default 0.0]
PRESSTUBING - tubing head pressure, atm [by default 1.0]
WCT - Water cut, % [by default 0.0]
GOR - Gas oil ratio, m³/m³ [by default 0.0]
RATETYPE - fluid type (LIQUID, OIL, GAS) [by default LIQUID]
FLOWRATE - Oil/liquid flow rate (or gas flow rate, thsd m³/day), m³/day [by default 0.0]
FREQUENCY - ESP frequency, Hz [by default 50.0]
PUMP - pump section without number of stages [by default '']
WEARFACTOR - wear factor, n/a [by default 1.0]
MAXOUTERDIAM - maximum outer diameter, mm [by default 120.0]
*/
ESPDESIGN
PUMPDEPTH 2000
PRESSTUBING 5
WCT 12.2
GOR 45.8
RATETYPE LIQUID
FLOWRATE 75
FREQUENCY 55
PUMP 'BORETS 5-ESPM5-60'
WEARFACTOR 0.95
MAXOUTERDIAM 120
/
15.Well deviation survey
DEPTH - measured depth (MD), m
TVD - TVD, m
ANGLE - zenith angle, °
AZIMUTH - azimuth, °
*/
INCLINOMETRY
[DEPTH] [TVD] [ANGLE] [AZIMUTH]
0.0 0.0 0.0 0.0
1000.0 850 3.1 15.6
1500.0 1320 5.6 37.1
/
16.Production casing data
CASING
[Pipe name] [top depth, m] [bottom depth, m] [cement sheath diameter, mm] [pipe outer diameter, mm] [pipe inner diameter, mm] [roughness, mm]
'7-28' 0.0 2005.0 8.5 152 146 0.0065
'6.5-28' 1800.0 2746.0 8.0 152 146 0.0065
/
17.Tubing data
TUBING
[Pipe name] [bottom depth, m] [pipe outer diameter, mm] [pipe inner diameter, mm] [roughness, mm]
'7-28' 1415.8 67.0 62.0 0.0065
'6.5-28' 2083.04 67.0 62.0 0.0065
/
18.Inner tubing string data
TUBINGINNER
[Pipe name] [bottom depth, m] [pipe outer diameter, mm] [pipe inner diameter, mm] [roughness, mm]
'7-28' 1415.8 67.0 62.0 0.0065
'6.5-28' 2083.04 67.0 62.0 0.0065
/
19.FLOWCORRMATCHPARAMS
Specifies matching parameters for multiphase flow correlations
The first column is the correlation name: HAGEDORNBROWN, AZIZ, BEGGSBRILL, ORKISZEWSKI, DUNSROS, ANSARI
The second column is the friction correction factor (by default 1.0)
The third column is the gravity correction factor (by default 1.0).
If a correlation is not listed in the table, its correction factors equal the default values.
By default, default coefficients are set for all pipes for all correlations.
