NeqSim Well Simulation Guide

This guide covers NeqSim’s well simulation capabilities, providing functionality for production system modeling including IPR models, VLP correlations, operating point calculation, lift curve generation, and multi-layer commingled production.

Overview

NeqSim provides three main classes for well simulation:

Class Purpose Key Features
WellFlow Inflow Performance (IPR) Vogel, Fetkovich, Backpressure, Table, Multi-layer
TubingPerformance Vertical Lift (VLP) Beggs-Brill, Hagedorn-Brown, Gray, Hasan-Kabir, Duns-Ros
WellSystem Integrated Well Model IPR+VLP coupling, Operating point solver, Lift curves

Table of Contents

  1. Inflow Performance Relationships (IPR)
  2. Vertical Lift Performance (VLP)
  3. Operating Point Calculation
  4. Lift Curve Generation
  5. Multi-Layer Commingled Wells
  6. Temperature Models
  7. Integration with Process Simulation
  8. Complete Examples

Inflow Performance Relationships (IPR)

The WellFlow class models reservoir-to-wellbore inflow using several IPR models.

Available IPR Models

1. Production Index (Darcy Flow)

For single-phase or undersaturated liquid flow:

q = PI × (P_res² - P_wf²)

WellFlow well = new WellFlow("producer");
well.setInletStream(reservoirStream);
well.setWellProductionIndex(1.5e-6); // Sm³/day/bar²
well.setOutletPressure(150.0, "bara");
well.solveFlowFromOutletPressure(true);
well.run();
System.out.println("Flow rate: " + well.getOutletStream().getFlowRate("MSm3/day"));

2. Vogel Equation (1968)

For solution-gas-drive reservoirs below bubble point:

q/q_max = 1 - 0.2(P_wf/P_res) - 0.8(P_wf/P_res)²

// From well test data: 500 Sm³/day at 120 bara, reservoir at 200 bara
well.setVogelIPR(500.0, 120.0, 200.0);
well.setOutletPressure(100.0, "bara");
well.solveFlowFromOutletPressure(true);
well.run();

3. Fetkovich Equation (1973)

Empirical model for gas wells:

q = C × (P_res² - P_wf²)^n

well.setFetkovichIPR(0.012, 0.85);  // C and n coefficients

4. Backpressure Equation

Gas wells with non-Darcy (turbulent) flow:

P_res² - P_wf² = A×q + B×q²

Where A is the Darcy term and B is the non-Darcy (rate-dependent) term.

well.setBackpressureIPR(0.5, 0.001);  // A and B coefficients

5. Table-Driven IPR

For measured IPR curves from well tests:

double[] pressures = {50, 80, 100, 120, 150, 180};  // bara
double[] rates = {2.5, 2.0, 1.6, 1.2, 0.7, 0.2};    // MSm³/day
well.setTableIPR(pressures, rates);

6. Loading IPR from CSV File

Load IPR curves from external files (e.g., from well test analysis software):

// Load IPR curve from CSV file
WellFlow well = new WellFlow("producer");
well.setInletStream(reservoirStream);
well.loadIPRFromFile("path/to/ipr_curve.csv");
well.run();

CSV file format:

Pwf(bara),Rate(MSm3/day)
50,5.2
80,4.1
100,3.2
120,2.4
150,1.5
180,0.8
200,0.2

Vertical Lift Performance (VLP)

The TubingPerformance class calculates pressure drop in tubing using multiphase correlations.

