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/PM Training course Integrated production modelling
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An Introduction to PROSPER, MBAL and GAP
Oifmsolutions ..._,.. INTEGRATED FIELD MODELING
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bifmsolutions ~ !NTEGR/~oTED
FIELD MODELING
IPM Training Manual
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Copyright notice
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The copyright in this manual is the property of ifm-so/utions. All rights reserved. No part of this manual may be reproduced, transmitted, transcript, translate, store in a retrieval system by any means, electronically, mechanically, magnetic, optic or any otherwise or disclose to third party without the prior consent of ifm-so/utions.
© ifm-so/utions. All rights reserved. /PM suite, GAP, PROSPER, MBAL, PVTP, REVEAL, RESOLVE, IFM and Open Server are trademarks of Petroleum Experts Ltd. The software described in this manual is furnished under a license agreement. The software may be used or copied only in accordance with the terms of the agreement. It is against the law to copy the software on any medium except as specifically allowed in the license agreement.
lfm-so/utions Contact details: Email:
[email protected] Tel. +54-11-48718937 www.ifm-solutions.com Junin 1057 4D Buenos Aires Argentina
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Petroleum Experts Ltd contact details: Email:
[email protected] Te. +44-131-4747030 www.petex.com Petex House 10 Logie Mill Edinburgh EH7 4HG Scotland, UK
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(~.-------------------------------------------------------------Table of Contents
Table of Contents ...............................................................................................................................•.......................................3
/PM training course introduction ...............................................................................................................................................4 The concept of IPM .................................................................................................................................................................... 5 The /PM modelling platform ...................................................................................................................................................... 6 Introduction and scope of work .................................................................................................................................................7 MBAL ........................................................................................: ................................................................................................8 Tutorial M-01: Performing the history matching in MBAL for a gas reservoir ........................................................................... 9 (~
Tutorial M-02: Perform the history matching in MBAL for an oil reservoir ............................................................................. 10 Tutorial M-03: History matching in MBAL for a gas and condensate reservoir ....................................................................... 12 Tutorial M-04: MBAL oil field history matching and predictions ............................................................................................. 13 ,~
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Tutorial M-05: Performing predictions in MBAL for a gas reservoir ........................................................................................ 15 PROSPER ..................................................................................................................................................................................16 Tutorial P-01: PROSPER introduction:._ constructing an ail well mode! ................................................................................... 17 Tutorial P-02: Basic example gas well model construction ...................................................................................................... 20 Tutorial P-03: PVT Black oil matching far an oil well mode/ ..................................................................................................... 23
Tutorial P-04: Selecting and matching a mu!tiphase flow correlation for an oil well model ................................................... 24 Tutorial P-05: Oil well model calibration review exercise ........................................................................................................ 27 Tutorial P-06: Gas well model performance analysis ............................................................................................................... 31 Tutorial P-07: Gas well modelling performance Hydraulic fracturing ...................................................................................... 32 Tutoria! P-08: Gas and condensate wet! model .......................................................................................................................34 Tutorial P-09: Electrical submersible pump design .................................................................................................................. 36 Tutorial P-10: Gas lift design .................................................................................................................................................... 38
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GAP ..........................................................................................................................................................................................41
Tutorial G-01: Gas and condensate field integrated production model set up .......................................................................42 Tutorial G-02: Integrated Production model- Solve Network ................................................................................................ 44 Tutorial G-03: Integrated Production Model- Production forecast ........................................................................................ 46 Tutorial G-04: Integrated model for an Oil field ...................................................................................................................... 47 Workshop ................................................................................................................................................................................48 Tutorial W-01: Gas field Integrated model ..............................................................................................................................48 Tutorial W-02: Gas field integrated model- Part 2 ................................................................................ ,................................ 54 Tutorial W-03: Offshore Oil field development plan ....................................................................., ........................................ 55 Tutorial W-04: Tight gas well modelling .................................................................., .............................................................. 57
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IPM Training Manual
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,-.------------------------------------------------------------r IPM training course introduction ( (
Objectives
• •
Learn how to use the software and develop skills in the use of IPM Basic understanding of the physics
•
Understanding the limitations of methods and techniques used
Agenda r
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Dayl Introduction to MBAL Materia! balance concept review History matching
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Graphical method (Havlena Odeh, Campbell, Cole) Analytical method
o Aquifer models MBAL Simulation Fractional flow matching (Fw, Fg) MBAL predictions in standalone basis. MBAL exercises for OJ!, Gas and condensate fluid.
Day 2 Introduction to PROPSER
Nodal analysis concept review The importance of the PVT Pressure loss in the wei! bore Selecting and matching a multiphase flow correlation
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Analyzing the well performance
Day3 Introduction to GAP Building a surface network model
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Integrating PROSPER and MBAL files Performing production forecasting within GAP
Day4
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Integrated model Workshop Field development planning using !PM This is a review of all concepts learnt (MBAL·PROSPER-GAP)
DayS PVT equation of state characterization
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Tight gas well modelling (PROSPER, MBAL, GAP) ESP design
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Gas lift design
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IPM Training Manual
·-----------------------------------------------------------------------The concept of IPM
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A production system can be visualised in a simple form as shown in the next sketch:
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To obtain how much oil/gas we can recover will depend on the interaction of the reservoir, wells and facilities. Any strategy designed to maximize the oil/gas recovery of the field requires simultaneous modelling of the reservoir, wells, and facilities up to the delivery point. Decision making process should be based on an integrated model to avoid isolated decision that will meet constraints in other parts of the system.
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'bifmsolutions r·· ~INTEGRATED FIELD MODELING
IPM Training Manual
'-------------------------------------------------------------------------The IPM modelling platform {
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The Petroleum Experts toolkit is designed to build and study a complete integrated model. It has the following tools that are used for different modelling aspects.
GAP, Surface network modelling and optimization tool. PROSPER, Single wellbore-modelling tool
MBAL, Material balance reservoir modelling tool PVTP, Fluid characterisation tool
The following sketch is drawn to explain how these tools interact with each other.
GAP r
PROSPER
•
•
MBAL
PVTP is used to characterise the fluid pressure- volume temperature behaviour and is used to
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construct models that will be used by other tools GAP is the total system-modelling tool. It models the surface network internally. For, modelling the reservoirs it uses MBAL tool. For well modelling GAP uses PROSPER.
C'._.__________________________________________________._..__._._.. ..__.___________.
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IPM Training Manual
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Introduction and scope of work
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In the overall scheme that we will follow during this course we will build an integrated model of a very simple condensate field.
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Then we will model each component of the system, the wells, the reservoirs and the gathering network in a sequential manner. At each stage we will be adding more information that may be available to us and see the value of the added information. We will start using MBAL to construct the material balance reservoir model. The next stage is the construction of the well model in PROSPER. At the end, we should be capable to use the field scale integrated model, to study the response of our total system. In order to keep track of what we will be doing it is better to use the following directory structure.
{:J CD1ive \·{J !····Wl !····Wl
Day1 Day2 Day3 L..Q Day4
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MBAL I I
MBAL is the material balance modelling tool. This tool can help the reservoir engineer to understand the reservoir behaviour and its drive mechanisms and perform predictions.
Methodology Through exercises the engineer will familiarize with the use of the material balance tool within MBAL. The engineer will have to solve reservoir engineering problems applying the material balance concept. The exercises and tutorials have been design to learn how to:
1. Construct models PVT input data, selecting and matching a black oil correlation Enter tank parameters and production history 2.
