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Joint Industry Project
“Added value from Intelligent Well &
Field systems Technology (IWFsT)”
Review 2011/13
David Davies & Khafiz Muradov
Intelligent Fields:
Why Do We Need Intelligence?
Accelerate Production Buildup
Reduce Well Count & Extend Plateau
Reduce Well Intervention frequency
Improve production monitoring and control
Improve safety and project economics
Advance
production
Q0il
(bpd)
Increase
plateau rateMaintain and
extend plateau
t (years)
Enhance post-
plateau production
Field Production Profile with Added Value:
History &Technology: of the IWFsT Project
• Completions providing a well with real-time, zonal production control
and monitoring (Intelligent Well Technology) began in 1994.
• HWU’s own R & D involvement started in 1998
• This project began in 2001 to meet industry demands for analysis of
the technology’s feasibility, reliability, application envelope & risks.
• The initial (2004) deliverables included an I-Technology evaluation
methodology, including the role of reliability plus several case studies.
• The 2nd phase (to 2010) developed tools for evaluating active &
passive advanced completions, began Intelligent Well monitoring research
& the integration of Intelligent Wells into Intelligent Fields.
• The current phase, started in 2011, concentrated on developing
optimisation methodologies for I-field design & control assisted by
improved monitoring techniques, plus a number of case studies.
• The 2014-2016 extension of the JIP proposes to explore new,
downhole flow control technologies screened for different reservoir
types, develop comprehensive, closed-loop, I-field control procedures
using advanced downhole, soft, multi-phase flow metering.
The 2013 IWFsT JIP Sponsors
IWFsT JIP
Project History & Achievements 2011-2013
The early Project History & Achievements (for 2004-2010) are available on request
Project Evolution (2008-2013) The IWFsT project is steered by the sponsors, continuously evolving by
responding to research leads, technology developments & sponsor insights
Three projects begun 2008-2010 were completed during 2011-2013
# Title Description Deliverales
A Added value of Uncertainty Minimisation
Evaluate the “Increased Added Value” of IWFsT by reducing the production uncertainty
Guidelines, Techniques & Workflow
B IWFsT & Water Injection Management Develop integrated waterflood management Guidelines & New Technique
C Online optimisation of Intelligent Well &
Field Systems
Develop an online optimiser based on model update
via a feedback decision loop for optimising njection
Online Controller & Optimiser
Well Liquid Rate Constraint: IW completion reduces oil and water
production uncertainties
Both Dynamic & Static Uncertainty
IW reduces reservoir heterogeneity &
Uncertainty
Well Pressure Constraint: IW completion reduces oil & water
production uncertainties
Increased pressure drop in IW completion
reduces oil production
Effective Control Strategy required (see
WCcritical-based reactive control studies:
Project 12)
IPR curves
0
50
100
150
200
250
0 5000 10000 15000 20000 25000
Production rate, sm3
Pre
ss
ure
, b
ar
Conventional Well
(Prosper)
ICV 3.5 in
ICV 4.5 in
Conventional
Horizontal Well
(Eclipse)
ICV 4.5 in Ecipse
Oil Rate of
Conventional Well
at WC=25% and
GOR=210 sm3/sm3
Eclipse liquid
production at
the first
timestep
Project A: Added IWFsT Value by
Minimising Uncertainty
Deliverables: Problem Analysis, Uncertainty
minimization, case studies, publications & thesis
Project B:
Water Injection Management
• Common techniques of
monitoring waterflooding
reviewed
• Type curves developed to
control total injection rate of
water in to the reservoirs
Waterflooding monitoring and management: Approaches investigated
Pressure management
Allocation management
• Techniques used to quantify
inter-well connectivity studies.
• New techniques introduced
to determine water allocation
factors
Pav=const
Q1->2
Qi->p
Images from Journal of Petroleum Science and Engineering 69 (2009) 227–238
Deliverables: Methods for improving performance of water flooding in order to:
• Maintain reservoir pressure
• Delay water breakthrough
• Enhance hydrocarbon recovery
• Decrease water production
Results summarised in a thesis
Production for a
period
Give initial ICV
settingsCurrent model
parameter
Step response
model
Optimisor
Measured
pressure, liquid
flow rate and water
cut data at every
sampling time
(seconds)
Waiting for
1 time
step
Optimum decision
variables series for
one predictive period
Do the first optimum value
equal to the current decision
variables value?
Keep current
valves setting
GPC controller
New valves setting
to achieve
optimum decision
variables
No
Yes
Database
Denoise
Updated Step
response model
Decision variables valuePiecewise step
response models
Step response model No.
Project C: Online for water injection allocation optimisation
0
0.5
1
1.5
Input: ∆u(t)
Output: ∆ y(t)
system
Reservoir response is
quantified and used to
predict the optimal
injection allocation:
Optimiser operating via a feedback decision
loop using Eclipse data for the response
model update and injection optimisation
Deliverables: Workflow developed & coded in Matlab suitable for liquid
constrained production & injection where reservoir shows linear behaviour
Project Evolution: New Projects started 2011-2013
Type # Project Description Deliverables
Pro
du
ction
Op
timisa
tion
1 IWFsT field design workflow Is the workflow for designing an IWFsT field different from a conventional field. Why?
What are the differences? Can the process be automated?