Available VLP Correlations

Correlation Best For Flow Patterns
Beggs-Brill All inclinations All patterns
Hagedorn-Brown Vertical oil wells Slug, bubble
Gray Gas wells Mist, annular
Hasan-Kabir Mechanistic All patterns
Duns-Ros Gas-liquid All patterns

Basic VLP Calculation

import neqsim.process.equipment.pipeline.TubingPerformance;
import neqsim.thermo.system.SystemSrkEos;

// Create tubing model
TubingPerformance tubing = new TubingPerformance("tubing");
tubing.setInletStream(feedStream);
tubing.setDiameter(0.1);          // 100 mm ID
tubing.setLength(3000.0);         // 3000 m TVD
tubing.setInclination(90.0);      // Vertical
tubing.setRoughness(0.00005);     // 50 microns

// Select correlation
tubing.setCorrelationType(TubingPerformance.CorrelationType.BEGGS_BRILL);

// Run calculation
tubing.run();

// Get results
double outletPressure = tubing.getOutletStream().getPressure("bara");
double pressureDrop = tubing.getPressureDrop();

Setting VLP Correlation

// Beggs-Brill (default, all inclinations)
tubing.setCorrelationType(TubingPerformance.CorrelationType.BEGGS_BRILL);

// Hagedorn-Brown (vertical oil wells)
tubing.setCorrelationType(TubingPerformance.CorrelationType.HAGEDORN_BROWN);

// Gray (gas wells)
tubing.setCorrelationType(TubingPerformance.CorrelationType.GRAY);

// Hasan-Kabir (mechanistic)
tubing.setCorrelationType(TubingPerformance.CorrelationType.HASAN_KABIR);

// Duns-Ros (gas-liquid)
tubing.setCorrelationType(TubingPerformance.CorrelationType.DUNS_ROS);

Table-Based VLP

Use pre-calculated or measured VLP curves instead of correlations:

// Set VLP table programmatically
double[] flowRates = {0.5, 1.0, 2.0, 3.0, 4.0, 5.0};  // MSm³/day
double[] bhpValues = {85, 92, 115, 145, 182, 225};    // bara
double whp = 50.0;  // Wellhead pressure (bara)

TubingPerformance tubing = new TubingPerformance("tubing");
tubing.setTableVLP(flowRates, bhpValues, whp);

// Interpolate BHP for a given flow rate
double bhp = tubing.interpolateBHPFromTable(2.5);  // MSm³/day

Loading VLP from CSV File

Load VLP curves from external files (e.g., from PROSPER, Pipesim, or other tools):

TubingPerformance tubing = new TubingPerformance("tubing");
tubing.loadVLPFromFile("path/to/vlp_curve.csv", 50.0);  // WHP = 50 bara

// Use interpolation
double bhp = tubing.interpolateBHPFromTable(3.0);  // Get BHP at 3 MSm³/day

CSV file format:

FlowRate(MSm3/day),BHP(bara)
0.5,85
1.0,92
2.0,115
3.0,145
4.0,182
5.0,225

Operating Point Calculation

The WellSystem class finds the intersection of IPR and VLP curves using an optimized bisection algorithm.

Using WellSystem for Operating Point

import neqsim.process.equipment.reservoir.WellSystem;
import neqsim.process.equipment.stream.Stream;

// Create reservoir stream
Stream reservoirStream = new Stream("reservoir", reservoirFluid);
reservoirStream.setFlowRate(5000.0, "Sm3/day");
reservoirStream.setTemperature(100.0, "C");
reservoirStream.setPressure(280.0, "bara");

// Create well system with inlet stream
WellSystem well = new WellSystem("production_well", reservoirStream);

// Configure IPR model
well.setIPRModel(WellSystem.IPRModel.PRODUCTION_INDEX);
well.setProductionIndex(2.5e-6, "Sm3/day/bar2");

// Configure tubing (VLP)
well.setWellheadPressure(60.0, "bara");
well.setTubingDiameter(4.0, "in");
well.setTubingLength(3000.0, "m");
well.setInclination(85.0);  // degrees from horizontal

// Configure temperature model
well.setBottomHoleTemperature(100.0, "C");
well.setWellheadTemperature(50.0, "C");

// Find operating point
well.run();

// Results
double flowRate = well.getOperatingFlowRate("Sm3/day");
double bhp = well.getBottomHolePressure("bara");
double drawdown = well.getDrawdown("bar");
System.out.println("Operating point: " + flowRate + " Sm³/day at " + bhp + " bara BHP");
System.out.println("Drawdown: " + drawdown + " bar");