*/
FLOWCORRMATCHPARAMS
HAGEDORNBROWN 1.21 1.02
AZIZ 1.0 1.30
BEGGSBRILL 2.41 1.58
ORKISZEWSKI 1.33 1.14
DUNSROS 1.46 2.01
ANSARI 3.09 1.81
/
20.General data for VFP table calculation
PRESSTUBING - tubing head pressure, atm
WCT - water cut, %
GOR - gas-oil ratio, m³/m³
WGR - water-gas ratio, m³/m³
CGR - condensate-gas ratio, m³/m³
RATETYPE - fluid type (LIQUID, OIL, GAS)
REPORTNODE - VFP calculation node (BOTTOMHOLE, GAUGE), by default BOTTOMHOLE
REPORTNODENUM - gauge number when using REPORTNODE=GAUGE
CALCEQUIPMENT - run electrical equipment calculation (pump, downhole motor, cable) (1 - calculate; 0 - do not calculate (by default))
*/
VFPBASECASE
PRESSTUBING 10.0
WCT 25.0
GOR 50.0
RATETYPE LIQUID
REPORTNODE GAUGE
REPORTNODENUM 1
CALCEQUIPMENT 0
/
21.General list of variables available for sensitivity analysis (IpmSensitivityCasesType)
PRESSTUBING - tubing head pressure, atm
PRESSBOTTOM - bottomhole pressure, atm
FLOWRATE - liquid flow rate, m³/day (or oil, m³/day, or gas, thsd m³/day)
WCT - water cut, %
GOR - gas-oil ratio, m³/m³
WGR - water-gas ratio, m³/m³
CGR - condensate-gas ratio, m³/m³
MULTPHASECOR - overall multiphase liquid flow correlation (enumeration, see keyword FLOWCORR) - must not be used with MULTPHASEHORCOR || MULTPHASEVERCOR
MULTPHASEHORCOR - horizontal multiphase liquid flow correlation (enumeration, see keyword FLOWCORR)
MULTPHASEVERCOR - vertical multiphase liquid flow correlation (enumeration, see keyword FLOWCORR)
TUBINGDIAM - tubing diameter, mm
ROUGHNESS - roughness, mm
HEATTRANSCOEF - overall heat transfer coefficient
FREQUENCY - ESP frequency, Hz
STROKELENGTH - stroke length, mm
STROKEPERMIN - stroke rate (per minute), 1/min
INJTEMP - injected fluid temperature, °C
PI - productivity index, m³/day/atm
NUMSTAGES - number of ESP stages (applied to the first section)
PUMPDEPTH - pump setting depth, m
GASCOEF - mechanical gas separation coefficient, %
WEARFACTOR - pump wear factor, n/a
GASLIFTRATE - gas lift rate, thsd m³/day
GASLIFTGLR - gas-liquid ratio for gas lift, m³/m³
VALVEDEPTH - gas lift injection depth, m
PRESSCASINGHEAD - casing head pressure, atm
PRESSRES - reservoir pressure, atm
TEMPCASINGHEAD - casing head temperature, °C
METHANOLINJECTDEPTH - methanol injection depth, m
METHANOLINJECTRATE - water-methanol mixture injection rate, m³/day
METHANOLINJECTFRACTION - methanol mole fraction, %
*/
Value arrays for calculating VFP tables (sample from IpmSensitivityCasesType)
Exception list: PRESSBOTTOM, PI, PRESSRES
*/
VFPCASES
FLOWRATE 10.0 20.0 30.0 40.0 50.0 100.0 200.0
PRESSTUBING 3.0 7.0 11.0 15.0 20.0
WCT 10.0 50.0 90.0
GOR 60.0
FREQUENCY 40.0 50.0
/
22.Parameter types used in the calculation of VFP tables
See the parameter list in the keyword VFPCASES
*/
VFPUSECASES
FLOWRATE
PRESSTUBING
WCT
GOR
/
23.General data for Gradient (Traverse) calculation
CALCULATEDVARIABLE - calculated variable (PRESSTUBING, PRESSBOTTOM, FLOWRATE)
PRESSTUBING - tubing head pressure, atm
PRESSBOTTOM - bottomhole pressure, atm
WCT - water cut, %
GOR - gas-oil ratio, m³/m³
WGR - water-gas ratio, m³/m³
CGR - condensate-gas ratio, m³/m³
FLOWRATE - liquid flow rate, m³/day (or oil, m³/day, or gas, thsd m³/day)
RATETYPE - fluid type (LIQUID, OIL, GAS)
CALCEQUIPMENT - run electrical equipment calculation (pump, downhole motor, cable) (1 - calculate; 0 - do not calculate (by default))
*/