Performing history matching Calibrating the model with graphical methods (Campbell, Cole, P/2, Havlena and Ode h) Analytical method
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Fractional flow curve matching, Fw, Fg Obtaining the OOIP, GIIP Estimating the parameters of the aquifer to obtain the best match
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Estimating the drive mechanism
r 3. Running a simulation
4. Production forecast using MBAL in standalone. ,r--
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IPM Training Manual
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Tutorial M-01: Performing the history matching in MBAL for a gas reservoir
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Objectives: Familiarize the user with MBAL and practice the procedure to perform a history matching of a gas reservoir material balance model.
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Reservoir data
PVT
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.
·
'·Parameters ... ... ... Specific gas gravity Separator pressure CGR (Condensate to gas ratio) Oil density Water salinity H2S% C02% N2% ·
·· .. I·· ..
Value
>
0.85 990 2 42 10000
units
··· .
Psig Stb/MMscf API Ppm % % %
0 0 0
The reservoir is at a depth of 9700 feet, the initial reservoir pressure is 4365 psig. The average reservoir thickness estimated with logs is 28 feet with an average porosity of 19%. The connate water saturation is estimated in 20%. The reservoir temperature is 200 ·F. The average reservoir permeability estimated with pressure transient analysis is 20 md. The equivalent reservoir radius is estimated in 30000 feet.
Pseudo relative permeability curves data
..
··Phase.
>
Water
I
EndPoint
<
0.02
Gas
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Residual Saturation.· · I· 0.20
Corey•Exponent .· · •·• .·
0.6
1
0.9
1
The field is producing since 1991 and the production history is attached in the Excel file called
AuxJiles\dayl \M-Ol.xls Questions Perform the history matching to calibrate the model and obtain:
<···
Variables ·· c •. Gas initial in place Determine the presence of an aquifer Actual recovery factor
(
. ·.
.
..
•.
·.Value
•·
••• I ,.·.·. .• ·.·. Units
.
Bscf yes/no %
Save this tutorial as M-01.mbi
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IPM Training Manual
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Tutorial M-02: Perform the history matching in MBAL for an oil reservoir
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Objectives: Familiarize the user with MBAL and the steps to perform the history matching of an oil material balance reservoir model.
r Reservoir data r----
PVT data
r · ·• .· · ·parameters GOR Oil density Specific gas gravity Water salinity H2S% C02% N2%
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'• r r·
r r
.· ·.·
... ·.
· ·. ·Value 250 32 0.65 10000 0 0 0
.
units
Scf/stb API Ppm % % %
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Reservoir temperature: 197 "F. The bubble point pressure has been measured in constant composition expansion experiment; the
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value is 1670 psig @ 197"F.
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The initial reservoir pressure at the datum depth is 4217 psig.
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Datum depth: 9370 feet.
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The following table shows the oil formation volume factor at different pressures.
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Pressure •psig 4217 3725 3390 1670
· Bo . :··rb/stb
1.118 1.1221 1.1249 1.139
The average porosity is estimated in 18%, the connate water saturation is 24.8%. The reservoir thickness is approximately 150 feet with an average permeability of 50 md. An equivalent reservoir radius has been estimated in 6000 feet.
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Pseudo relative permeability curves data Phase
..
·Residual Saturation
.·
End Point
Corey Exponent
Water
0.248
0.6
1
Oil
0.15
0.8
1
Gas
0.02
0.9
1
The production history is given in attached Excel spread sheet called AuxJiles\day1 \M-02.xls
Questions Perform the history matching of the model and answer the following points:
Variables ·.... ·.·· Oil initial in place Gas initial in place Actual recovery factor Active aquifer exist Is there an initial gas cap?
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.
·.·
Value·
,;
.···
Units:·: ·........ ·
MMstb Bscf % Yes/No Yes/No
Save this tutorial as M-02.mbi
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Oifmsolutions ~ INTEGRATED FIELD MODELING
!PM Training Manual
Tutorial M-03: History matching in MBAL for a gas and condensate reservoir Objectives: Perform the history matching for a gas and condensate MBAL model with production history by well.
Reservoir data PVTdata ..
.
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Parameters ·
.
Separator pressure Separator Temperature Separator GOR Separator gas gravity TankGOR Tank gas gravity Condensate gravity Water salinity Dewpoint at reservoir temp Reservoir Temperature Reservoir pressure H2S
co, N,
Value
··.· ..·· . I
··.
500 80 6943 0.81 120 0.96 50.5 100000 4870 274 6495 0 0 0
·Units
psig
OF scf/stb scf/stb API ppm psig
OF psig % % %
The average porosity has been estimated in 17% with an average connate water saturation of 25%. The field is on production since June 1998 and the production history can be found on the Excel spread sheet Aux_files\day1 \M-03.xls. Pseudo relative permeability curves data
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:-
Phase-----
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Residual Saturation--;: .
End Point.
Corey Exponent ··· ...
Water
0.25
0.6
2
Oil
0.10
0.3
1.3
Gas
0.02
0.9
2
Questions Perform the history matching to calibrate the model and obtain:
.---:
•·
. _Variables ·.. · Gas initial in place Determine the presence of an aquifer Actual recovery factor Main drive mechanism ··.
...
.
·.·· · .·.
·. ·value.
• - .•
. I>< . - ul1its . •• Bscf yes/no %
Save this tutorial as M-03.mbi
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IPM Training Manual
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Tutorial M-04: MBAL oil field history matching and predictions
Objectives: Perform the history matching for an oil reservoir in MBAL Using the calibrated model perform a production forecast. Estimate the evolution of the oil production rate, water production rate and gas production rate.
Reservoir data
PVT · Parameters ..·. · ··
I GOR
Oil density Specific gas gravity Water salinity H2S% C02% N2%
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... <,Value · : Units 800 Scf/stb 35 API 0.78 Ppm 80000 0 % 0 % 0 %
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The measured reservoir temperature is 250 ·F with an initial reservoir pressure of 5215 psig.
PVT Laboratory measurements · Pressure .. Bubble .point 1.· ·.· GOR 'F'· ...· l_ psig · 'psig I ·• .< Scf/si:b _ 250 3600 3600 800
Temjlerlltu~e
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· Bo · ·... Oil viscosity .. ·. rb/stb . ·, · · :· .···· .. ·. cp •__ < 1.456 0.31
The average porosity is estimated in 23%, the connate water saturation is 19%. The average reservoir thickness is approximately 102 feet with an average permeability of 20 md. An equivalent reservoir radius is estimated in 2200 feet.
Pseudo relative permeability curves data
I :: • · .. Water Oil
Gas
Ph~se
I . ·.Residual Saturation .· ·
•.. ·: ..
········
:
End Point :. : .•
. Corey ExponenL
0.19
0.6
1
0.15
0.8
1
0.02
0.9
1
'
The production history has been stored in the Excel spread sheet called AuxJiles\day1\M-04.xls for your convenience.
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Questions Perform the history matching ofthe model and answer the following points:
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Variables :>'. ';_ '___·
_--
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Value
Oil initial in place Gas initial in place Actual oil recovery factor Active aquifer exist Is there an initial gas cap? Main drive mechanism
•_···-;'-_.·--.-· I· ..·
Units ._··, ·.
---·
MMstb Bscf % Yes/No Yes/No
Section 2: Production forecast r
The field is currently producing with only one well, called Well-1. The productivity index of Weil-l is 16.5 stb/day/psi and the VLP for this well is located in the auxiliary files folder (AuxJiles\dayl\we/1-
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l.tpd).
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The well is producing to a separator with a pressure of 360 psig with a maximum capacity of 3500 stb/day of liquid. ("
Perform a production forecast until the end of the concession 01/01/2025 and show the evolution of the oil production rate, water cut and GOR.
Estimate the oil recovery factor in 2025 and the oil proved developed reserves.
What would you da to improve the recovery factor? Quantify your suggestions using MBAL.