IPR Models Available

Model Enum Value Parameters
Production Index PRODUCTION_INDEX setProductionIndex(pi, unit)
Vogel (1968) VOGEL setVogelParameters(qMax, pwfTest, pRes)
Fetkovich (1973) FETKOVICH setFetkovichParameters(C, n, pRes)
Backpressure BACKPRESSURE setBackpressureParameters(A, B)

Operating Point Methods

Method Description
getOperatingFlowRate(unit) Flow rate at IPR-VLP intersection
getBottomHolePressure(unit) Bottom-hole pressure at operating point
getWellheadPressure(unit) Wellhead pressure (target constraint)
getDrawdown(unit) Reservoir pressure - BHP
getOutletStream() Output stream for downstream connection

Lift Curve Generation

Generate IPR and VLP curves for nodal analysis.

Generating VLP Curve (Tubing Performance)

TubingPerformance tubing = new TubingPerformance("tubing");
tubing.setInletStream(gasStream);
tubing.setDiameter(0.1);
tubing.setLength(3000.0);
tubing.setCorrelationType(TubingPerformance.CorrelationType.BEGGS_BRILL);

// Generate VLP curve
double[] flowRates = {0.1, 0.5, 1.0, 2.0, 3.0, 4.0, 5.0};  // MSm³/day
double[][] vlpCurve = tubing.generateVLPCurve(flowRates);

// vlpCurve[0] = flow rates
// vlpCurve[1] = required bottom-hole pressures
for (int i = 0; i < vlpCurve[0].length; i++) {
    System.out.printf("Flow: %.2f MSm³/day, BHP: %.1f bara%n",
        vlpCurve[0][i], vlpCurve[1][i]);
}

Generating IPR Curve

WellSystem well = new WellSystem("producer");
well.setReservoirPressure(280.0, "bara");
well.setProductivityIndex(2.5e-6);
well.setIprModel(WellSystem.IPRModel.PRODUCTION_INDEX);

// Generate IPR curve (flowing BHP vs flow rate)
double minPwf = 50.0;
double maxPwf = 270.0;
int points = 20;
double[][] iprCurve = well.generateIPRCurve(minPwf, maxPwf, points);

// iprCurve[0] = flowing BHP values
// iprCurve[1] = corresponding flow rates

Combined Nodal Analysis Plot Data

WellSystem well = new WellSystem("nodal_analysis");
// ... configure well ...

// Get both curves
double[][] iprCurve = well.generateIPRCurve(50, 270, 20);
double[][] vlpCurve = well.generateVLPCurve(new double[]{0.5, 1.0, 2.0, 3.0, 4.0, 5.0});

// Operating point
well.run();
double opFlow = well.getOperatingFlowRate("MSm3/day");
double opBHP = well.getOperatingBHP("bara");

// Export to CSV or plot
System.out.println("IPR Curve:");
for (int i = 0; i < iprCurve[0].length; i++) {
    System.out.printf("%.1f, %.3f%n", iprCurve[0][i], iprCurve[1][i]);
}
System.out.println("\nVLP Curve:");
for (int i = 0; i < vlpCurve[0].length; i++) {
    System.out.printf("%.3f, %.1f%n", vlpCurve[0][i], vlpCurve[1][i]);
}
System.out.printf("\nOperating Point: %.3f MSm³/day at %.1f bara%n", opFlow, opBHP);

Multi-Layer Commingled Wells

Model wells producing from multiple reservoir layers.

