ifm solutions ipm training course
TRANSCRIPT
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PM Training
ourse
Integrated production modelling
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VIII>C:IdadU.-..
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t - _ . ~ ~ - -
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An
Introduction
to PROSPER MBAL and GAP
Oifmsolutions
..._ .. INTEGRATED
FIELD
MODELING
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N T E G R / ~ o T E D
FIELD MODELING
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IPM Training Manual
opyright notice
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, electronical ly, mechanically, magnetic, opt ic
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.
t
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
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Edinburgh EH7 4HG
Scotland, UK
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HIJ. Josiluill
H l z ; ~
ft.
Fiscal de
Produccl on
V P A C F D R P
YPF
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( ~ I N T E G R T E D FIELD MODELING
IPM Training Manual
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Table of Contents
Table of Contents ...................................................................................................................................................................... 3
/PM training course introduc tion ...............................................................................................................................................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 reservo ir ........................................................................... 9
Tutorial
M-02: Perform
the
history matching in MBAL
for
an
oil
reservo ir .............................................................................10
Tutorial
M-03:
History matching in MBAL for
a
gas and condensate reservoi r .......................................................................12
Tutorial M-04: MBAL
oil
field
history
match ing and pred ictions ............................................................................................. 13
Tutorial
M-05:
Performing predictions in
MBAL
for a gas reservo ir ........................................................................................ 15
PROSPER ..................................................................................................................................................................................
16
Tutorial P-01: PROSPER introduction:._ constructing an ail well mode ...................................................................................17
Tuto rial P-02: Basic example gas
w ll
model cons truc tion ...................................................................................................... 20
Tutorial P-03:
PVT
Black oil ma tching far an oil well mode/ ....................................................................................................23
Tutorial P-04: Selecting and matching a mu tiphase flow correlation
for
an oil wel l model ................................................... 24
Tutorial P-05: Oil well model cal ibration review exercise ........................................................................................................ 27
Tutorial
P-06: Gas well model
perfo rmance analysis ............................................................................................................... 31
Tutorial P-07: Gas well modelling pe rformance Hydraulic frac turing ...................................................................................... 32
Tutor ia P-08: Gas and condensate wet model .......................................................................................................................
34
Tutorial P-09: Electrical submersible
pump
design ..................................................................................................................36
Tutorial P-10: Gas lift design ....................................................................................................................................................38
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 P roduction Model Production forecast .......................................................................................46
Tutorial
G-04: Integrated
model
for an Oil fiel d ...................................................................................................................... 47
Work shop ................................................................................................................................................................................48
Tutorial W-01:
Gas
fiel d 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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IPM training course introduction
Objectives
Learn how to use the software and develop skills
n
the use of
IPM
Basic understanding
of the
physics
Understanding
the
limitations
of methods
and techniques used
Agenda
Dayl
Day 2
Day
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
MB L Simulation
Fractional f low 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
(MBALPROSPER-GAP)
PVT
equation
of
state characterization
Tight gas well modelling
(PROSPER,
MBAL,
GAP)
ESP design
Gas
lif t 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.
ny 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
th t
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.
t
has
the following tools that are used
for
dif ferent 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 fol lowing sketch is drawn to explain how these tools interact with each other.
G P
PROSPER
MB L
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. t models the surface network internally. For modelling the
reservoirs
it uses
MBAL tool. For well modelling
GAP uses PROSPER
C ._._ _._..__._._. __. _.
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Introduction and scope
o
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
star t 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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MB L
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 product ion 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 IIP
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 matchingof a
gas
reservoir mater ial 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 permeabi lity 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 . ;_ ___
_-- ' Value
-; -_.--.-
I
Units ._,
.
---
Oil initial in place
MMstb
Gas initia l in place
Bscf
Actual oil recovery factor
Active aquifer exist
Yes/No
Is
there an initial gas cap? Yes/No
Main drive mechanism
ection : Production forecast
The field is currently producing with only one well, called Well-1. The productiv ity 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 unt il 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 n 2025
nd
the oil proved developed reserves
What would you da to improve
the
recovery factor?
Quantify your suggestions using MBAL.
ave this tutorial
as
M-04.mbi
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IPM Training Manual
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
s
negotiating a better
gas
price; however t
is
necessary to provide at least
40 MMscf/day of
gas
untillQZO.
The question
th t
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 .
.
&.:
: : ~ ~ ~ ~ ~ ~ : : : ~ ~ ~ ; : : : : : : : : : : : : : : ; : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : : :
. t ~ ~ . ~ ~ / ' : f I M e . J .
7
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PROSP R
Methodology
Through exercises the engineer wi ll 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 u t o r i a l s have been design to learn how to
1. Construct models
PVT
input data, selecting and matching a black oil correlat ion
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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FIELD MODELING
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IPM Training Manual
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
Deviation Survey
.
.
.
.
. ..