GRADIENTBASECASE
CALCULATEDVARIABLE PRESSBOTTOM
PRESSTUBING 10.0
WCT 25.0
GOR 50.0
FLOWRATE 100
RATETYPE LIQUID
CALCEQUIPMENT 0
/
24.Value arrays for calculating Gradient (Traverse) (sample from IpmSensitivityCasesType)
Exception list: PI, PRESSRES
*/
GRADIENTCASES
PRESSTUBING 3.0 7.0 11.0 15.0 20.0
FLOWRATE 10.0 20.0 30.0 40.0 50.0 100.0 200.0
WCT 10.0 50.0 90.0
GOR 60.0
MULTPHASEHORCOR HAGEDORNBROWN AZIZ BEGGSBRILL
MULTPHASEVERCOR HAGEDORNBROWN BEGGSBRILL
/
25.Parameter types used in the calculation of Gradient (Traverse)
See the parameter list in the keyword GRADIENTCASES
*/
GRADIENTUSECASES
FLOWRATE
PRESSTUBING
WCT
GOR
/
26.General data for nodal analysis calculation
PRESSTUBING - tubing head pressure, atm
WCT - water cut, %
GOR - gas-oil ratio, m³/m³
WGR - water-gas ratio, m³/m³
CGR - condensate-gas ratio, m³/m³
INTERSECTION - left or right intersection point search; takes values:
RIGHT - only the right point is searched (default value)
LEFT - only the left point is searched
CALCEQUIPMENT - run electrical equipment calculation (pump, downhole motor, cable) (1 - calculate; 0 - do not calculate (by default))
*/
NODALBASECASE
PRESSTUBING 10.0
WCT 25.0
GOR 50.0
INTERSECTION RIGHT
CALCEQUIPMENT 0
/
27.Value arrays for calculating nodal analysis (sample from IpmSensitivityCasesType)
Exception list: PRESSBOTTOM
*/
NODALCASES
PRESSTUBING 3.0 7.0 11.0 15.0 20.0
FLOWRATE 10.0 20.0 30.0 40.0 50.0 100.0 200.0
WCT 10.0 50.0 90.0
GOR 60.0
MULTPHASEHORCOR HAGEDORNBROWN AZIZ BEGGSBRILL
MULTPHASEVERCOR HAGEDORNBROWN BEGGSBRILL
PRESSRES 189.0 205.0
/
28.Parameter types used in the calculation of nodal analysis
See the parameter list in the keyword NODALCASES
*/
NODALUSECASES
FLOWRATE
PRESSTUBING
WCT
GOR
PRESSRES
/
29.Keywords for linking ESP equipment to the well model Pump (one) and pump sections (arbitrary number)
*/
ESCPUMP
[Depth, m] [Mech. frequency, Hz] [Wear factor, n/a]
1600 60 1
Sections
[Name] [Number of stages]
'BORETS B 272-450' 100
'BORETS B 272-450 (repaired)' 110
/
Motor (one)
MOTOR
[Name]
'406 PL-200P'
/
30.Dual-string gas-lift data (one record)
GASRATE - Gas lift rate, thsd m³/day
GASTEMP - Gas temperature, degrees Celsius
DEPTH - Gas injection depth, m
*/
DUALGASLIFT
GASRATE 15.0
GASTEMP 30.0
DEPTH 1900.0
/
31.Valve gas-lift data
CALCMETHOD - Gas-lift calculation type (FIXDEPTH (Fixed injection depth) | SPECIFIEDDEPTHS (Select the valve through which injection is possible, with maximum depth))
RATEMETHOD - Injected gas specification method (RATE (Fixed gas rate) | GLR (Gas-Liquid Ratio))
GASRATE - Gas lift rate, thsd m³/day
GLR - Gas-Liquid Ratio, m³/m³
GASTEMP - Injected gas temperature at the wellhead, degrees Celsius
CASINGPRES - Casing head pressure, atm
GASGRAVITY - Gas density at standard conditions [relative density to air] (by default 1)
CO2CONTENT - Content CO2 [%] (by default 0)
H2SCONTENT - Content H2S [%] (by default 0)
N2CONTENT - Content N2 [%] (by default 0)
DPACROSS - Valve pressure drop, atm (by default 0)
*/
VALVEGASLIFT
CALCMETHOD FIXDEPTH
RATEMETHOD RATE
GASRATE 15.0
GLR 120.0
GASTEMP 30.0
CASINGPRES 25.0
GASGRAVITY 1
CO2CONTENT 3
H2SCONTENT 4
N2CONTENT 5
DPACROSS 10.0
/
32.Fixed-depth valve data
DEPTH - Valve depth, m
DIAMETER - Valve diameter, mm
DERATING - Correction factor, %
*/
VALVEFIXDEPTH
DEPTH 2500.0
DIAMETER 12
DERATING 100
/
33.Calculation data with a single valve selected
