pipesim day1 single branch
DESCRIPTION
pipesim Day1 Single BranchTRANSCRIPT
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Presentation:1.PIPESIM Basics:
1. PIPESIM File Naming and structure2.Single Branch Model Basics (Iteration
Options).3.Building a Model.4.Description of PIPESIM Model
Components.5.Single Branch Operations.
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PIPESIM Single Branch Model:
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1. PIPESIM File naming.
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File naming GUI input files
xxx.bps PIPESIM input file (single branch) xxx.bpn PIPESIM input file (network) xxx.pgw input file xxx.pvt Fluid Property PIPESIM-GOAL input
file xxx.fpt FPT input file
Output file xxx.out Output file xxx.sum Summary file xxx.plt Job plot (1 data point for each case) xxx.plc Case plot (1 data point for each
node)
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2. PIPESIM Single Branch Model Basics:
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Iteration Options: PIPESIM is a steady state multiphase flow
simulator.
PIPESIM performs simultaneous pressure and temperature calculations. It has three fundamental iteration options (with inlet temperature always defined):• Non-Iterative
Pin and Qin known, calculate Pout
• Iterate on PressureQin and Pout known, calculate Pin
• Iterate on FlowratePin and Pout known, calculate Qin
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Solution algorithm Solution computed in flow direction Each pipeline is divided into a number of
segments determined automatically Pressure and energy balances in each
segment Fluid physical properties are calculated at
averaged conditions across each segment
Flow regime determined from gas and liquid superficial velocities
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3.Building a Model:
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Building a model
Define objects in the model, i.e. well completion, tubing, etc using the toolbox
Enter physical data, i.e. tubing ID, etc. Enter fluid data: black oil/compositional Set boundary conditions Select an operation
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Single branch toolbox
POINTER
CONNECTOR
MULTIPLIER/ ADDER
NODEHORIZONTAL COMPLETION
TUBING
VERTICAL COMPLETION
REPORT TOOL
NA POINT
COMPRESSOR
EXPANDER
PUMP
SEPARATOR
HEATER/ COOLER
CHOKE
RISER
FLOWLINESOURCE
KEYWORD INSERTER
INJECTED GAS
ANNOTATION
BOUNDARY NODE
MULTIPHASE BOOSTER
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4.Description of PIPESIM model components:
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Well completion models
Well PI (Oil & Gas) Vogel Equation (Oil) Jones (Oil & Gas) Fetkovich Equation (Oil) Back Pressure Equation (Gas) Pseudo Steady State (Oil & Gas) Forcheimer’s Equation (Gas & Condensate) Hydraulic Fracture (Oil & Gas) Transient (Oil & Gas)
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Inflow performance relationships Oil Reservoirs:
Well Productivity Index Vogel Equation Fetkovich Equation Jones Equation Pseudo-Steady-State
Equation Hydraulic Fracture Transient
Gas and Gas Condensate Reservoirs:
Well Productivity Index Back Pressure Equation Jones Equation Pseudo-Steady-State
Equation Hydraulic Fracture Forcheimer Transient
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Well productivity index (PI)
For LiquidQ = PI x (Pws - Pwf)
For gas compressible reservoirs Q = PI x (Pws
2 - Pwf2)
where, Pws = static reservoir pressurePwf = flowing bottom-hole pressureQ = flowrate
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Vogel’s equation
Empirical relationship for fluid below bubble point pressure:
q/qmax = 1 - (1 - C)(Pwf/Pws) - C(Pwf/Pws)2
where, C = PI Coefficient, normal value is 0.8
qmax = Absolute Open Hole PotentialPws = Static Reservoir PressurePwf = Bottom Hole Flowing Pressure
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Fetkovich’s equation
Alternative to Vogel’s equation Empirical correlation
q / qmax = [ 1 - ( Pwf / Pr )2 ] n
The lower the value of n, the greater the degree of turbulence
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Jones equation
Gas and saturated oil reservoirs Equations:
Gas: (P2) = AQ + BQ2
Oil: (P) = AQ + BQ2
whereA : Laminar flow coefficient (Darcy)B : Turbulent flow coefficient (Non Darcy)
Also known as “Forcheimer equation”
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Back pressure equation
For gas wellsQ = C (Pws
2 - Pwf2)n
Schellhardt & Rawlins empirical equation Normally, 0.5 < n < 1.0
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Pseudo - steady - state equation
Oil and gas reservoirs Darcy equation Parameters used in equation :
Permeability Thickness Radius (reservoir external drainage) / Area / Shape Skin (dimensionless skin factor) Wellbore diameter
Gas well: laminar and turbulent flow Oil well: laminar flow
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Well completion options
ONLY valid when used with the pseudo-steady-state equation inflow performance model.