Using WellFlow for Multi-Layer

// Create fluid streams for each layer
SystemInterface layer1Fluid = new SystemSrkEos(80, 200);
layer1Fluid.addComponent("methane", 0.90);
layer1Fluid.addComponent("ethane", 0.07);
layer1Fluid.addComponent("propane", 0.03);
layer1Fluid.setMixingRule("classic");
Stream layer1Stream = new Stream("layer1", layer1Fluid);
layer1Stream.run();

SystemInterface layer2Fluid = new SystemSrkEos(95, 220);
layer2Fluid.addComponent("methane", 0.85);
layer2Fluid.addComponent("ethane", 0.10);
layer2Fluid.addComponent("propane", 0.05);
layer2Fluid.setMixingRule("classic");
Stream layer2Stream = new Stream("layer2", layer2Fluid);
layer2Stream.run();

// Create multi-layer well
WellFlow well = new WellFlow("commingled_well");
well.addLayer("Upper Sand", layer1Stream, 200.0, 1.0e-6);  // 200 bara, PI
well.addLayer("Lower Sand", layer2Stream, 220.0, 1.5e-6);  // 220 bara, PI
well.setOutletPressure(150.0, "bara");  // Common BHP
well.run();

// Get individual layer contributions
double[] layerRates = well.getLayerFlowRates("MSm3/day");
System.out.println("Layer 1 flow: " + layerRates[0] + " MSm³/day");
System.out.println("Layer 2 flow: " + layerRates[1] + " MSm³/day");
System.out.println("Total flow: " + well.getOutletStream().getFlowRate("MSm3/day"));

Using WellSystem for Multi-Layer

WellSystem well = new WellSystem("multi_zone_producer");
well.setWellheadPressure(50.0, "bara");
well.setTubingDiameter(0.1);
well.setTubingLength(3500.0);

// Add layers with different properties
well.addLayer("Zone A", streamA, 250.0, 1.2e-6);
well.addLayer("Zone B", streamB, 280.0, 0.8e-6);
well.addLayer("Zone C", streamC, 265.0, 1.5e-6);

// Find operating point for commingled production
well.run();

double totalFlow = well.getOperatingFlowRate("MSm3/day");
double bhp = well.getOperatingBHP("bara");
double[] zoneFlows = well.getLayerFlowRates("MSm3/day");

Temperature Models

Configure wellbore temperature profile for accurate property calculations.

Available Temperature Models

Model Description Use Case
ISOTHERMAL Constant temperature Quick estimates
LINEAR_GRADIENT Linear geothermal Simple wells
RAMEY Ramey (1962) steady-state Established production
HASAN_KABIR Energy balance Transient, accurate

Setting Temperature Model

// Isothermal (default)
tubing.setTemperatureModel(TubingPerformance.TemperatureModel.ISOTHERMAL);

// Linear gradient (specify surface and BH temperatures)
tubing.setTemperatureModel(TubingPerformance.TemperatureModel.LINEAR_GRADIENT);
tubing.setSurfaceTemperature(25.0);   // °C
tubing.setBottomholeTemperature(90.0);

// Ramey model (needs formation properties)
tubing.setTemperatureModel(TubingPerformance.TemperatureModel.RAMEY);
tubing.setFormationThermalConductivity(2.5);  // W/m·K
tubing.setOverallHeatTransferCoefficient(25.0);

// Hasan-Kabir energy balance
tubing.setTemperatureModel(TubingPerformance.TemperatureModel.HASAN_KABIR);

Ramey Temperature Model

The Ramey (1962) model accounts for:

tubing.setTemperatureModel(TubingPerformance.TemperatureModel.RAMEY);
tubing.setGeothermalGradient(0.03);    // °C/m
tubing.setSurfaceTemperature(15.0);     // °C
tubing.setFormationThermalConductivity(2.5);
tubing.setOverallHeatTransferCoefficient(20.0);
tubing.setProductionTime(365.0);        // days

Integration with Process Simulation

Complete Well + Process System

import neqsim.process.processmodel.ProcessSystem;
import neqsim.process.equipment.stream.Stream;
import neqsim.process.equipment.reservoir.*;
import neqsim.process.equipment.pipeline.TubingPerformance;
import neqsim.process.equipment.separator.Separator;
import neqsim.process.equipment.compressor.Compressor;