.
...
..
True vertical
Unit
Scf/stb
API
ppm
1
Geothermal :
gradient .
e a s u r ~ ~
..
. Temperature .
I
depth :
L dE pth ..
. "F
..
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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/ft
2
/F
U Overall he t 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
ack
of
well head temperature the following rule
of
humb can
be
used:
Oil
and water wells :
Condensate wells:
Dry and wet gas wells:
8
10
Btu/h/Jf F
7
Btu/h/Jf
F
1 3
Btu/h/Jf
~
~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~
IPRdata
>
Variable
...
Value.
. . llif
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
PROSP R
file
s
P Ol.out
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Tutorial P 02: Basic example gas w ll 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
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r
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
Compo ent
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
16
30
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Down-hole equipment data
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/ft
2
/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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Tutorial P 03: PVT Black oil matching for an oil well model
This tutoria l
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
gr vity
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 t o i l
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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.
bjectives
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
O .
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
,
e v i ~ t i o n
survey
,,.,
Geothermal ,
'
' . ' , , , , ,
/F
IPRdata
Variable
-
._ Value
-
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r
I
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r
r
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 multiphase 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
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
t
which water cut the well will
not be able to flow naturally.
I Variable
Value
units
I
ater cut
Save this tuto rial s P-04.aut
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INTEGRATED FIELD MODELING
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Training Manual
Tutorial P 05: Oil well model calibration review exercise
This exercise was design
to
review
the
well model calibration procedure.
There is PVT
d t
from the lab
th t
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 li t curves for numerical simulators
Well matching procedure
a
PVT
matching
1. PVT Input data Enter basic pvt data solution GOR oi l 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
correlationfrom the drop down menu.
b Select nd 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. I f
the test point lies between both correlations, select several
correlations to compare with the test point.
4. Match VLP I Select only 1 correlat ion I Match
i.
Check
on correction parameters
P
;;1 gravity term multiplier)P
2
;;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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Data
PVTdata
Variable
.
.
.
Value
.
Unit
..
Solution GOR
Oil
density
Gas gravity
Water salinity
PVT
lab
data:
Pressure
p ~ i
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
s
Rb/stb
:
Geother111al
.
' gradient
_
,
Temperature
..
'
."F
. ;
.
.
50
313
.
::
: ,
_
: _ t .
,
.. 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/ft
2
/F
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r
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
Paramete r 1
Paramete r 2
2. Using
the
well test
data
determine:
Variable
.Value
Units .
Flowing bottom hole pressure
psig
Ll p
friction
psi
Ll p
gravity
psi
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r INTEGRATED FIELD MODELING
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rosion
In
PROSPER
there are 2 equations to calculate the erosional velocity
AP114E
It
is
used for fluids free o solids/sand production
C o n o c o ~ P h i l i p s
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 equat ion, 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 s imulator 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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Tutorial P 06: Gas well model performance analysis
This tutorial start from the
gas
well model created in tutorial P-02.
bjectives
Analyze th performance of a gas well model
Evaluate th operating condition and liquid loading probability
Perform sensitivity analysis
to
optimize
th gas
production
Using the well
model
cre ted
in
Tutorial P-02 PROSP R file P-02.out ev lu te 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 th VLP/IPR intersection, what can we
say
about
th
stability
of
th solution? Is
it
stable
or unstable solution?).
3. In th flowing bottom hole pressure, What are th contributions of well head pressure,
friction losses and pressure drop due to gravity?
. .
ariable
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 th fluid velocity and critical velocity Turner velocity) versus depth
for
th question 1.
What can you say about the liquid loading probability
of
this well?
6. Evaluate th effect
of
installing compressors. Plot
th Gas
rate
of
this well versus well head
pressure.
Save the
PROSP R
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
tart 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
4
FCD
10
X
(Fracture half length )
30
m
Fracture height Reservoir
thickness
Time since production start
1
days
FCD: Dimensionless
fracture conductivity
t
is
the relationship between the transfer capacity
o
luids
o
the fracture and the
capacityo the reservoir to deliver
fluids
into the fracture
K1 : Fracture capacity
b f Fracture
idth
K : Reservoirpermeability
XL Fracture
half
/enght
.
Variable
as rate
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Value . .
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 .
.
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
Tutor ial M-Q3.
M-D3.mbi)
The eill icon should be associated
to
the
file created in the Tutorial
P ~ 0 8 P ~ O B . o u t )
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
w w w i f m ~ s o l u t i o n s c o m
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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
eparator pressure
of 1
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 eparator pressureo 1 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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r
,.
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:
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IPM Training Manual
4. Evaluate the installation
of
compressors at
the
plant {Separator location),
for that
perform a
sensit ivity 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 5 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 limi ted 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 th GAP file as G 02.gap
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/PM Training Manual
Tutorial G-03: Integrated Production odel - 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
d te
entered in the production
history of the tank until 01/01/2025 with 1 month time
step size.