Save this tutorial as M-04.mbi
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IPM Training Manual
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Tutorial M-05: Performing predictions in MBAL for a gas reservoir Objectives: Perform a production forecasting for a gas reservoir using well models. Using as a basis the MBAL file created in tutorial M-01 and the field and well model information provided below a perform a production forecast until the end of the concession 01/01/2027. The field is currently producing with 4 wells (M5-1, M5-2, M5-3 and M5-4) to a separator operating at 1200 psig. All the wells have the same tubing configuration (3 Y," Tubing) and the VLP are attached in the auxiliary files folder. (Aux_Files\day1\M05-Gas_well.tpd) The IPR of the wells are described with the C and N model and a summary is shown in the next table:
.
.
..··· .
· Well:
·
'c·:
.·
M5-1 M5-2 M5-3 M5-4
.
.
C Mscf/day/psi' 0.008345 0.011195 0.0082 0.007865
N
.
0.94123 0.92674 0.94 0.93771
Questions Perform a production forecast until 01/01/2027 and answer the following points:
.
· . Variables · Plot the gas production rate evolution Estimate the gas recovery factor in 2027 Estimate the gas proved developed reserves Estimate the P/2 abandonment value .•.
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Value
Units
% Bscf psig
The contract department is negotiating a better gas price; however it is necessary to provide at least 40 MMscf/day of gas untillQZO. The question that has been asked to your department is if it is possible to achieve this level of production and what actions or investments would be required. Explain the solution:.
y 8.?.?.~.-::.~t?.f...&.:...~ ...................................................................................................................... ..
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::~~~~~~:::~~~;.::::::::::::::;::::::::::::::::::::::::::::::::::::::::::::::::::::·.::::::::::::::::::::::::::::::::::::::::::
~r.t~·~.~~/':f!I!Me.J. 7 ..~r.~~ ..cft':..&.6w,..................................................................................
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IPM Training Manual
PROSPER
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Methodology Through exercises the engineer will familiarize with the use of PROSPER and well performance evaluation. The engineer will have to solve production engineering problems to analyze the performance of oil and gas wells. The exercises and ~utorials have been design to learn how to:
1. Construct models PVT input data, selecting and matching a black oil correlation Enter well information 2. Calibrating or matching the model Calibrating the PVT Matching and selecting a multiphase flow correlation Calibrating an IPR model 3.
Evaluating the performance of the well
4.
Performing sensitivity analysis to evaluate future conditions
5.
Performing the design of artificial lift system
6.
Generating lift curves for numerical simulators
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Tutorial P-01: PROSPER introduction- constructing an oil well model
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Objectives: Familiarize the user with PROSPER and the input of data Perform basic calculations in PROSPER Construct an oil naturally flowing well and obtain results
Expected calculations: Considering a well head pressure of 400 psig and actual conditions of reservoir we would like to know: Estimate oil production rate. Estimate flowing bottom-hole pressure.
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Estimate well head temperature.
Data PVTdata Variable· .. ·.·. Solution GOR Oil density Gas gravity Water salinity
.
· ..
..
.
Unit Scf/stb API
Value 430 34 0.73 85000
·. .
ppm
Deviation Survey Deviation Survey
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·. .· . •... ~ .
. ..
. . ..
.
...
1. Geothermal : ..
· · gradient . · • • Measur~~····· . · True vertical . . Temperature . "F .· dE!pth · ·.'. . .. depth· :.····· L I · .. · . · ...•... · .. ·... m<· . ··.· m ·. 80 0 0 443.4 452 489 475.7 564 535 665 601.2 663.1 790 1145 1896 2736 1639.9 1706.4 2885 1726.5 163 2930 .
r . _ . _. . . . . . . ._.. ._._.. . . . . . . . . . . . . . . ._.. . . . . . . ..__.._._. ..__._._.._._.__.. . . . . . . ._.
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Down-hole equipment data
...
. . Down-hole equipment . Description ID>··• Depth .·.
...·...
·
m r-
Xmas tree Tubing Restriction Tubing Casing
.· ..
0 1000 1000 2700 2930
Roughness
inch
inch ·.
2.992 2.75 2.992 6.366
0.0006 0.0006 0.0006 0.0006
Geothermal gradient
Measure depth .
..
Temperature
I
.. m
.•.
0 2930
r
F
80 163
· ·
. •·· ..
2
Overall heat transfer coefficient "U": 8 BTU/h/ft /F
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"U" (Overall heat transfer coefficient) It is used to calculate the heat transfer between the well and its surroundings. It is obtain from well test when well head temperature is available. In cose of lack of well head temperature the following rule of thumb can be used:
•
Oil and water wells :
8 -10 Btu/h/Jf/F
•
Condensate wells:
5- 7
Btu/h/Jf/F
•
Dry and wet gas wells:
1- 3
Btu/h/JfIF ,~
~----------------------------------------~
IPRdata
>
·Variable •••... ·.·
Reservoir pressure Reservoir temperature Water cut Productivity Index
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•••
...
··
Value.·...•.••.
2571 163 0 3.5
• ..
Ullif
psig
F %
Stb/day/psi
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r Results
For a well head pressure of 400 psig and 0% water cut estimate:
Variable
Well head temperature
Save the PROSPER file as P-Ol.out
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Tutorial P-02: Basic example gas well model construction
Objectives: Familiarize the user with PROSPER and the input of data Perform calculations in PROSPER Construct a gas well model in PROSPER with the data available and obtain results.
Expected results: Considering a well head pressure of 1000 psig and actual reservoir conditions we would like to know: Estimate the gas production rate Estimate the flowing bottom hole pressure Obtain well head temperature r
Data: PVT r
Variable·
:
. · . . · ...
.
·.
Separator pressure Oil/Condensate density CGR WGR Water salinity
('-, '
Value
Units ·.
1000 50 1 2
Psig API Stb/MMscf Stb/MMscf ppm
90000
.
.
Gas composition
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r r Compo11ent
...
·
.
Nitrogen Carbon dioxide Methane Ethane Propane
.. ··. ..
.
··.· Molar fraction . .. .
.. ·...
2% 0.5% 95% 2% 0.5%
..· ·Molecular weight· '
.
.
ibm/lbmol . 28
.··
44 16 30
44
Apparent molecular weight of air: 28.96 lbm/lbmol
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IPM Training Manual
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Down-hole equipment data ·Geothermal ... gradient
m 0 3000
l_: . ~ 1
I
·.·.
224
Down'hole equipment. ·
:Description.· ·. ·.. ....... Dl1pthm
.
. ..
.·
Xmas tree Tubing Restriction Tubing Casing
·.··
·. . .
0 2500 2500 2800 3000
. ;.··
.·· . . -
ID
•".
..
.inch.··
2.992 2.75 2.992 6.366
"U" (Overall heat transfer coefficient): 3 BTU/h/ft2/F
IPR data ..
Variable
Reservoir pressure Reservoir Temperature WGR CGR Permeability Net thickness Drainage Area Wei/bore radius Perforation thickness Skin c. (Dietz shape factor)
.'
1760 224 2 1 2 34 100 0.354 34 1 31.6
Value
·,
· Unit·".. •
psig F Stb/MMscf Stb/MMscf md m Acres Ft m
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Results For a well head pressure of 1000 psig calculate: .. ·.. ··•. .· . ·. · · · · Variable ··. Gas rate Flowing bottom hole pressure Well head temperature
I·..
•
Value
Units sm'/dia 2 Kg/cm
..
"C
Save this tutorial as P-02.aut
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IPM Training Manual
'-----------------------------------------------------------------Tutorial P-03: PVT Black oil matching for an oil well model This tutorial will show you how to match the PVT using lab data. Objectives Demonstrate the procedure to calibrate the PVT of an oil well model Review concepts of pressure drop and the importance of the PVT
Start the exercise from PROSPER file created in Tutorial P-Ol. (P-Ol.out)
Data PVTdata . Variables Solution GOR Oil density Gas specific gravity Water Salinity
.. .