To calculate skin factor and turbulence coefficient (for gas wells).
Completion options: None (i.e. no skin resistance to inflow) Open Hole (well is not cemented or cased) Perforated (McLeod model) Gravel Packed (Jones model)
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Horizontal completion models Distributed PI (finite conductivity):
Distributive PI: PI per unit length Steady State PI (Joshi) Pseudo Steady State PI (Babu & Odeh)
Single Point PI (infinite conductivity): Steady State PI (Joshi) Pseudo Steady State PI (Babu & Odeh)
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Tubing data
Well Tubing Details Depth (TVD / MD) Detailed Profile Data Tubing ID’s - can be changed at any point
along the tubing Artificial Lift: Gas Lift, ESP etc. Tubing/annular/combined flow Ambient temperature profile
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Flowline details
Flowline geometry: Length, ID Undulation profile Simple or Complex Heat Transfer
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Flowline, Tubing Heat transfer Energy balance for each segment Heat enters
with flowing fluid through pipe wall
Two options: User specified overall U-value User supplied pipe coating information
Reference: A.C. Baker, M. Price. “modelling the Performance of High-Pressure High-Temperature Wells”, SPE 20903, (1990).
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Heat transfer (cont.)
U-values - Overall heat transfer coefficient relative to the pipe outside diameter (OD)
Defaults Insulated pipe 0.2 BTU/hr/ft2/F Coated 2.0 BTU/hr/ft2/F Bare (in Air) 20 BTU/hr/ft2/F Bare (in Water) 200 BTU/hr/ft2/F
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Heat transfer (cont.)
Overall heat transfer coefficient can be calculated from the user supplied data
User can supply up to 4 coatings on the pipe w/ Thickness Thermal Conductivity
Also specify Pipe thermal conductivity Burial depth Ground thermal conductivity Ambient air/water velocity
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Equipment
• Pump• Compressor• Choke• Flow Multiplier/Divider• Flow Adder/Substractor• Injection Point
Multiphase Booster Generic Multiphase
Pump Separator Expander Heater Exchanger Generic Equipment
(dP / dT)
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5.Single Branch Operations:
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Single branch operations
System Analysis Pressure/Temperature Profile Flow Correlation Matching Nodal Analysis Optimum Horizontal Well Length Reservoir Tables Gas Lift Rate v Casing Head Pressure Artificial Lift Performance
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Flow correlation matching
To determine the most suitable flow correlation
Select the required flow correlations Enter measured pressure and temperature
survey data (FGS), through “MEASURED DATA”.
Enter known boundary conditions Results show each correlation and the
entered data
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Pressure/temperature profile
Compute the pressure and temperature profile for a system and also vary some other parameters within system
Enter sensitivity variable Enter boundary conditions Resulting PSPLOT shows pressure or
temperature against depth (well) or elevation (flowline).
Can plot measured data also.
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System analysis
Set up multiple sensitivity operation. Set up System Analysis Plot :
Specify calculated variable. Select X axis variable. Select any number of sensitivity variables (Z axis
variables).