// 1. Reservoir and Well
SimpleReservoir reservoir = new SimpleReservoir("reservoir");
reservoir.setReservoirFluid(reservoirFluid);
reservoir.setReservoirPressure(280.0, "bara");
reservoir.setTemperature(85.0, "C");

WellFlow inflow = new WellFlow("IPR");
inflow.setInletStream(reservoir.getOutletStream());
inflow.setWellProductionIndex(2.0e-6);

// 2. Tubing
TubingPerformance tubing = new TubingPerformance("tubing");
tubing.setInletStream(inflow.getOutletStream());
tubing.setDiameter(0.1);
tubing.setLength(3000.0);
tubing.setCorrelationType(TubingPerformance.CorrelationType.BEGGS_BRILL);

// 3. Surface Facilities
Separator separator = new Separator("HP_sep");
separator.setInletStream(tubing.getOutletStream());

Compressor compressor = new Compressor("export_comp");
compressor.setInletStream(separator.getGasOutStream());
compressor.setOutletPressure(150.0, "bara");

// 4. Build Process System
ProcessSystem plant = new ProcessSystem();
plant.add(reservoir);
plant.add(inflow);
plant.add(tubing);
plant.add(separator);
plant.add(compressor);

// 5. Run
plant.run();

// 6. Results
System.out.println("Wellhead pressure: " + tubing.getOutletStream().getPressure("bara"));
System.out.println("Gas export rate: " + compressor.getOutletStream().getFlowRate("MSm3/day"));

Coupling with WellFlowlineNetwork

// Multiple wells feeding a gathering network
WellFlowlineNetwork network = new WellFlowlineNetwork("field_network");

// Add wells
network.addWell(well1);
network.addWell(well2);
network.addWell(well3);

// Set manifold back-pressure
network.setManifoldPressure(40.0, "bara");

// Solve network
network.run();

// Get individual well rates
for (WellFlow well : network.getWells()) {
    System.out.println(well.getName() + ": " + 
        well.getOutletStream().getFlowRate("MSm3/day") + " MSm³/day");
}

Complete Examples

Example 1: Gas Well Analysis

// Rich gas well with Vogel IPR and Beggs-Brill VLP
SystemInterface gas = new SystemSrkEos(85, 250);
gas.addComponent("nitrogen", 0.02);
gas.addComponent("CO2", 0.03);
gas.addComponent("methane", 0.80);
gas.addComponent("ethane", 0.08);
gas.addComponent("propane", 0.04);
gas.addComponent("n-butane", 0.02);
gas.addComponent("n-pentane", 0.01);
gas.setMixingRule("classic");
gas.init(0);

Stream reservoir = new Stream("reservoir", gas);
reservoir.setFlowRate(3.0, "MSm3/day");
reservoir.run();

// Well system
WellSystem well = new WellSystem("gas_producer");
well.setInletStream(reservoir);
well.setReservoirPressure(250.0, "bara");
well.setProductivityIndex(3.0e-6);
well.setWellheadPressure(50.0, "bara");
well.setTubingDiameter(0.088);  // 3.5" tubing
well.setTubingLength(2800.0);
well.setVlpCorrelation(WellSystem.VLPCorrelation.GRAY);
well.run();

System.out.println("=== Gas Well Operating Point ===");
System.out.println("Flow rate: " + well.getOperatingFlowRate("MSm3/day") + " MSm³/day");
System.out.println("BHP: " + well.getOperatingBHP("bara") + " bara");
System.out.println("Drawdown: " + well.getDrawdown() + " bar");

Example 2: Oil Well with Artificial Lift Comparison

// Compare production with different wellhead pressures (simulating lift)
WellSystem well = new WellSystem("oil_producer");
well.setReservoirPressure(180.0, "bara");
well.setProductivityIndex(5.0e-6);
well.setTubingDiameter(0.076);  // 3" tubing
well.setTubingLength(2000.0);
well.setVlpCorrelation(WellSystem.VLPCorrelation.HAGEDORN_BROWN);