.
. .
.
Value 430 34 0.73 85000
Units··.·.··..··.
•••
Scf/stb API ppm
PVT lab data: Pressure·
·. Tem11en1ture
..
•F
~
.
c
•
psig ~· ~
.GOR Scf/Stbc._ ·.
-
~·
Bo Rb/stb
·. .· .....
·.
J.loll
·. ·.·. ' Cp
163
2571
430
1.204
0.87
163
2235 *PB
430
1.209
0.84
163
1522
281
1.139
-
•··
PB: (Bubble point) r
....
•·.
Variable> . ··.
.
...
.··
····.· Selected multi phase correlation for Bo,Pb, GOR
. .
.
·Value
·
.
Selected multi phase correlation for ~-toil
c
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IPM Training Manual
--------------------------------------------------------Tutorial P-04: Selecting and matching a multiphase flow correlation for an oil well model Create an oil well model in PROSPER, match the well model with measure data available. Using the calibrated model estimate the water cut at which the naturally flowing well can no longer flow. Objectives
Demonstrate the procedure to calibrate a multiphase flow correlation for an oil well model Use the calibrated model to obtain production rate
Data PVT data (Tutorial 04 explains this section) Variables.
....··.··
.
.·
Solution GOR Oil density Gas specific gravity Water Salinity
value 430 34 0.73 85000
Units Scf/stb API
.. ·
ppm
(
PVT lab data:
•. ·.· OF
163 163 ,--._
163
.
·.
2235 *PB
GOR ..· Scf/Stb c 430 430
1522
281
Temperature .• 1·····.
Pressure •· psig 2571
.•
Bo Rb/stb
llon ·.
1.204 1.209
0.87
1.139
-
..
Cp
0.84
PB: (Bubble point)
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r r r
Down-hole equipment data
'
.
'
.
'
Measure depth',
m·
r
(
.. ,,.,'
Devi~tion survey •
,
'
,',
Geothermal ,
,',',
,'. ,' True vertical< depth · .. ,m : ,,
....
'
'.
'
0 443.4 475.7 601.2 1706.4
80
2902
1713
163
I·
0 1000 1000 2700 2700 2850 2902
Xmas tree Tubing Restriction Tubing Restriction Tubing Casing
r
'
''.
0 452 489 665 2885
. · , Down"hole equipment ·., Description Measure depth .. . m .· •...
r
~-oF
'··.·.
. ID inch
'.,
..
.
2.992 2.75 2.992 2.441 2.992 6.366
Overall heat transfer coefficient: 8 BTU/h/ft>/F
IPRdata
r Variable Reservoir pressure Reservoir temperature Water cut PI (Productivity index)
I
r
-
·
._ Value <•·. •. 2405 163 15 4.8
.
.· Units· · ,· ·.·
psig F %
Stb/day/psi
r
(
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1
·--------------------------------------------------------------------(
r
Well test data
Date,
01/10/09
WHP ·Psig
WHT :--_oF
Water .cut %.
.Liqui.d rate stb/day
,Gauge depth m
.. ;Gauge pressure. pSig
395
110
15
2100
2700
1796
GOR scf/stb
2405
250
Well matching calibration results I
r
.... ·•
. .·
Variable Selected multi phase correlation Matching Parameter 1 Matching Parameter 2 Flowing bottom hole pressure Calibrated Productivity index
.·
Value ·•
I
.Units
·.
t.o' /.(} f..,
I c;~
II'!
7-
psig stb/d/psi
The field is under water flooding operation, it is planned to maintain the reservoir actual reservoir r
•
pressure, and it is expected and increased water cut production in the near future for this well. Using the calibrated well model and the test well head pressure determine at which water cut the well will not be able to flow naturally.
I
Variable
Water cut
Value
·units
I
Save this tutorial as P-04.aut
r
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Tutorial P-05: Oil well model calibration review exercise This exercise was design to review the well model calibration procedure. There is PVT data from the lab that can be used to match a black oil correlation and well test data to calibrate and select a multiphase flow correlation. The calibrated model will be used to estimate erosion velocities.
r"··
Objectives: Review the well construction and calibration procedure using measured data. Perform calculations with the calibrate well model Estimate erosional velocities and suggest actions to avoid erosion. Generate lift curves for numerical simulators
Well matching procedure a) PVT matching 1.
PVT /Input data (Enter basic pvt data (solution GOR, oil density, gas gravity))
2.
Match data (Enter lab data)
3.
Regression
4.
Parameters (Check on parameters and look for the best black oil correlation)
I Match All
P, ::=1 Pz ::=0 5.
(
(
r
Select the chosen black oil correlation from the drop down menu.
b) Select and calibrate o multiphase flow correlation
f Matching I
VLP/IPR Q.C. (Enter well test data)
1.
Matching
2.
Estimate U value (Estimate the overall heat transfer coeffident and transfer it to the geothermal gradient section)
3.
Correlation Comparison i. Select the Q.C. correlations (Fancher Brown y Duns and Ros modified)
ii. If the test point lies between both correlations, select several correlations to compare with the test point. 4.
Match VLP I Select only 1 correlation i.
I Match
Check on correction parameters P, ;;1 (gravity term multiplier)P2;;1 (friction term multiplier).
c) IPR calibration
I Select the multiphase flow correlation calibrated f Calculate I Plot
1.
VLP/IPR
2.
IPR (Modify parameter with high uncertainty in the IPR to achieve the
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(
Data (
PVTdata
(
Variable . ··.·.·
'·.
·
.
...
Solution GOR Oil density Gas gravity Water salinity
·.···
.
Value
.·
Unit
.. •
·
2800 44 0.769 75000
·
..
.·
Scf/stb API ppm
PVT lab data: Pressure
so
. GOR
p~ig
Scf/Stb ·' 2800
7785.3 *PB
Rb/stb
PB: Bubble point
r Down-hole equipment
I
.·.•.•. Deviation survey ·' ·· ···· .: Geother111al .
t -• ·~ .~·.··-·····!Measure .
depth
! ' gradient ~ _ True vertical , Temperature .. 1 ,.depth · .... ' ·. ."F ·. · .
•ft. 0 85.3 1856.96 11358.30 20544.60 22385.20
r
r r
j ....:;_ ··~··· .·_ . . . _
I
.
23845.10
.
ft 0 85.3 1843.83 8307.09 12322.80 12821.50 13566.30
Xmas-tree Tubing
ft· .·•· ·,
Tubing Restriction Tubing Restriction Tubing Casing
'ID
11423.9 20600.4 22319.6 23218.5
···.
. •: .
I.····Roughn~ss
·.·. ·. inch._ • . . , inch'· -- · 4.13 3.81 4.13 3.75 4.13 3.75 3.18 3.81
sssv
·.
313
~·. Measuredepth . .
._ 85.3 1857
. 50
· :· · . ·· .::. : · <•' :•··.,··, Down-hole equipment 1 ~escription L 2>, ....:· · ·.···•·· ·._ .. ' :
;
6e-5 6e-5 6e-5 6e-s 6e-5
Over all heat transfer coefficient: 8 BTU/h/ft2/F www.ifm-solutions.com
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IPR Data
.....
·.· ... ··.
Variabl.e Reservoir model Reservoir pressure Water cut GOR Temperature
> •··•. •· · .· ••.. •·.· ·. ·
· Value ···.··.· .• VOGEL 7785.3 0 2800 313
...
