IFM Solutions IPM Training Course

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Integrated production modelling

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• An Introduction to PROSPER, MBAL and GAP

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IPM Training Manual

Copyright notice

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.

/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

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 www.ifm-solutions.com J HIJ."Josiluill Hlz;~ ft. Fiscal de Produccl'on V.P.A.C.F.·D.R.P. YPFB Page 2/62 © JFM-Solutions

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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 Dayl Day 2 Day3 Day4 DayS www.ifm-solutions.com Introduction to MBAL

Materia! balance concept review History matching

o Graphical method (Havlena Odeh, Campbell, Cole) o 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.

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 Analyzing the well performance

Introduction to GAP

Building a surface network model

Integrating PROSPER and MBAL files

Performing production forecasting within GAP

Integrated model Workshop

Field development planning using !PM

This is a review of all concepts learnt (MBAL·PROSPER-GAP)

PVT equation of state characterization

Tight gas well modelling (PROSPER, MBAL, GAP) ESP design

Gas lift design

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The concept of IPM

A production system can be visualised in a simple form as shown in the next sketch:

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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The IPM modelling platform

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

PROSPER

•

• MBAL

PVTP is used to characterise the fluid pressure- volume temperature behaviour and is used to 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

Introduction and scope of work

In the overall scheme that we will follow during this course we will build an integrated model of a

very simple condensate field.

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

Day1

!····Wl

Day2

!····Wl

Day3 L ..

Q

Day4

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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

Fractional flow curve matching, Fw, Fg Obtaining the OOIP,

GIIP

Estimating the parameters of the aquifer to obtain the best match Estimating the drive mechanism

3. Running a simulation

4.

Production forecast using MBAL in standalone.

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IPM Training Manual

Tutorial M-01: Performing the history matching in MBAL for a gas reservoir

Objectives:

Familiarize the user with MBAL and practice the procedure to perform a history matching of a gas reservoir material balance model.

Reservoir data

PVT

.

. _{'·Parameters} _..._·_...

·

_... _> _{Value ·· .. I·· ..}

units ··· . Specific gas gravity 0.85

Separator pressure 990 Psig CGR (Condensate to gas ratio) 2 Stb/MMscf Oil density 42 API

Water salinity 10000 Ppm

H2S% 0 %

C02% 0 %

N2% 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. _> Residual Saturation.· ·

_I·

< EndPoint

I

Corey•Exponent .··· •·• . ·

Water 0.20 0.6 1

Gas 0.02 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 • . . ·. .

..

•. _{·.Value •·}

••• I ,.·.· ... • ·.· .. Units

Gas initial in place Bscf Determine the presence of an aquifer yes/no Actual recovery factor %

Save this tutorial as M-01.mbi

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Tutorial M-02: Perform the history matching in MBAL for an oil reservoir

Objectives:

Familiarize the user with MBAL and the steps to perform the history matching of an oil material balance reservoir model.

Reservoir data

PVT data

· ·• .· · ·parameters .· ·.·

...

_·. _{· ·. ·Value} .

units

GOR 250 Scf/stb Oil density 32 API Specific gas gravity 0.65

H2S% 0 %

C02% 0 %

N2% 0 %

Reservoir temperature: 197 "F.

The bubble point pressure has been measured in constant composition expansion experiment; the value is 1670 psig @ 197"F.

The initial reservoir pressure at the datum depth is 4217 psig. Datum depth: 9370 feet.

The following table shows the oil formation volume factor at different pressures.

Pressure

· Bo

I

•psig . :··rb/stb 4217 1.118 3725 1.1221 3390 1.1249 1670 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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,-.---1 Pseudo relative permeability curves data

r 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:

r Variables · .... ·.··

..

. . ·.· Value· ,; .··· Units:·: · ... ·

Oil initial in place MMstb Gas initial in place Bscf Actual recovery factor %

Active aquifer exist Yes/No Is there an initial gas cap? Yes/No

Save this tutorial as

M-02.mbi

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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

. . .

.

-"

_{Parameters ·}

.

_{··.· .. ··}

. I Value _··.

·Units

Separator pressure 500 psig Separator Temperature 80

OF

Separator GOR 6943 scf/stb Separator gas gravity 0.81

TankGOR 120 scf/stb Tank gas gravity 0.96

Condensate gravity 50.5 API Water salinity 100000 ppm Dewpoint at reservoir temp 4870 psig Reservoir Temperature 274

OF

Reservoir pressure 6495 psig

H2S 0 %

co,

0 %

N,

0 %

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.