In addition, also specify sensitivity relation. One variable Several variables that change together Several variables permuted against one another
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Nodal analysis
Classical nodal analysis at any point (insert NA point in the model).
Break the system into two and compute the inflow and outflow around that point.
Resulting PSPLOT shows the classical inflow/outflow curves.
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Nodal analysis
Pres
Pse
p
Inflow/outflow curvesPr
essu
re
ID = 3"
ID = 3 1/2"ID = 4"
Reservoir Performance
Flow Rate
WHP
= 3
00
Flow
ing
Bott
omho
lePr
essu
re
Flow Rate
Reservoir Performance
WHP
= 1
00
WHP
= 2
00
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Reservoir tables Produce a table of bottom-hole pressures that
can be utilised by reservoir simulators. (VFP tables).
Interface to common reservoir simulators such as: ECLIPSE VIP PORES COMP4 MoRes
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Artificial lift performance
Allows artificial lift performance curves (gas or ESP lift) to be generated and also varies some other parameters within system.
To produce input performance curves for GOAL.
Resulting plot is gas lift quantity (or ESP power) versus oil production rate.
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Artificial lift systems
Gas lift Two Model Options :
Fixed injection depth & rate. Multiple injection points (Gas Lift Valves).
ESP (Electrical Submersible Pump)
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Gas Lift Design
• New mandrel spacing.• Design for existing mandrels (current spacing). Casing & tubing pressure sensitive valves (IPO / PPO
valves). Valve spacing, test rack pressure calculations and valve
sizing. Unloading gas and liquid rate calculations – sizing of
unloading valves. Bracketing valve calculations.• Multiple static gradient options.• Database of valve parameters (editable).
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Gas Lift Design
Additional Design Tools / Operations :
Deepest injection point calculation. Bracketing range calculations. Lift Gas Response Curves – how production rate and
injection depth respond to various sensitivities.
Analysis can be performed assuming “Optimum Depth of Injection” or “Injection at Specified Mandrel Depths only”.
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Gas Lift Dagnostics
Simulate an existing well design (for current production & injection conditions).
Calculate valve status (open, closed, throttling). Determine valve throughput (based on bellows
load rate). Troubleshoot existing gas lift installation for
multi-porting, shallow injection etc.).
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Gas lift design : Pressure – Depth Plot.
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Electrical submersible pump
Database with a list of ESP manufacturers and models (i.e. Reda, Centrilift etc) is made available.
Base data: casing diameter, minimum & maximum flowrates and base speed.
Design data: pump speed, number of stages, head factor.
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ESP performance curve
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ESP variable speed curves
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ESP Design
Selects & Designs a pump to meet design conditions of production rate and production pressure.
Select appropriate pump for casing size and production rate.
Select required number of stages. Identify requirements for separation. Identify power requirements. Analyse variable speed performance of the pump / well
system. Simple motor and cable screening requirements.
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6. Multiphase Flow Modelling in PIPESIM:
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Pressure change calculation method Determine the phase(s) present Determine the inclination angle Determine the flow pattern Calculate the elevational, frictional and
accelerational pressure losses or gains
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Phases present
If the liquid volume fraction < 0.00001 then single phase gas exists
If the liquid volume fraction > 0.99 then single phase liquid exists
otherwise multiphase flow exists
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Single phase flow correlations
Available Moody (default) AGA - Dry Gas Equation Panhandle A Panhandle B Hazen-Williams Weymouth
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Inclination angle
If the inclination angle > 45° or < -45° then vertical flow patterns and pressure change correlations apply
otherwise horizontal flow patterns and pressure change correlations apply
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Multiphase flow correlations
Published industry standard correlations: Duns & Ros Orkiszewski Hagedorn & Brown Beggs & Brill (original & revised) Mukherjee & Brill Govier, Aziz & Fogarasi AGA & Flanigan Oliemans Gray Noslip