.·
Units.· •.· •.. ·· .
psig % scf/stb •F
Well test data Data
WHT. ~F-·
1/2/2009
3235.3
178
Water cut· %
liq1,1id rate stb/day
Gauge depth. ft.
Gauge press. psig
Reservoir GOR pressure. scf/stb psig
0
9274
15251
5796.8
7785.3
2800
Questions
1. What are the multiphase flow correlation selected and the correction parameters?
Value · .
·•.·• .Variable Selected multiphase flow correlation Parameter 1 Parameter 2 ..··
(~
2.
Using the well test data determine: ·.· .. ..• ··· · ·.. ·• Variable .· Flowing bottom hole pressure Ll.p friction Ll.p gravity ·
r· ,.
.
.......
· • ·.·Value
Units psig psi psi
.
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/PM Training Manual
Erosion In PROSPER there are 2 equations to calculate the erosional velocity AP114E
It is used for fluids free of solids/sand production
c
Ve=--
K.
Ve: erosional velocity C: Empirical constant {400 -100}
lim: mixture density Conoco~Phil/ips
It is used when solids/sand are produced
D.K.
Ve=S ,fW
Ve: erosional velocity S: Geometric factor (elbows, T, etc) D: Pipe/tubing /.D.
&n: mixture density W: Sand production
3. Considering a C factor of 100 in the API 14E erosion velocity equation, it is desire to obtain the erosion velocity profile and the fluid velocity profile. (Plot erosional velocity vs depth and the fluid velocity (Total no slip velocity) vs depth)
4. What action can prevent the erosion of the tubing?
5. Generate lift curves to use in MBAL and in the numerical simulator Eclipse. What are the variables and ranges to use? ·..
..Variable
.
Minimum value
I
Maximum value ·
.
·...
Units
.·.. ·.
liquid rate
Save this tutorial as P-05.out
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IPM Training Manual
Tutorial P-06: Gas well model performance analysis This tutorial start from the gas well model created in tutorial P-02.
Objectives Analyze the performance of a gas well model Evaluate the operating condition and liquid loading probability Perform sensitivity analysis to optimize the gas production
Using the well model created in Tutorial P-02, PROSPER file P-02.out evaluate the following: 1.
Perform a VLP/IPR plot for a well head pressure of 1000 psig
2.
Perform a VLP/IPR plot for a well head pressure of 1000 psig and range of gas rates from 0.3 to 40 MMscf/day
Looking at the VLP/IPR intersection, what can we say about the stability of the solution? (Is it stable or unstable solution?). 3.
In the flowing bottom hole pressure, What are the contributions of well head pressure, friction losses and pressure drop due to gravity? . .·
.....
·. . · .. ·
Variable
....
.
. ·.·
Pressure · •
Percentage
ps1g
..
Well head pressure d.p gravity d.p friction
4.
Plot a pressure and temperature gradient for the solution of question 1. (Pressure and temperature vs depth)
5.
Plot the fluid velocity and critical velocity (Turner velocity) versus depth for the question 1. What can you say about the liquid loading probability of this well?
6.
Evaluate the effect of installing compressors. Plot the Gas rate of this well versus well head pressure.
Save the PROSPER file as P-06.out
r-
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Tutorial P-07: Gas well modelling performance Hydraulic fracturing This Tutorial starts from the gas well model created in Tutorial 02
Objectives Evaluate the performance of the well for a hydraulic fracture stimulation Perform a sensitivity analysis on the fracture half length and conductivity Perform a sensitivity analysis on the well head pressure Perform sensitivity analysis to the tubing size Estimate the P/Z abandonment value
Start opening the PROSPER file created in Tutorial P-02.
1.
Estimate the impact of hydraulic fracturing the well for a well head pressure of 1000 psig .
. ·.··. Porosity
Variable
....
·.
.·
FCD XL (Fracture half length ) Fracture height Time since production start
·.·· .
Value
-Units.
.·
14
%
10 30
m
Reservoir thickness 10
days
FCD: Dimensionless fracture conductivity
It is the relationship between the transfer capacity offluids of the fracture and the capacity of the reservoir to deliver fluids into the fracture.
K1 : Fracture capacity bf Fracture Width K,: Reservoir permeability XL: Fracture half /enght
-~
~-
.·
.
Value . .·
Variable·
Gas rate
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Units MMscf/day
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2.
Estimate the well performance at 1000 psig for a range of FCD and X,. FCD proposed values: S, 10, 20
X, proposed values: 10, 20, 30, 40, SO m The well performance is affected by this parameters and the cost of the fracture will also depend on these parameters. Gas rate table in MMscf/day
I· --·· .. ·•·FeD Xl m' ·. .
. s
.< '·.
'
..
. .• 10
·.·
..
·.·.·•
..
.·
!
'
• ••
20 ·. '
.
•
10 20 30 40
so 3.
Using the hydraulic fracture parameters of point 1, perform a sensitivity analysis to the well head pressure ranging from 200 psig to 1000 psig. Plot the gas rate in MMscf/day vs the well head pressure.
I.
'
WHP psig 200
.
.·
I
Gas rate· MMscf/day
.
400 600 800 1000
For a well head pressure of SOO psi and the hydraulic fracture of point 1 perform a sensitivity analysis to the tubing size. TubingiD inch .. 1.99S 2.441 2.992 3.9S8
<
Gas rate MMscf/day
For a well head pressure of SOO psi and the hydraulic fracture of point 1 determine the P/Z abandonment value for this field.
WHf' Psig
,.
Abandonment Reservoir Pressure Psig
soo
the PROSPER file r._._. . . . .Save ..__._._._. .. . .as . .P-Ol. . . .out ._.. ._._________._.. . . . . ._.._._______________________ www.ifm-solutions.com
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Tutorial P-08: Gas and condensate well model Construct a gas and condensate well model; obtain the expected gas production rate if the well head pressure is 1500 psig.
Objectives
r
Construct a gas and condensate well model Estimate gas flow rate and flowing bottom hole pressure Perform sensitivity analysis to well head pressure and tubing size Data
PVT .·
_'C·.
· Description ·
·...
Separator pressure Separator Temperature Separator GOR separator gas gravity Tank GOR Tank gas gravity Condensate density API WGR (condensed vaporized water) Water salinity
10000 0.5 0.8 0 4870 274 6495
C02 N2 H2S Dew point pressure Reservoir temperature Reservoir pressure (
Value.
500 80 6943 0.81 120 0.96 50.5
Units psig F scf/Stb
scf/stb
ppm % % % psig F psig
Deviation survey
Vertical well down to 15000 ft .
.r--Down-hole equipment -,:-
I
Description .
Xmas tree Tubing Restriction Tubing Casing
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·
...•.1 .
Measure depth ·.. · .. ·· Tubing/Casing ID ·..
._. •..
0 3000 14500 15000
.
ft
•.· .
<
•-···
---
2.992 2.441 2.992 6.366
Page 34/62
·• inch • •
• .. ·
I . ·.-
. --
·..
Roughness ·. inch
.
0.0006 0.0006 0.0006
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IPM Training Manual
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Geothermal gradient
r
Ambient temperature: 70"F. Reservoir temperature: 274 "Fat 15000 ft. Overall heat transfer coefficient: 5 Btu/h/ft2/f Reservoir data Petroleum Experts IPR reservoir model .·
·.
Description_ Reservoir Pressure Reservoir Temperature GOR WGR Reservoir permeability Reservoir thickness Drainage area c. Dietz shape factor Wellbore radius Perforation thickness Time since production started Porosity Residual water saturation Skin
"
··Values 6495 274 6944 2 17 120 100 31.6 0.354 120 100 11 25 1
·.
·.·.
-
.·
Units psig "F Scf/stb Stb/MMScf md
ft Acres (Dietz shape) ft
ft days % %
Questions 1.