DEPTH - Valve depth, m
*/
VALVESPECIFIEDDEPTHS
DEPTH
1000.0
1500.0
2000.0
/
34.Keyword for linking an SRP pumping unit to the well model (one record)
Row list:
UNITNAME - Pumping unit name [required field - identifier for adding a pumping unit to the well model from the local catalog]
CRANKROTATION - Rotation direction: CLOCK - clockwise (by default) || ANTICLOCK - counterclockwise
ACTION - Pumping unit condition flag: NEW - new (by default) || OLD - used (affects polynomial selection for efficiency calculation)
PUMPSPEED - Strokes per minute, 1/min (by default 4)
TARGETRATE - Target liquid flow rate, m³/day (by default 10)
CALCMODE - Input calculation parameter: LIQUIDRATE - liquid flow rate, m³/day || PUMPSPEED - strokes per minute, 1/min
PLUNGERDIAM - Plunger diameter, mm (by default 50)
MODFACTOR - Pump volumetric efficiency, n/a (by default 1)
TUBINGANCHOR - Tubing anchor: 0 - no (by default) || 1 - yes
*/
SRPUMP
UNITNAME 'M-640D-305-168'
CRANKROTATION CLOCK
ACTION NEW
PUMPSPEED 4
TARGETRATE 10
CALCMODE LIQUIDRATE
PLUNGERDIAM 50
MODFACTOR 0.85
TUBINGANCHOR 0
/
35.SRP rod configuration
The second row is the column list.
The third and subsequent rows are the table.
Column list:
NAME - Rod name (by default '')
DIAM - Diameter, mm (by default 16)
LENGTH - Length, m (by default 1000)
WEIGHT - Rod weight in air, N/kg (by default 7.8)
STRESS - Allowable stress, atm (by default 980)
DENSITY - Density, kg/m³
ELASTICITY - Elasticity, atm
YOUNGSMODULUS - Young's modulus, atm
*/
RODSET
[NAME] [DIAM] [LENGTH] [WEIGHT] [STRESS] [DENSITY] [ELASTICITY] [YOUNGSMODULUS]
'GOST_16' 16.0 1567.3 7.8 980 2000.0 493570 493570
/
36.Mechanical separation data (one record)
Column list (fixed)
1. Mechanical separation usage flag [Flag]
1 - mechanical separation is included in the calculation
0 - mechanical separation is not included in the calculation (default value)
2. Separator name from catalog [Name]
3. Separation type (MODEL || USERDEFINED) [Type]
MODEL - calculation from catalog data
USERDEFINED - user-defined fixed separation coefficient
4. User-defined separation coefficient, % [Coef.] (by default 0)
*/
SEPARATOR
[Flag] [Name] [Type] [Coef.]
1 'SEP-120' MODEL 80
/
37.Natural separation data (one record)
Column list (fixed)
1. Natural separation model (SHAKIROV || ALHANATI) [Model]
USERDEFINED - user-defined fixed separation coefficient (default value)
SHAKIROV - Shakirov-Mishchenko model
ALHANATI - Alhanati model
2. User-defined separation coefficient, % [Coef.] (by default 0)
*/
NATURALSEPARATOR
[Model] [Coef.]
ALHANATI 30.83
/
38.Cables (arbitrary number) and extension (one)
CABLELINE
[Extension name]
'MLE, ESP flat B 319 KELB P'
[Cable name] [Length, m]
'SL212-PPOTB' 1000
'SL212-PPOTB' 500
/
39.Methanol injection data
ENABLE - Whether methanol injection is used: 1 - used, 0 - not used (by default)
RATE - Water-methanol mixture rate, m³/day
METHANOLFRAC - Methanol mole percent in the water phase, %
TEMP - Injected water-methanol mixture temperature at the wellhead, degrees Celsius
CASINGPRES - Casing head pressure, atm
WATERGRAVITY - Water density at standard conditions, kg/m³ (by default 1000)
DEPTH - Injection depth, m
*/
METHANOLINJECTOR
ENABLE 0
RATE 0
METHANOLFRAC 0
TEMP 0
CASINGPRES 0
WATERGRAVITY 1000
DEPTH 0
/
40.Packer data
ENABLE - include-in-calculation flag (1 - used, 0 - not used). By default 0.