.

~

Phase---

:-

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:

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... _{. _Variables · .. ·}

.

_{·.·· · .·.} _{·. ·value. • - .•}

_{. I>< . - ul1its . • •}

Gas initial in place Bscf Determine the presence of an aquifer yes/no Actual recovery factor %

Main drive mechanism

Save this tutorial as M-03.mbi

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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

I

· Parameters .. · .. ·· · · <,Value · :

...

Units

GOR 800 Scf/stb

Oil density 35 API Specific gas gravity 0.78

H2S%

0

%

C02% 0 %

N2% 0 %

The measured reservoir temperature is 250 ·F with an initial reservoir pressure of 5215 psig.

PVT Laboratory measurements

Temjlerlltu~e · Pressure .. Bubble .point 1.· ·.· GOR · Bo · · ...

I

_{Oil viscosity} 'F'· ... ·

_{l_}

psig · 'psig

_{I ·•}

_{.< Scf/si:b _} .. ·. rb/stb . ·, · ··:· .···· .. ·. cp • __

<

250 3600 3600 800 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.

I :: • ·· ..

Ph~se • .. ·: ..

···

I .

·.Residual Saturation .· · : End Point :. : .• . Corey ExponenL

Water 0.19 0.6 1

Oil 0.15 0.8 1 _'

Gas 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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Perform the history matching ofthe model and answer the following points:

'

..

;

_Variables:>'. ';_ '___· _-- ~ ' Value • _···-;'-_.·--.-·

I· . .

·

Units ._··, ·. ---·

Oil initial in place MMstb Gas initial in place Bscf Actual oil recovery factor %

Active aquifer exist Yes/No Is there an initial gas cap? Yes/No Main drive mechanism

Section 2: Production forecast

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-l.tpd).

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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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·: .· . C Mscf/day/psi' . _N . M5-1 0.008345 0.94123 M5-2 0.011195 0.92674 M5-3 0.0082 0.94 M5-4 0.007865 0.93771

Questions

Perform a production forecast until 01/01/2027 and answer the following points:

.•. _{· . Variables ·} .

I

_Value _Units

Plot the gas production rate evolution

Estimate the gas recovery factor in 2027 %

Estimate the gas proved developed reserves Bscf Estimate the P/2 abandonment value 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:.

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PROSPER

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

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. Estimate well head temperature. Data PVTdata Variable· .. ·.·. · .. .

..

. Solution GOR Oil density Gas gravity Water salinity Deviation Survey Value 430 34 0.73 85000 • r • _{Deviation Survey} ·. .· . •

...

~ .

.

. . . . . .

.

... .. · True vertical .. Unit · . . Scf/stb API ppm

1.

Geothermal : ·· · gradient . ··• •

Measur~~···

.. . Temperature .

I

depth· :.··· L dE!pth · ·.'. . .. "F .. ·

· . . . m<· .. ··.·

_{m ·.}

I

· .. ·.· ...•... ·· ..

0 0 80 452 443.4 489 475.7 564 535 665 601.2 790 663.1 1896 1145 2736 1639.9 2885 1706.4 2930 1726.5 163 r . _ . _ . . . _ . . . _ . _ . . . . _ . . . . . _ _ . . _ . _ . . . _ _ . _ . _ . . _ . _ . _ _ . . . . _ .

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Down-hole equipment data

... _{Down-hole equipment .} . .

Description Depth .·. ID>··• Roughness

m · ... · ... .· .. _{inch ·.} _inch Xmas tree 0 Tubing 1000 2.992 0.0006 Restriction 1000 2.75 0.0006 Tubing 2700 2.992 0.0006 Casing 2930 6.366 0.0006 Geothermal gradient Measure depth

I

Temperature · · . ..

_{.. m}

.•. F . •·· .. 0 80 2930 163 Overall heat transfer coefficient "U": 8 BTU/h/ft2/F

"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 :

• Condensate wells: • Dry and wet gas wells:

8 -10 Btu/h/Jf /F 5- 7 Btu/h/Jf /F 1 - 3 Btu/h/Jf

IF

,~ ~---~ IPRdata

>

·Variable •••... ·.· _••• ··

...