For a well head pressure of 1500 psig, estimate: ·:c..·.·· ..
Variables
.·.
Gas flow rate
Value
.31,G1Z
Flowing bottom hole pressure Well head temperature
2.
Units MMscf/day psig
2..07- .-:":13
"F
Evaluate gas production increase with the following alternatives: Tubing size increase Well head pressure reduction (compression).
Which is the most attractive alternative?
Save the PROSPER file as P-OB.out www.ifm-solutions.com Page 35/62 /.----------------------------------------------------------------------------. © tFM-Solutions
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Tutorial P-09: Electrical submersible pump design
An electric submersible pump design is requested and we have the following data: Objectives
Using PROSPER design an electric submersible pump. Perform sensitivity analysis using the created model.
PVTdata Description
GOR Oil density
Value 170 28
scf/stb API
Gas gravity Water salinity
0.72 1000
ppm
Units
Deviation survey
Vertical well down to 1700 m Down-hole equipment Type
Measure depth m
Xmas tree Tubing
0 1600
Casing
1700
Tubing ID inch
2.441
TubingOD inch
2.875
CasingiD inch
6.36 6.36
Note: Top of Perforations at 1700 m Geothermal gradient Measure depth m
0 1700
Temperature •F
80 152
Overall heat transfer coefficient: 8 Btu/h/ft2/F
r
. _ _ .. ._ . _ . . _ _ .. . . . . . . .. _ _ . _ .. . . . . . . . . .. _ _ . _ . . _ . _ _ .. . . ._ . _ . . _ . _ _ . . _. . . .. _ _ . _ . _ . . ___
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IPM Training Manual
Reservoir data
Description
Reservoir Pressure Reservoir Temperature Water cut GOR Permeability Net thickness Drainage Area Dietz Shape factor c.: Wei/bore radius Skin
Units
Value
1630 152
psig
55 170
%
250 6 100 31 0.354 0
"F
scf/stb md m acres
ft
Results
Perform the design of an electric-submersible pump considering: Expected liquid rate of 1000 stb/day Assuming a well head pressure of 150 psi Operating frequency 60 hz Pump located 200m above the perforations
Selected ESP:
Description Pump selected
I
Description
Model
Number of stages
Model
HP
Perform a sensitivity analysis to the water cut and check that operating points are located inside the operating envelope of the ESP.
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!PM Training Manual
Tutorial P-10: Gas lift design
Objectives
Perform a gas lift design in PROSPER. Determine the number, depth and orifice of the unloading valves. Obtain the optimum gas lift injection rate that maximizes the production. PVT data Description
Value
500 32 0.65 75000
GOR Oil density Gas gravity Water salinity
Units
scf/stb API ppm
r System Equipment
r Deviation survey
Vertical well down to 2400 m
r
Down-hole equipment Type
Measure depth
m
Tubing/Casing ID inch
Roughness inch
Xmas tree Tubing
0 2200
2.99
0.0006
Casing
2400
6.36
0.0006
r
r Note: Packer depth 2200 m r
Geothermal gradient Measure depth
m 0 2400
Temperature "F 70 165
Overall heat transfer coefficient: 8 Btu/h/ft2/F
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Reservoir data
Description Reservoir Pressure Reservoir Temperature Water cut GOR Permeability Net Thickness Drainage area Dietz Shape factor Wellbore radius Skin
c.:
Value 2900 165 70 500 80 15 100 31 0.354 0
Units
psig
'F %
scf/stb md m acres ft
Gas lift data
Parameter Gas lift gas gravity Available gas Well head pressure Gas lift Casing pressure ~P valves Packer depth Water cut Minimum spacing between valves Valve type Completion fluid gradient
Value 0.65 20 200 1500 100
2200 70 100 CAMCO R-20 0.43
Units
MMsd/day psig psig psi m %
m Normal psi/ft
r
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--------------------------------------------------------
,-
Results 1.
Determine the number of mandrels/valves necessary to start up the well and their depths. Valve number
Depth m
1-
r
Determine the depth and size of the operating orifice: ............................................................ ..
2.
Determine the optimum gas lift injection rate that maximize the oil production rate for a well head pressure of 200 psi and water cuts of 70, 80 and 90%. Water cut
Optimum gas lift Injection rate MMscf/day
%
Oil production rate Stb/day
70 80 90 I
r
Performance curve
1000
r
r
900
r
,,
r
-
.,>.
-..
800 700
:
-
"'
600
r-
~
,-
0
soo
s:
~
::s
"D 0
r r
r ~
' : ,-
,r
r
a
5
400 300 200 100 0 0
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2
4
6
8 10 12 14 Gas lift gas lnjeetion rate MMscf/day
Page 40/62
16
18
·20
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IPM Training Manual
('
-------------------------------------------------------GAP GAP is the surface network modelling tool developed by Petroleum Experts Ltd. This tool can help the engineers to study a field in an integrated fashion. GAP can be linked directly to MBAL and PROSPER to model the entire system from the reservoir, wells and surface facilities.
Methodology Through exercises the engineer will familiarize with the use of GAP in different context. The engineer will have to solve reservoir engineering problems evaluating the field in an integrated fashion. The exercises and tutorials have been design to learn how to:
1. Set up GAP Models Constructing the network Linking the corresponding files to the icons Generating VLP/IPR
r
Entering pipeline data 2.
Solving the network Solve the network for: i. Non optimization case ii. Optimizing Initializing IPRs from tank simulations Performing sensitivity analysis
3.
Production forecast. Non-optimizing Optimizing Modifying the network and adding constraints and schedule.
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(~--------------------------------------------------------------------Tutorial G-01: Gas and condensate field integrated production model set up
(
,r
Objectives: Set up an integrated model for a gas and condensate field Familiarize with the use of GAP Generate IPR and VLP
The set up of a model in GAP consist on a series of steps:
1. Draw the layout of the system in GAP. ('
Using the short-cut icons showed below:
From left to right the icons are: Add Separator, Add Joint, Add link~pipe, Add Well, Add Tank
Draw the following layout:
( Woll2
Woll3
-.
-. ··.,
-' ···,X>.
·-. -.
2. Linking the icons with the corresponding file. The Tank and Well icons should have an associated file created in MBAL and PROSPER respectively. The Tank icon should be associated to the file created in the Tutorial M-Q3. (M-D3.mbi)
,--·
The Weill icon should be associated to the file created in the Tutorial P~08 (P~OB.out) The Well 2 and Well 3 icons should be associated to the PROSPER files attached in the auxiliary folder called: Aux_Files\day3\G-01_ Wefl2.aut and Aux_Fi/es\day3\G-D1_ Wel/3.out www.ifm~solutions.com
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(
Generating IPR and VLP
Generate the IPR from the main menu in GAP selecting:
Generate I Generate well /PRs with PROSPER (~
Generate the VLPs from the main menu in GAP selecting:
Generate I Generate well VLPs with PROSPER In the VLPs generation is very important to enter a wide range of conditions that will cover all possible intersections of VLP and IPR. Discuss the ranges of the different variables used. 4.
Pipe __
/
-
-_-
... _--
Enter the pipeline information
-
'----
-_
-- -----·
-.
.- ___ -
--
Length km Inside diameter inches Roughness inches Correlation Outside Temp "F Overall heat Transfer coef. BTU/h/F/ft'
-
WHlto - Manifold 3 6 0.0006 Beggs and Brill 70 3
·----_
WH2to Manifold
2.5 6 0.0006 Beggs and Brill 70
3
WH3to mar\ifpld 4 6 0.0006 Beggs and Brill 70 3
Manifold to - sepjoint 40 11 0.0006 Beggs and Brill 70
3
Note: Assume a flat terrain for all the pipelines
Save the GAP file as
G-Ol.gap
(
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Oifmsolutions ~INTEGRATED FIELD MODELING
IPM Training Manual
Tutorial G-02: Integrated Production model- Solve Network
Objectives:
Familiarize with the concepts of: How to solve the network in GAP Initialize the IPRs from Tank simulations Optimize/Non-optimize options Performing sensitivities
1.