System.out.println("Wellhead Pressure | Flow Rate | BHP");
for (double whp = 10; whp <= 50; whp += 10) {
    well.setWellheadPressure(whp, "bara");
    well.run();
    System.out.printf("%17.0f | %9.2f | %6.1f%n",
        whp, well.getOperatingFlowRate("Sm3/day"), well.getOperatingBHP("bara"));
}

Example 3: Multi-Zone Completion

// Three-zone commingled gas well
WellSystem well = new WellSystem("multizone_gas");
well.setWellheadPressure(45.0, "bara");
well.setTubingDiameter(0.1);
well.setTubingLength(3200.0);

// Zone A: Shallow gas, high perm
well.addLayer("Zone_A", shallowStream, 180.0, 4.0e-6);
// Zone B: Middle, moderate perm
well.addLayer("Zone_B", middleStream, 220.0, 2.0e-6);
// Zone C: Deep, low perm but high pressure
well.addLayer("Zone_C", deepStream, 280.0, 0.8e-6);

well.run();

System.out.println("=== Multi-Zone Production ===");
System.out.println("Total rate: " + well.getOperatingFlowRate("MSm3/day") + " MSm³/day");
double[] zoneFlows = well.getLayerFlowRates("MSm3/day");
System.out.println("Zone A: " + zoneFlows[0] + " MSm³/day");
System.out.println("Zone B: " + zoneFlows[1] + " MSm³/day");
System.out.println("Zone C: " + zoneFlows[2] + " MSm³/day");

API Reference Summary

WellFlow (IPR)

Method Description
setWellProductionIndex(pi) Set productivity index
setVogelIPR(qTest, pwfTest, pRes) Configure Vogel IPR
setFetkovichIPR(c, n) Configure Fetkovich IPR
setBackpressureIPR(a, b) Configure Backpressure IPR
setTableIPR(pwf[], rate[]) Set table-driven IPR
addLayer(name, stream, pRes, pi) Add reservoir layer
getLayerFlowRates(unit) Get layer flow contributions

TubingPerformance (VLP)

Method Description
setDiameter(d) Set tubing ID (meters)
setLength(L) Set tubing length (meters)
setInclination(angle) Set inclination (degrees from horizontal)
setRoughness(eps) Set pipe roughness (meters)
setCorrelationType(type) Select VLP correlation
setTemperatureModel(model) Select temperature model
generateVLPCurve(rates) Generate lift curve
getPressureDrop() Get calculated pressure drop

WellSystem (Integrated)

Method Description
setReservoirPressure(p, unit) Set reservoir pressure
setProductivityIndex(pi) Set well PI
setWellheadPressure(p, unit) Set tubing outlet pressure
setIprModel(model) Select IPR model
setVlpCorrelation(corr) Select VLP correlation
getOperatingFlowRate(unit) Get operating flow rate
getOperatingBHP(unit) Get operating BHP
generateIPRCurve(min, max, n) Generate IPR curve
generateVLPCurve(rates) Generate VLP curve

Complete Production System Example

For a comprehensive example demonstrating the full integration of well simulation with downstream processing, see WellToOilStabilizationExample.java.

This example includes:

Using WellSystem in ProcessSystem

The WellSystem class integrates seamlessly with ProcessSystem for building complete production flowsheets. It uses an optimized IPR+VLP solver with:

// Create reservoir and reservoir stream
SimpleReservoir reservoir = new SimpleReservoir("Main Reservoir");
reservoir.setReservoirFluid(reservoirFluid, 1e6, 10.0, 10.0);

Stream reservoirStream = new Stream("Reservoir Stream", reservoir.getReservoirFluid());
reservoirStream.setFlowRate(5000.0, "Sm3/day");
reservoirStream.setTemperature(100.0, "C");
reservoirStream.setPressure(250.0, "bara");

// Create WellSystem with integrated IPR and VLP
WellSystem well = new WellSystem("Producer-1", reservoirStream);