_{Value.· ...•.••.} • . . Ullif

Reservoir pressure 2571 psig Reservoir temperature 163 F

r

_{Water cut} ₀ _%

Productivity Index 3.5 Stb/day/psi

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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:

r r ( ' - , ' (

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Data: PVT

Estimate the gas production rate

Estimate the flowing bottom hole pressure Obtain well head temperature

Variable·

:

. · . . · ... _._·. Separator pressure Oil/Condensate density CGR WGR Water salinity Gas composition Value 1000 50 1 2 90000

Compo11ent . . ··. _{· ·.· Molar fraction} _{.. ·}

...

·

.

. . .

..

·...

. .. . ' Nitrogen 2% Carbon dioxide 0.5% Methane 95% Ethane 2% Propane 0.5% Apparent molecular weight of air: 28.96 lbm/lbmol

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---Units · . . . Psig API Stb/MMscf Stb/MMscf ppm ·Molecular weight· . . _{ibm/lbmol .} .·· 28

44

16 30

44

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m

0 3000 ·Geothermal ... gradient 224 l_: . ~ ·.·. Down'hole equipment. · .·· . . -1 :Description.· · .. · .. ... Dl1pthm •". ID I . . .. .· ·.·· · . . .

.

_;.··

.. _.inch.·· Xmas tree 0 Tubing 2500 2.992 Restriction 2500 2.75 Tubing 2800 2.992 Casing 3000 6.366

"U" (Overall heat transfer coefficient): 3 BTU/h/ft2_/F

IPR data

..

Variable . '

Value ·, _{·· Unit·".. •}

Reservoir pressure 1760 psig Reservoir Temperature 224 F

WGR 2 Stb/MMscf CGR 1 Stb/MMscf Permeability 2 md

Net thickness 34 m Drainage Area 100 Acres Wei/bore radius 0.354 Ft Perforation thickness 34 m

Skin 1

c.

(Dietz shape factor) 31.6

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Results

For a well head pressure of 1000 psig calculate:

.··. ·. · · · ·· Variable ··. .. · .. ··•. I· .. • Value

Gas rate

Flowing bottom hole pressure Well head temperature

Save this tutorial as P-02.aut

Units ..

sm'/dia Kg/cm2

"C

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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 .

..

. . . _Value

•••

Units··.·.·· .. ··.

Solution GOR 430 Scf/stb Oil density 34 API Gas specific gravity 0.73

Water Salinity 85000 ppm PVT lab data:

·. Tem11en1ture Pressure· .GOR Bo

.. •F ~ .. c • psig _{~· ~} - Scf/Stbc._ ·. ~· Rb/stb 163 2571 430 1.204 163 2235 *PB 430 1.209 163 1522 281 1.139 PB: (Bubble point) ·.

_·.

_J.loll

.·

...

_{· .. ·.·. ' Cp}

_•··

0.87 0.84

-....

_•·.

····.·

Variable> . ··. .

...

_.·· _._. _. _·Value _· _.

Selected multi phase correlation for Bo,Pb, GOR Selected multi phase correlation for ~-toil

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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. .... ··.·· . _.· _value _Units . . ·

Solution GOR 430 Scf/stb Oil density 34 API Gas specific gravity 0.73

Water Salinity 85000 ppm

PVT lab data:

Temperature .• 1···. Pressure ·. GOR .• Bo

llon

.. •. ·.· OF . _•· _psig _{.. · Scf/Stb c} _Rb/stb ·. _Cp 163 2571 430 1.204 0.87 163 2235 *PB 430 1.209 0.84 163 1522 281 1.139

-PB: (Bubble point)

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Down-hole equipment data

, Devi~tion survey •

..

,,.,' Geothermal ,

' ' ' . ' ,', , ' , ' , <gradiellt • ,

Measure ,'. ,' True vertical< Temperature depth', , , depth

'.

~-oF

.

'··.· .

m·

· .. ' : ,m

....

' ' ' . ' 0 0 80 452 443.4 489 475.7 r 665 601.2 2885 1706.4 2902 1713 163 ( . · , Down"hole equipment ·.,

.

r

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Description Measure depth

_I·

ID ' . , ..