Perform a production forecast using a sep r tor pressure of 1000 psig with all wells fully open.
Check the results such as gas production rate profiles
t
the separa tor, 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
th t
you might have
to
evaluate different alternatives.
i.
. Set up the constraint
t the
sep r tor level
ii. Set
all the
w ll
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 t the plant (Separator location), specify compressors
installation timing and inlet pressure.
2./nstalling compressors
t 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 th
G P
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.
85ft
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 folderAuxJiles\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
product ion 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
t
is possible to dril l 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?
r
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Workshop
Tutorial W 01:
Gas
field integrated model
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:
Gl:62 m
..
135 m1 :1 indl
41 m 1 :1 inch
12 m1 :1 inch
Well1
8
r
GL:
62 m
GL: 605m
The delivery point pressure
is
70 kg/cm
2
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( INTEGRATED FIELD MODELING
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PVTdata
. Parameters .
.
Value
_:_
Units
r
Specific gas gravity 0.71
Separator pressure
1000
Psig
CGR (Condensate to
gas
ratio)
7
Stb/MMscf
Oil density 42
API
Water salinity
70000 Ppm
H2S
0
C02
11
N2
1
r
Reservoir data
(
.
.
.
: Parameters
:
:feet .
......
0
0
13238 13238
16063 16053
19423 19393
19715 19678
Down-hole equipment
...
Measured
Tubing Tubing Casing
; Casing
depth
ID
roughness. ID
roughness
Type feet
inches
inches
inches
.
inches
Xmas Tree 0
Tubing 106 3.96 0.0006
Restriction
2 61
Tubing 14567 3.96 0.0006
Restriction
3.46
Tubing
14600 3.96 0.0006
Casing 16463 6 36 0.0006
Geothermal gradient
Measure depth Formationtemperature
feef
O
0
59
16463 260
Overall heat transfer coefficient: 2 Btu/h/ft
2
/F
Inflow performance data
.
Parameter Value Units
.
Reservoir Model C and n
Reservoir Pressure
3060 1
(psiql
Reservoir Temperature 302
(deq F)
Water-Gas Ratio 0
(STB MMscf)
Condensate Gas Ratio 8 3
(STB/MMscf)
I
.
.
IPRmodeldata .
c
I
0.009 (Mscfiday/psi2)
n
I
1
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Well3
Deviation survey
Measure depth rue vertical depth
..
.feet
.. .
I
.
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
. . .
. Mea.sured .Tubing
Tubing
Casing
.
I .
depth,...
.
JD. roughness
.10 - .
.
Type
feet
inches
inches
inches
Xmas Tree 0
TubinQ
105
3.96
0.0006
Restriction
3.81
TubinQ
17038 3.96 0.0006
TubinQ 17048 2.99 0.0006
Restriction 2.75
Tubing
17111 2.99 0.0006
Restriction
2.2
Tubing
17144 2.99 0.0006
Casing 17270
6.46
Geothermal gradient
Measure depth
.F:olll ation temperature ...
.. feel
.
. . .
-
0 59
17270
302
Overall heat transfer coefficient: 2 Btu/h/ft F
Inflow performance data
Parameter
Value
Units
Reservoir Model C and n
Reservoir Pressure 3073.16
psiQ)
Reservoir
Temperature 302
(deq F)
Water-Gas Ratio 0 (STB/MMscf)
Condensate Gas
Ratio 8.23 (STBIMMscf)
Casing
roughness
inches
0.0006
c
0.3749 (Mscf/davlosi2)
n
0.71848
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Questions
Is it possible to achieve the proposed contract? What actions should be considered?
"
.
"
"
.
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INTEGRATED FIELD MODELING
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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:
Parameter
Value
Units
'
Reservoir depth
12320
feet
Reservoir Temperature 230
O
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 PI
Water salinity
100000
ppm
H
5
0
co 6
N
0.5
Evaluate
if
i t 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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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 platfo rm contains dedicated export oil and gas flow-lines going to
the
shore.
Using the data provided be low 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 fi nd all
the
data available:
45F
20km
14800 feet
13700feet
.
Data
Reservoir 1
.Reservoir 2 Uni ts.
OOIP 160 70 MMstb
Pressure 6600 10200 psig
GOR 470 1450 scf/stb
API
36
41
Gas
gravity
0.68 0.72
Reservoir depth 13700 14800
TVDSS
(feet)
Permeability
52
420
rnd
Net thickness 22 45 feet
Porosity 0.19 0.23 fraction
Connate
water
saturation 0.23
0.15 fraction
Water salinity 87000
12000
ppm
Reservoir Temperature 197 240
F
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r ~ I N T E G R T E D FIElD MODELING
IPM Training Manual
Relative permeability curve Corey function table
Phase.
Residual End Point Corey Exponent
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