DEPTH - packer setting depth, m. By default 0.
*/
PACKER
ENABLE 1
DEPTH 2342.32
/
41.Gauge list
The first column is the measured setting depth, m
The second column is a comment in 'quotes'
*/
GAUGES
2052.25 '20 meters above the pump'
1895.10 ''
/
42.WELLMATCHPOINTS specifies a table of actual points for well model matching
The first row is well purpose and lift method (a dual key that determines the parameter list)
well purpose matches the PURPOSE value of the WELLPROPS keyword and takes values OIL || INJ || GAS || GASINJ
lift method matches the LIFTTYPE value of the WELLPROPS keyword and takes values UNDEF || NFL || SRP || ESP || ESPCP || RDPCP || GL || DGL
The third and subsequent rows are the data table (the table must contain at least 1 row)
Table format depends on well purpose and lift method
Full column list:
[ENABLED] [DATE] [COMMENT] [TUBP] [TUBT] [GAUGEMD] [GAUGEP] [GAUGET] [RESP] [WCT] [LRATE] [GOR] [FREEGOR] [FREQ] [WFACT] [INTP] [DISP] [GLINJRATE] [WGR] [CGR] [GRATE] [WINJRATE] [GINJRATE] [CASINGHEADP] [INJD]
Common columns:
0th column - ENABLED - include-in-calculation flag: 1 - include (default value); 0 - do not include (Enabled)
1st column - DATE - measurement date (Measurement Date)
2nd column - COMMENT - comment in 'quotes' (Comment)
3rd column - TUBP - tubing head pressure, atm (Tubing Pressure)
4th column - TUBT - tubing head temperature, degrees Celsius (Tubing Temperature)
5th column - GAUGEMD - measurement depth, m (Gauge Measured Depth)
6th column - GAUGEP - pressure at the specified depth, atm (Gauge Pressure)
7th column - GAUGET - temperature at the specified depth, degrees Celsius (Gauge Temperature)
8th column - RESP - reservoir pressure, atm (Reservoir Pressure)
9th column - CASINGP - casing head pressure, atm (Casing Pressure) - used if FLOWTYPE == ANNULAR
Column set depending on PURPOSE and LIFTTYPE:
Table format PURPOSE=OIL && LIFTTYPE=NFL (naturally flowing oil well)
10th column - WCT - water cut, % (Water Cut)
11th column - LRATE - liquid flow rate, m³/day (Liquid Rate)
12th column - GOR - gas-oil ratio, m³/m³ (Gas Oil Ratio)
13th column - FREEGOR - free GOR, m³/m³ (Free Gas Oil Ratio)
Table format PURPOSE=OIL && LIFTTYPE=GL (oil well with valve gas lift)
10th column - WCT - water cut, % (Water Cut)
11th column - LRATE - liquid flow rate, m³/day (Liquid Rate)
12th column - GOR - gas-oil ratio, m³/m³ (Gas Oil Ratio)
13th column - FREEGOR - free GOR, m³/m³ (Free Gas Oil Ratio)
14th column - GLINJRATE - gas-lift gas rate, thsd m³ (Gaslift Injection Rate)
15th column - CASINGHEADP - gas injection casing head pressure, atm (Casing Head Pressure)
16th column - INJD - gas lift injection depth, m (Injection Depth (Measured))