. . . m .· •... _inch . Xmas tree 0 Tubing 1000 2.992 Restriction 1000 2.75 Tubing 2700 2.992 Restriction 2700 2.441 Tubing 2850 2.992 Casing 2902 6.366 Overall heat transfer coefficient: 8 BTU/h/ft>/F

IPRdata

Variable _- · ._ Value <•·. •. . .· Units· · ,· ·.·

Reservoir pressure 2405 psig Reservoir temperature 163 F Water cut 15 %

PI (Productivity index) 4.8 Stb/day/psi

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Well test data

Date, WHP WHT Water .Liqui.d rate

·Psig :--_oF .cut stb/day %.

01/10/09 395 110 15 2100

Well matching calibration results

. . · _Variable

....

_·• _.·

Selected multi phase correlation Matching Parameter 1

Matching Parameter 2 Flowing bottom hole pressure Calibrated Productivity index

,Gauge .. ;Gauge depth pressure. m pSig 2700 1796 2405 Value ·•

I

.Units ·.

t.o'

/.(} f.., I c;~

7-

psig II'! stb/d/psi GOR scf/stb 250

The field is under water flooding operation, it is planned to maintain the reservoir actual reservoir 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 Value ·units

I

Water cut

Save this tutorial as P-04.aut

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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.

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

I

Match All

4. Parameters (Check on parameters and look for the best black oil correlation)

P, ::=1 Pz ::=0

5. Select the chosen black oil correlation from the drop down menu.

b) Select and calibrate o multiphase flow correlation

1. Matching

f

Matching

I

VLP/IPR Q.C. (Enter well test data)

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

Match

i. Check on correction parameters P, ;;1 (gravity term multiplier)P₂;;1

(friction term multiplier).

c) IPR calibration

1. VLP/IPR

I

Select the multi phase flow correlation calibrated

f

Calculate

I

Plot 2. IPR (Modify parameter with high uncertainty in the IPR to achieve the

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r r r !PM Training Manual Data PVTdata

Variable . ··.·.· '·. . ·

...

·.··· _Value

.

· .. • Unit .· · ..

Solution GOR Oil density Gas gravity Water salinity PVT lab data: Pressure p~ig 7785.3 *PB PB: Bubble point Down-hole equipment 2800 44 0.769 75000 . GOR Scf/Stb ·' 2800

I

.·.•.•.

Deviation survey ·' ·· · ··· .

t -•

·~

.

~·.··-···-

j .... :;_

··~···

.·_ ... _

!Measure . depth · .. · 1 True vertical . ,.depth · .... •ft. I . ft 0 0 85.3 85.3 1856.96 1843.83 11358.30 8307.09 20544.60 12322.80 22385.20 12821.50 23845.10 13566.30 Scf/stb API ppm

so

Rb/stb : Geother111al . ! ' gradient ~ _ , Temperature .. ' ·. ."F

.

; . ·. 50 313 .·

· :· · . ·· .::. : · <•' :•··.,··,

Down-hole equipment

···.

.

_•:

.

1

~escription

···•·· .. ~·. Measuredepth . . 'ID I.····Roughn~ss

L

2>, .... :···.·._

' : ._ ft· .·•· ·, ·.·. · .. inch._ • . . , inch'· -- ·· Xmas-tree 85.3 Tubing 1857 4.13 6e-5

sssv

3.81 Tubing 11423.9 4.13 6e-5 Restriction 3.75 Tubing 20600.4 4.13 6e-5 Restriction 3.75 Tubing 22319.6 3.18 6e-s Casing 23218.5 3.81 6e-5

Over all heat transfer coefficient: 8 BTU/h/ft2/F

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IPR Data

> •··•. •· · .· •• .. •·.· ·. · Variabl.e

...

·.· ... ··. · Value ···.··.· .•

...

.· Units.· •. · • .. ·· . Reservoir model VOGEL

Reservoir pressure 7785.3 psig

Water cut 0 %

GOR 2800 scf/stb

Temperature 313 •F

Well test data

Data WHT. Water liq1,1id rate Gauge Gauge Reservoir GOR

~F-· _cut· _stb/day _depth. _press. _{pressure. scf/stb}

%

ft. psig psig

1/2/2009 3235.3 178 0 9274 15251 5796.8 7785.3 2800

Questions

1. What are the multiphase flow correlation selected and the correction parameters?

.. ·· . _·•.·• _.Variable Value · .