Solve the network for a Separator pressure of 1000 psig Analyze the gas production rate at the separator and in each well in the system. ·.
·•.
·..
.··
.
·.well.l
·.
.....
Wefl2
·...
·.
·
Well3 .
Separator
.··
..
Gas production rateMMscf/day
2.
Initialize the IPRs from Tank simulations at the most recent date Discuss the changes.
3.
Solve the network for a Separator pressure of 1000 psig Analyze the total gas production rate and in each well. .
··Weill ··
...
Well2 _:: _
Wefl3
.
·.
.
Separator
Gas production ... · rateMMsd/day
What is the difference between point 1 and point 3?
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4.
Evaluate the installation of compressors at the plant {Separator location), for that perform a sensitivity analysis to the separator pressure ranging fram 1000 psig to 100 psig.
1
1000 800 600 400 200 100
... c c r
Separator pres.sure Separator Gas l)roduction rate ., MMscf/day · · .. ·.··. · psig . .· I·· · .· ·.
5. In the plant a piece of equipment will be out of service for a couple of months for a major maintenance; this will limit the total capacity of the plant to 45 MMscf/doy of gas at the separator level. Solve the network optimizing with this limitation with a separator pressure of 1000 psig and
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check how GAP honours this constraint. Which well is GAP chocking back? Why?
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6.
The reservoir engineer is considering shut in Well 2 for a pressure build transient test during the plant limited capacity period. How much gas production rate is expected from the rest of the wells?
("" ••
:
.·
.
'
7':
·.Weill.
Well3
Separator
Gas production · I · rate MIViscf/dev
r r r
Save the GAP file as G-02.gap
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/PM Training Manual
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Tutorial G-03: Integrated Production Model - Production forecast
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Objectives:
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Familiarize the user on how to perform production forecasts Perform different prediction scenarios saving the results
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The production forecast will be performed from the most recent date entered in the production history of the tank until 01/01/2025 with 1 month time step size.
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a. Perform a production forecast using a separator pressure of 1000 psig with all wells fully open. Check the results such as gas production rate profiles at the separator, per well and fill in the next tables:
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Cumulative gas production 8scft2""1
Weill ·_
.Separator.
-
-
--
--
weu.z
--
_-• .. Well 3 _ -- --
--_
' Gas recovery factor%
-_
Abandonment reservoir pressure __ P/Zabandonment · ·
- .-- __ •-
b. A new contract is being negotiated; the company should be able to deliver 55 MMscf/day of gas until 01/07/2018. As a reservoir engineer in charge of the field you have to evaluate if it is possible to achieve this target rate. For that you might have to evaluate different alternatives. i. . Set up the constraint at the separator level ii. Set all the well in controllable iii. Perform a prediction optimizing to check if the field is able to produce the target rate for mentioned period without additional investments.
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iv.
If necessary to be able to achieve the contract rate evaluate the following scenarios:
1. Installing compressor at the plant (Separator location), specify compressors installation timing and inlet pressure. 2./nstalling compressors at the manifold, specify compression installation timing, inlet pressure and power requirements. 3.Drilling additional wells, select a type well, specify drill plan schedule. 4. Pulling/Workover option, changing the tubing size of the wells. Comment and discuss the results with your colleagues. Save the GAP file as G-03.gap
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IPM Training Manual
Tutorial G-04: Integrated model for an Oil field A recent discovered offshore oil field is on production with one well located 16000 feet from an existing production platform. The water depth in the region is approximately 85 feet as shown in the next diagram.
185ft I
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The pipeline is an 8 inches ID and the separator in the platform is operating at 400 psig.
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The reservoir is modelled in MBAL and the file has been created by the reservoir engineer and is
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located in the Auxiliary files folder AuxJiles\day3\G.04_Tank.mbi The well model is the PROSPER file created in the tutorial P-05, P-OS.out The separator maximum capacity allocated for this field is of 50000 stb/day of liquid. Perform the following steps:
1. Construct the GAP lay-out for this system 2.
Perform a production forecast from the end of the production history until January 2029 using 1 month time step size for the first couple of years and 2 months time step size until
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the end. 3.
Evaluate the oil production rate evolution, the oil recovery factor, the cumulative oil production.
4.
It is possible to drill 2 more wells with a distance of 5000 feet from the discovery well, evaluate the impact of drilling these wells in 2012 (January and June respectively).
5.
Evaluate the option of maintaining the reservoir pressure by means of water injection at 6800 psig. When it will be required to inject water in the reservoir to avoid going below the proposed value? How much water injection rate would be required?
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bifmsolutions ~ INTEGRATED FIELD MODELING
IPM Training Manual
Workshop I
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Tutorial W-01: Gas field integrated model
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A gas field located on-land is producing since 1973 with an average gas rate production of 30 MMscf/day. Since 2010 a new contract was signed to deliver 45 MMscf/day until January 2020. Evaluate if this contract is feasible and consider different options to achieve the contract using the data provided below: Schematic of the field:
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Gl:620m
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,.. 13500 m 10:10 indl
4100 m 10:10 inch
1200 m 10:10 inch
Well1 GL~
GL: 620m
811 rn
GL: 605m
The delivery point pressure is 70 kg/cm 2 •
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INTEGRATED FIELD MODELING
IPM Training Manual
PVTdata . · Parameters
.·' .
Value
Specific gas gravity Separator pressure CGR (Condensate to gas ratio) Oil density Water salinity H2S% C02% N2%
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_:_ Units ·
0.71 1000 7 42 70000 0 11 1
Psig Stb/MMscf API
Ppm %
% %
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Reservoir data (
!
·,.
·.. ··.
· :'Parameters · :
<
Reservoir temperature Reservoir initial pressure Average porosity Connate water saturation Reservoir thickness
.•. Value 302
. ' ·.
•
Units
...
.
OF Psig
8659 6 32
% %
67
feet
The production and reservoir pressure history is located in the file W-Dl_Production_history.xls located in the auxiliary files folder. (AuxJiles\day4\ W-Ol_Production_Histary.xls)
Wells data The following section describes the well data
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IPM Training Manual
r Weill
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Deviation Survey Measured depth ...•. ·
True Vertical depth .... ·.feet . · •· 0 12598 12956 14087 17443 17759 18657
l:·•.··... ·. ·feet.· 0 12598 12959 14091 17454 17772 18678
r r Down-hole equipment
.. r r
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.
..
Type Xmas Tree Tubing Restriction Tubing Restriction Tubing_ Casing
. 1 ••
Tubing roughness ··inches ·•··
•Measured depth ·.·. .TubingiD · ·feet · inches· 0 109 3.96 3.81 14403 2.99 2.2 14435 2.99 17740
Casing rollghriess inches
Casing ID · inches·
0.0006 0.0006 0.0006 4.41
0.0006
Geothermal gradient
r .·
I·
Measured depth feet
·
1
.
Formation temperature
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0 17740
r
'F59 302
.
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(·
2
Overall heat transfer coefficient: 2 Btu/h/ft /F Inflow performance data
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Parameter-
..
I
• ·. Value
Units
Cand n Reservoir Model Reservoir Pressure Reservoir Temperature Water-Gas Ratio Condensate Gas Ratio
... ..
.·
c n
·.·
·· ...· . . ·
3118 302 0 7 IPRModel data ··. . ·.· · 0.0096 I 1 I
(psi\1) (deq F)
(STB/MMscf) (STB/MMscf) ·.