Table format PURPOSE=OIL && LIFTTYPE=DGL (oil well with dual-string gas lift)
10th column - WCT - water cut, % (Water Cut)
11th column - LRATE - liquid flow rate, m³/day (Liquid Rate)
12th column - GOR - gas-oil ratio, m³/m³ (Gas Oil Ratio)
13th column - FREEGOR - free GOR, m³/m³ (Free Gas Oil Ratio)
14th column - GLINJRATE - gas-lift gas rate, thsd m³ (Gaslift Injection Rate)
Table format PURPOSE=OIL && LIFTTYPE=ESP (oil well with ESP)
10th column - WCT - water cut, % (Water Cut)
11th column - LRATE - liquid flow rate, m³/day (Liquid Rate)
12th column - GOR - gas-oil ratio, m³/m³ (Gas Oil Ratio)
13th column - FREEGOR - free GOR, m³/m³ (Free Gas Oil Ratio)
14th column - FREQ - ESP frequency, Hz (Operating Frequence)
15th column - WFACT - pump wear factor, n/a (Pump Wear Factor)
16th column - INTP - pump intake pressure, atm (Pump Intake Pressure)
17th column - DISP - pump discharge pressure, atm (Pump Discharge Pressure)
Table format PURPOSE=GAS && LIFTTYPE=NFL (naturally flowing gas well)
10th column - WGR - water-gas ratio, m³/m³ (Water Gas Ratio)
11th column - CGR - condensate-gas ratio, m³/m³ (Condensate Gas Ratio)
12th column - GRATE - gas flow rate, thsd m³/day (Gas Rate)
Table format PURPOSE=INJ && LIFTTYPE=UNDEF (water injection well)
10th column - WINJRATE - water injection rate, m³/day (Water Injection Rate)
Table format PURPOSE=GASINJ && LIFTTYPE=UNDEF (gas injection well)
10th column - GINJRATE - gas injection rate, thsd m³/day (Gas Injection Rate)
11th column - WGR - water-gas ratio, m³/m³ (Water Gas Ratio)
12th column - CGR - condensate-gas ratio, m³/m³ (Condensate Gas Ratio)
*/
WELLMATCHPOINTS
OIL NFL
[ENABLED] [DATE] [COMMENT] [TUBP] [TUBT] [WCT] [LRATE] [GAUGEMD] [GAUGEP] [GAUGET] [RESP] [GOR] [CASINGP] [FREEGOR]
1 08.01.1986 '6 mm;15/9' 12.5 10.2 1.1 69.6 2020 23 65.5 70 11.3 56.9 0.0
/
WELLMATCHPOINTS
OIL DGL
[ENABLED] [DATE] [COMMENT] [TUBP] [TUBT] [WCT] [LRATE] [GAUGEMD] [GAUGEP] [GAUGET] [RESP] [GOR] [FREEGOR] [GLINJRATE]
1 08.01.1986 '6 mm;15/9' 12.5 10.2 1.1 69.6 2020 23 65.5 70 56.9 0.0 15.5
/
WELLMATCHPOINTS
OIL GL
[ENABLED] [DATE] [COMMENT] [TUBP] [TUBT] [WCT] [LRATE] [GAUGEMD] [GAUGEP] [GAUGET] [RESP] [GOR] [FREEGOR] [GLINJRATE] [CASINGHEADP] [INJD]
1 08.01.1986 '6 mm;15/9' 12.5 10.2 1.1 69.6 2020 23 65.5 70 56.9 0.0 15.5 50.0 1700.0
/
WELLMATCHPOINTS
OIL ESP
[ENABLED] [DATE] [COMMENT] [TUBP] [TUBT] [WCT] [LRATE] [GAUGEMD] [GAUGEP] [GAUGET] [RESP] [CASINGP] [GOR] [FREEGOR] [FREQ] [WFACT] [INTP] [DISP]
1 17.09.1990 '45Hz;24/0' 12.2 15.5 45. 97.3 2020.54 33.5 65.5 110.4 11.3 67.1 10.05 45.0 0.24 33.3 45.5
/
WELLMATCHPOINTS
GAS NFL
[ENABLED] [DATE] [COMMENT] [TUBP] [TUBT] [WGR] [CGR] [GRATE] [GAUGEMD] [GAUGEP] [RESP] [CASINGP]
1 12.09.1965 '8 mm' 22.5 20.2 0.02 0.01 10629 2012.4 23 70 21.3
/
WELLMATCHPOINTS