Selected multiphase flow correlation Parameter 1

Parameter 2

(~

2. Using the well test data determine:

·.· .. · ..• ··· · · .. ·• Variable .·

...

· • ·.·Value Units .

Flowing bottom hole pressure psig

Ll.p friction psi

Ll.p gravity psi

r·

,.

_______________________ _

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Erosion

In PROSPER there are 2 equations to calculate the erosional velocity

AP114E

It is used for fluids free of solids/sand production

Conoco~Phil/ips

It is used when solids/sand are produced

c

Ve=--K.

D.K.

Ve=S ,fW

Ve: erosional velocity

C: Empirical constant {400 -100}

lim: mixture density

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

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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

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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 .

. ·.··. _Variable

....

·. .· ·.·· . Value .· _{-Units .}

Porosity

14

%

FCD

10

XL (Fracture half length ) 30 m Fracture height Reservoir

thickness

Time since production start 10 days

FCD: Dimensionless fracture conductivity

It is the relationship between the transfer capacity of fluids 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

.· . Variable· Gas rate www.ifm-solutions.com ~-Value . . · Units MMscf/day Page 32/62 © IFM-Solutions

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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

. < _'·.

. s

_' .. ·.· . .• 10 ·.·.·• .. 20 · .. Xl

m' ·.

.

• . . .· ! ' • •• ' . 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 psi g. Plot the gas rate in MMscf/day vs the well head pressure.

I.

' WHP _..·

I

Gas rate· psig MMscf/day . 200 400 600 800 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 Gas rate

inch

.. <

MMscf/day 1.99S

2.441 2.992 3.9S8

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

soo

Abandonment Reservoir Pressure Psig

Save the PROSPER file as P-Ol. out

r . _ . _ . . . .__._._._. . . _. . . _. ________ _._. . . _.._._ ____________________ __

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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

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

. ·

· Description · _'C·. · ... Value. Units

Separator pressure 500 psig Separator Temperature 80 F Separator GOR 6943 scf/Stb separator gas gravity 0.81

Tank GOR 120 scf/stb Tank gas gravity 0.96

Condensate density API 50.5

WGR (condensed vaporized water)

Water salinity 10000 ppm

C02 0.5 %

N2 0.8 %

H2S 0 %

Dew point pressure 4870 psig Reservoir temperature 274 F Reservoir pressure 6495 psig

Deviation survey

Vertical well down to 15000

ft .

-,:-Description . · ...•. 1 . Measure depth · .. · .. ·· Tubing/Casing ID · ..

I . ·.-

Roughness

I ._. •.. . ft •. · .

<

•-··· ·• inch • • • .. ·

.

· .. _inch Xmas tree 0

---

--Tubing 3000 2.992 0.0006 Restriction 2.441 Tubing 14500 2.992 0.0006 Casing 15000 6.366 0.0006 www.ifm-solutions.com Page 34/62 . ·. © IFM-Solutions

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Geothermal gradient

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 Questions ··Values -6495 274 6944 2 17 120 100 31.6 0.354 120 100 11 25 1

1. For a well head pressure of 1500 psig, estimate:

·:c..·.·· . . _Variables .·. _Value

Gas flow rate

.31,G1Z

Flowing bottom hole pressure

Well head temperature _2..07-

_.-:":13

·.

2. 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

·.·. .· Units psig "F Scf/stb Stb/MMScf md

ft

Acres (Dietz shape) ft

ft

days % % Units MMscf/day psig "F

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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 Value GOR 170 Oil density 28 Gas gravity 0.72 Water salinity 1000 Deviation survey

Vertical well down to 1700 m

Units

scf/stb API ppm

Type Measure depth Tubing ID TubingOD CasingiD

m inch inch inch Xmas tree 0

Tubing 1600 2.441 2.875 6.36 Casing 1700 6.36 Note: Top of Perforations at 1700 m

Measure depth Temperature

m •F

0 80

1700 152 Overall heat transfer coefficient: 8 Btu/h/ft2/F

r . _ _ . . . _ . _ . . _ _ . . . . . _ _ . _ . . . . . _ _ . _ . . _ . _ _ . . . . . _ . _ . . _ . _ _ . . _ . . . . . _ _ . _ . _ . . _ __