// Configure IPR model (Vogel for solution gas drive)
well.setIPRModel(WellSystem.IPRModel.VOGEL);
well.setVogelParameters(8000.0, 180.0, 250.0); // qMax, testPwf, Pr

// Configure VLP (tubing)
well.setTubingLength(2500.0, "m");
well.setTubingDiameter(4.0, "in");
well.setWellheadPressure(80.0, "bara");
well.setBottomHoleTemperature(100.0, "C");
well.setWellheadTemperature(65.0, "C");

// Connect downstream equipment
PipeBeggsAndBrills flowline = new PipeBeggsAndBrills("Flowline");
flowline.setInletStream(well.getOutletStream());
flowline.setLength(5000.0);
flowline.setDiameter(0.2);

// Build complete ProcessSystem
ProcessSystem process = new ProcessSystem();
process.add(well);          // WellSystem as first equipment
process.add(flowline);
process.add(inletChoke);
process.add(hpSeparator);
// ... add remaining equipment

// Run complete simulation
process.run();

// Access well operating point results
double opRate = well.getOperatingFlowRate("Sm3/day");
double bhp = well.getBottomHolePressure("bara");
double drawdown = well.getDrawdown("bar");

Performance Considerations

The WellSystem solver is optimized for speed:

Feature Description
Simplified VLP Uses hydrostatic + friction correlation instead of full TubingPerformance iteration
Bisection solver Robust convergence in ~15-20 iterations
Single flash per iteration Minimizes thermodynamic calculations
Typical solve time < 1 second for complex fluids

For detailed VLP calculations with full correlation support, use TubingPerformance directly.

VLP Solver Modes

WellSystem supports multiple VLP solver modes for different accuracy/speed tradeoffs:

import neqsim.process.equipment.reservoir.WellSystem.VLPSolverMode;

// Default: Fast simplified solver (hydrostatic + friction)
well.setVLPSolverMode(VLPSolverMode.SIMPLIFIED);

// Traditional correlations (via TubingPerformance)
well.setVLPSolverMode(VLPSolverMode.BEGGS_BRILL);
well.setVLPSolverMode(VLPSolverMode.HAGEDORN_BROWN);
well.setVLPSolverMode(VLPSolverMode.GRAY);
well.setVLPSolverMode(VLPSolverMode.HASAN_KABIR);
well.setVLPSolverMode(VLPSolverMode.DUNS_ROS);

// Advanced multiphase models
well.setVLPSolverMode(VLPSolverMode.DRIFT_FLUX);  // Drift-flux with slip
well.setVLPSolverMode(VLPSolverMode.TWO_FLUID);   // Separate momentum equations
VLP Solver Mode Description Speed Accuracy
SIMPLIFIED Hydrostatic + friction correlation Fastest Approximate
BEGGS_BRILL Beggs & Brill empirical correlation Medium Good for general use
HAGEDORN_BROWN Hagedorn-Brown for vertical wells Medium Good for oil wells
GRAY Gray correlation for gas wells Medium Good for gas wells
HASAN_KABIR Mechanistic model Slow High accuracy
DUNS_ROS Duns & Ros correlation Medium Good for gas-liquid
DRIFT_FLUX Accounts for phase slip velocity Medium Better for high GOR
TWO_FLUID Separate gas/liquid momentum Slowest Highest accuracy

See Also

References

  1. Vogel, J.V. (1968). “Inflow Performance Relationships for Solution-Gas Drive Wells”
  2. Fetkovich, M.J. (1973). “The Isochronal Testing of Oil Wells”
  3. Beggs, H.D. and Brill, J.P. (1973). “A Study of Two-Phase Flow in Inclined Pipes”
  4. Hagedorn, A.R. and Brown, K.E. (1965). “Experimental Study of Pressure Gradients…”
  5. Gray, H.E. (1974). “Vertical Flow Correlation in Gas Wells”
  6. Hasan, A.R. and Kabir, C.S. (2002). “Fluid Flow and Heat Transfer in Wellbores”
  7. Ramey, H.J. (1962). “Wellbore Heat Transmission”