INJ UNDEF
[ENABLED] [DATE] [COMMENT] [TUBP] [WINJRATE] [GAUGEMD] [GAUGEP] [GAUGET] [RESP] [CASINGP]
1 12.09.1965 '8 mm' 50.3 750.6 2012.4 230 48 350 51.3
/
WELLMATCHPOINTS
GASINJ UNDEF
[ENABLED] [DATE] [COMMENT] [TUBP] [GINJRATE] [WGR] [CGR] [GAUGEMD] [GAUGEP] [GAUGET] [RESP] [CASINGP]
1 25.06.1982 '6.4 mm' 40.3 10750.6 0.02 0.01 1511.0 223 56 313.4 41.3
/
43.Specifies parameters for matching multiphase flow correlations
DEPTHTYPE - depth type for matching the pump efficiency factor (GAUGE || PUMPINTAKE || PUMPDISCHARGE)
A list of correlations follows
The first column is the correlation name: ORKISZEWSKI || DUNSROS || BEGGSBRILL || MUKHERJEEBRILL || HAGEDORNBROWN || ANSARI || GRIFFITH || AZIZ || POETTMANNCARPENTER || GRAY
The second column is the friction correction factor (by default 1.0)
The third column is the gravity correction factor (by default 1.0).
The fourth column is the include-in-calculation flag
*/
CORRELATIONMATCHPARAMS
DEPTHTYPE PUMPINTAKE
HAGEDORNBROWN 1.21 1.02 1
AZIZ 1.0 1.30 1
BEGGSBRILL 2.41 1.58 0
ORKISZEWSKI 1.33 1.14 0
DUNSROS 1.46 2.01 0
ANSARI 3.09 1.81 1
/
44.Correlation comparison data
TESTNUMBER - test number
TUBP - tubing head pressure, atm
WCT - water cut, %
GOR - gas-oil ratio, m³/m³
FREEGOR - free GOR, m³/m³
WGR - water-gas ratio, m³/m³
CGR - condensate-gas ratio, m³/m³
LRATE - liquid flow rate, m³/day
GRATE - gas flow rate, thsd m³/day
WINJRATE - water injection rate, m³/day
GINJRATE - gas injection rate, thsd m³/day
INJTEMP - injected fluid temperature, °C
GLINJRATE - gas-lift gas rate, thsd m³/day
FREQ - ESP frequency, Hz
WFACT - pump wear factor, n/a
CASINGHEADP - casing head pressure, atm
INJD - gas lift injection depth, m
*/
FLOWCORRCOMPAREDATA
TESTNUMBER 1
TUBP 25
WCT 22
GOR 500
FREEGOR 0
WGR 0.0002
CGR 0.0005
LRATE 32
GRATE 0
WINJRATE 100
GINJRATE 15
INJTEMP 20
GLINJRATE 0
FREQ 50
WFACT 0.9
CASINGHEADP 50
INJD 2000
/
45.Specifies depth measurement data for correlation comparison
The second row is the column list.
The third and subsequent rows are the table.
Column list:
DEPTH - measurement depth, m
PRESS - pressure at measurement depth, atm
TEMP - temperature at measurement depth, °C
*/
FLOWCORRCOMPAREPOINTS
DEPTH PRESS TEMP
2000 180 50
2500 200 60
/
46.Data for calculating CO2 corrosion rate using method M-506 (Norsok standard)
*/
CORROSION
PH 7.5 -- pH, dimensionless (by default 7.5)
47.Data for calculating the erosion penetration rate of the inner pipe surface
*/
EROSION
PARTICLEDENS 2000.0 -- particle density, kg/m³ (by default 2000.0)
PARTICLEDIAM 1.0 -- particle diameter, mm (by default 1.0)
PARTICLERATE 0.0 -- particle (sand) rate, kg/day (by default 0.0)
PIPESTRENGTH 250.0 -- pipe material Brinell hardness, kgf/mm² (by default 250.0)
/