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Reservoir data

Description Value

Reservoir Pressure 1630 psig Reservoir Temperature 152 "F

Water cut 55 %

GOR 170 scf/stb Permeability 250 md Net thickness 6 m Drainage Area 100 acres

Dietz Shape factor

c.:

31

Wei/bore radius 0.354 ft

Skin 0

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 Model Pump selected

I

Description Model Units Number of stages

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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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 Units

GOR 500 scf/stb Oil density 32 API Gas gravity 0.65 Water salinity 75000 ppm r System Equipment r Deviation survey

Vertical well down to 2400 m

r Down-hole equipment

Type Measure depth Tubing/Casing ID Roughness

m

inch inch Xmas tree 0 Tubing 2200 2.99 0.0006 Casing 2400 6.36 0.0006

r

Note: Packer depth 2200 m

r

Measure depth Temperature

m "F

0 70

2400 165 Overall heat transfer coefficient: 8 Btu/h/ft2/F

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Reservoir data

Description Value Units

Reservoir Pressure 2900 psig Reservoir Temperature 165

'F

Water cut 70 %

GOR 500 scf/stb Permeability 80 md Net Thickness 15 m Drainage area 100 acres Dietz Shape factor

c.:

31

Wellbore radius 0.354 ft Skin 0

Gas lift data

Parameter Value Units

Gas lift gas gravity 0.65

Available gas 20 MMsd/day Well head pressure 200 psig

Gas lift Casing pressure 1500 psig

~P valves 100 psi Packer depth 2200 m Water cut 70 %

Minimum spacing between valves 100 m Valve type CAMCO R-20 Normal Completion fluid gradient 0.43 psi/ft

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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

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 Oil production

% Injection rate rate MMscf/day Stb/day 70 80 90

Performance curve

1000 900 800 700 600

soo

400 300 200 100 0 0 2 4 6 8

10

12

14

16

18

Gas lift gas lnjeetion rate MMscf/day

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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

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

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:

Woll3

-.

_··., ···,X>.

·-.

Woll2 -'

-.

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

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( 3. 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. Enter the pipeline information

/

Pipe ' -

-

-_

- WHlto

·----_

WH2to - WH3to Manifold to

__ - -_-

...

_-- _---- _-- _---·

_-.

.-___ - -- _{- Manifold} _Manifold _mar\ifpld sepjoint

-Length km 3

2.5

4 40 Inside diameter inches 6 6 6 11

Roughness inches 0.0006 0.0006 0.0006 0.0006 Correlation Beggs and Beggs and Beggs and Beggs and

Brill Brill Brill Brill Outside Temp "F 70 70 70 70

Overall heat Transfer coef. BTU/h/F/ft' 3 3 3 3

Note: Assume a flat terrain for all the pipelines

Save the GAP file as

G-Ol.gap

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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 .} .··

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 . · .

Gas production ... ·

rateMMsd/day

What is the difference between point 1 and point 3?

Separator ..

. _Separator

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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.

5.

6.

1

Separator pres.sure Separator Gas l)roduction rate . ,

·.··. ·· psig . .· I·· · .· ·. MMscf/day · · ..

1000

800

600

400

200

100

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 check how GAP honours this constraint.

Which well is GAP chocking back? Why?

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

Save the GAP file as G-02.gap

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Tutorial G-03: Integrated Production Model - Production forecast

Objectives:

Familiarize the user on how to perform production forecasts Perform different prediction scenarios saving the results

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.

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:

- - - .Separator. Weill ·_

----

weu.z

-- _ -• .. Well 3 _

--Cumulative gas --_

production 8scft2""1

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.

iv.

Perform a prediction optimizing to check if the field is able to produce the target rate for mentioned period without additional investments.

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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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

The pipeline is an 8 inches ID and the separator in the platform is operating at 400 psig.

The reservoir is modelled in MBAL and the file has been created by the reservoir engineer and is 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 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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IFM Solutions IPM Training Course

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Integrated production modelling

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An Introduction to PROSPER, MBAL and GAP

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Table of Contents

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IPM training course introduction

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The concept of IPM

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The IPM modelling platform

GAP,

PROSPER,

MBAL,

PVTP,

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PROSPER

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MBAL

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Introduction and scope of work

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Tutorial M-01: Performing the history matching in MBAL for a gas reservoir

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