I (Mscfldaylpsi2) I
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Well2 Deviation survey
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· · Measured depth . True vertical depth ···•·· ··•··· .. .feel >. · .··:·feet .. ·.·.......
0 13238 16063 19423 19715
0 13238 16053 19393 19678
Down-hole equipment
·.·
r
...
Type Xmas Tree Tubing Restriction Tubing Restriction Tubing Casing
Casing ;.·Casing Tubing Measured Tubing depth ·..• roughness ID ·.· •.• roughness. ID inches · ·.· inches· .· inches feet ·. inches
0 106 14567 14600 16463
3.96 2.61 3.96 3.46 3.96
0.0006 0.0006 0.0006 6.36
0.0006
r
r r
Geothermal gradient Measure depth
· 'feef··• •• 0 16463
Formation·temperature
.·...... · OF
.· .
59 260
Overall heat transfer coefficient: 2 Btu/h/ft 2/F r
Inflow performance data .
· Parameter' Value Units Reservoir Model C and n (psiql 3060.1 Reservoir Pressure (deq F) Reservoir Temperature 302 (STB!MMscf) Water-Gas Ratio 0 (STB/MMscf) Condensate Gas Ratio 823 ... ·•· . . .. . . ·.· I IPRmodeldata ·.· · .·.... · 0.009 (Mscfiday/psi2) I n 1 I .
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IPM Training Manual
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Well3 Deviation survey True vertical depth Measure depth ..·.· I . feet· .feet 0 0 7298 7298 12467 12464 12549 12546 13041 13038 14321 14316 14518 14512 15502 15482 16781 16729 17175 17109 17758 17676 17848 17765
.·.· ....
Down-hole equipment .
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Type
.
'
.
· · ·,·•
Xmas Tree TubinQ Restriction TubinQ TubinQ Restriction Tubing Restriction Tubing Casing
.Mea.sured .•Tubing depth,.·.··. . ..JD. inches • feet 0 3.96 105 3.81 17038 3.96 17048 2.99 2.75 17111 2.99 2.2 17144 2.99 17270
Tubing Casing ·· Casing roughness .• .10 - . roughness ·· inches· ·inches inches
0.0006 0.0006 0.0006 0.0006 0.0006 6.46
0.0006
Geothermal gradient Measure depth . .. feel 0 17270
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... .F:olll)ation temperature ...
•F .
.. .
.
59 302
Overall heat transfer coefficient: 2 Btu/h/ft'/F Inflow performance data · ··• · Parameter Reservoir Model Reservoir Pressure Reservoir Temperature Water-Gas Ratio Condensate Gas Ratio
c n
Value· C and n 3073.16
·Units
(psiQ)
302 0
(deq F) (STB/MMscf)
8.23
(STBIMMscf)
0.3749 0.71848
(Mscf/davlosi2)
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Questions: Is it possible to achieve the proposed contract? What actions should be considered?
............ " ,., ' ........... ······ ..................................................... " ......... " ............................................... ' ........... .
................................................................................................................................................................. ................................................................................................................................................................. .................................................................................................................................................................
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IPM Training Manual
Tutorial W-02: Gas field integrated model- Part 2 The company has made a new discovery nearby the gas field modelled in the Tutorial W-01. A new structure located 12 km south of Well 2 containing dry gas reservoir. The process engineers are considering tie-in the new field to the existing facilities. The company is evaluating extending the existing gas sale contract from 45 MMscf/day to 60 MMscf/day from June-2012 until 2020. The following parameters have been estimated:
.~
·•··
Value ·..
Parameter .·
Units
Reservoir depth
12320
feet
Reservoir Temperature
230
OF
Pressure gradient
Normal
GOIS volumetric estimation
137
Bscf
Reservoir permeability
32
md
Net thickness
34.7
feet
Drainage area
500
Acres
Specific gas gravity
0.675
CGR
5.1
stb/MMscf
Oil density
47
API
Water salinity
100000
ppm
H25
0
co,
6
%
N,
0.5
%
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Evaluate if it is possible to achieve the proposed target rate for the proposed period, estimate the number of wells required in the new structure.
Also evaluate if the gas production of the existing wells will be impacted by the back pressure of this new development.
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Oifmsolutions ~INTEGRATED FIELD MODELING
IPM Training Manual
Tutorial W-03: Offshore Oil field development plan
Objectives An offshore oil field has been discovered with two reservoirs (Reservoir 1 and Reservoir 2) and few data is available. The discovered field is located some 20 km from an existing platform. With some minor investment the existing platform can accommodate additional40000 stb/day of liquid. The platform contains dedicated export oil and gas flow-lines going to the shore.
Using the data provided below design a field development plan, a minimum recovery factor of 30% for both reservoirs will make this project attractive. The proposed start date of production is 01/06/2014 and end of concession is 1/01/2027. In the next diagram and tables you will find all the data available:
45•F 20km
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14800 feet 13700feet
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.·
• Data ·. OOIP Pressure GOR API Gas gravity Reservoir depth Permeability Net thickness Porosity Connate water saturation Water salinity Reservoir Temperature
·Reservoir 1 160 6600 470 36 0.68 13700 52 22 0.19 0.23 87000 197
.Reservoir 2 70 10200 1450 41 0.72 14800 420 45 0.23 0.15 12000 240
Units.· MMstb psig
scf/stb
TVDSS (feet) rnd feet fraction fraction ppm "F
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IPM Training Manual
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Relative permeability curve Corey function table Phase.
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<
Water
Oil Gas
...
..
~
·.·.
Residual -~· . saturation 0.23/0.15 0.15 0.02
End Point
..
...
0.8
.7 0.9
Corey Exponent .
.·.
1 1.5 1
Field development plan description (e.g. number of wells, drill plan schedule, type of wells (e.g. naturally flowing, artificially lifted), water injection requirements, etc)
.................................................................................................................................................................
Plot the expected oil production rate, water production rate, gas production rate.
What is the oil recovery factor for reservoir 1 and reservoir 2? r-
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Tutorial W-04: Tight gas well modelling
Objectives: Practice the steps to construct and calibrate tight gas well model Data Provided PVT data ·..
Gas gravity
. .··
0.7
Separator Pressure. ·
...
.
CGR
2 35
Condensate gravity Watersalinity · · · .. ~··
(
H2S
.
C02 N2
·.
.. .
<.
...·. ··.
250
·
·.
... · .. ·
29000
...
. ·.
psig Stb/MMscf API ppm
0 0 0
Petro-physical parameters
Model Type Well Radius _ .•.. ·.
..
...
Well in Bounded Radial Reservoir ·
.
0.354
(feet)
..
0 0
(1/(Mscf/day))
5000
(psig)
200
(deg F)
Darcy Skiri(S) .·· · •. · · . •··· Non- Darcy Skin (D) ••·· Initial Pressure·.·.·..•· ••· .. • . r·
lnitiaiTemperature ·•
.··
.
0.1
(md)
Drainage•AreaRadius
.
650
(feet)
Porosity
. .·
0.1
(fraction)
....
200
(feet)
0
(day)
0.4
(fraction)
Use Corr
(1/psi)
4.00E-06
(1/psi)
Permeability •
.··
·.··
••
LayerThickneiss • Start.of Production ·•
·•··
.ConnateWater,Saturation Water Compressibility ·•· Rock.Compressibility
..
·.
Well data information
The well is a vertical well down to 12000 feet with a 2 7/8" tubing (ID 2.441 inch) 2
Overall heat transfer coefficient 3 Btu/f/h/ft and ambient temperature of 70•F. The well test data is provided in the Excel spread sheet called
AuxJiles\day5\ Tight_gas_we/1_ Test.xls
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