Guidelines &
workflow
2 Application of Genetic &
other Algorithms for control
of I-wells.
Identify the preferred stochastic production optimization method for both I-well & I-
field control
Test feasibility.
Workflow &
Guidelines
We
ll De
sig
n
3 Design an ideal device for
downhole flow control to
meet production optimization
Reconsider the available (JIP & other) approaches to choosing a particular device, its
location and control principles. Propose a methodology for choosing the best device or
group of devices that meets a particular well, field and/or production objective.
Guidelines
/Methodology
4 ICV/AICD design based on
predicted life-time
production
ICD/(A)ICD design is often carried out on a “snapshot” basis at one time in the well’s
lifetime. Apply dynamic design principles to ensure that long-term production
conditions & objectives are also met.
Workflow, Proof of
design feasibility,
guidelines, examples
5 I-Single-boreholes and I-
Multilaterals. Are they
different?
Are the JIP findings for single-bores applicable to multilaterals? What are the
differences? This includes: injectivity study between the laterals; interference while
monitoring/clean-up; loss or gain of control flexibility
Comparative results
supported by example
studies.
Pro
du
ctio
n
Mo
nito
ring
6 Develop Temperature
Transient Analysis (TTA)
Further development of the TTA and its application guidelines for horizontals/verticals
gas/oil producers/injectors.
TTA methodology &
Examples
7 Advanced methods for
interpretation of downhole
data from multiple
measurement devices
Analysis of data from multiple measurement devices is a wide area. Application to the I-
well/field measurement and control system is promising. Manipulation of ICVs to
increase the information content of the data is included here.
Methodology;
Examples of the
application
8 Interference of I-well design
and control strategies with
production network
Investigate how changes in the production network (i.e. an existing/newly installed
pump/gas lift/separator/another well tie-back) can cause the I-well control strategy to
become unstable. Investigate design principles & benefits.
Research results
9 “Value of IWFsT, a 2nd look” Re-evaluate the “Value of Flexibility offered by IWFsT” using Real Options Rejected by sponsors
10 Heavy Oil production with
IWFsT
Develop design methodology for a heavy oil ,I-Well completion with artificial lift
designed to mitigate water fingering with an ICD completed horizontal well.
Methodology &
Examples
Ad
ditio
nal
11 Workover scheduling Methodology for proactive workover scheduling Case study – N2-field
12 WCcrit based reactive control Methodology for fast and robust, reactive ICV control and ON/OFF application area Thesis, publications
13 N-field case study Test well completion design and control methodologies: both reactive and proactive Results
14 DTS feasibility Forecast DTS response to water influx for a heavy-oil producing, advanced well Results
15 ICS comparison and design Compare Inflow Control Systems (ICS). Suggest (A)ICD design methodology Methodology. Thesis
20
25
30
35
40
5 10 15 20 25
Op
en
ing
TSP
Closing TSP
K1_50_K2_500Phi25Trans0.0
K1_50_K2_500Phi25Trans0.1
K150_K2_500Phi25Trans0.2
K1_50_K2_500Phi25Trans0.3
K1_50_K2_500Phi25Trans0.5
K1_50_K2_500Phi25Trans0.7
Achievements:
Well Placement
Production String Design
(ICDs)
Optimise the Control
Strategy
ICV
Optimum strategy becomes more
critical as transmissibility increases.
Best Conventional Well Trajectory
can be the best I-well trajectory
0
100
200
300
400
500
0 10 20 30 40 50
ICV
Are
a (m
m2
)
Time Step
Loop complete for
Synthetic Model
Developed procedure is being tested with a real field model
Deliverables by December 2013: extra project 11and:
• Step-by-Step workflow
• Guidelines for optimisation setup
• Comparison with the conclusions from the synthetic model
Project 1: I-Field Design Workflow &
Project 2: Application of Genetic & other
Algorithms for control of I-wells
Slow
Loop
Project 2: Application of Genetic &
other Algorithms for I-well control
Reacti
ve C
ontr
ol
Pro
acti
ve
Opti
mis
ati
on
Validating
Decisions (Uncertainties)
Data
Processing
Pro
acti
ve
Contr
ol
Fast
Loop Deliverables: New algorithm for proactive
optimisation
Guidelines for limiting the
proactive, optimisation to
essential periods only
Workflow to define optimum
control frequency
Guidelines for modifying
available tools for proactive
optimisation
Problems: o Large number of variables
o Large, full-field model
Progress
I-Well
Slow loop activated ONLY when needed
Control frequency of the slow loop
Project 3: Customise Design of Downhole Flow Control Devices for Production Optimization
Sta
nd
ard
Des
ign
Cu
stom
ised
Desig
n
ICV or ICD?
Optimal Zonal Pressures for I-injector Requires this performance:
Using a 6 position ICV
with this trim design
Deliverables: PUNQ study showed that knowledge of optimal rate or FBHP required
to make the optimum design. A comprehensive, unified design is part of Projects 1 & 2.
Ideal performance
of the best device?
Example: I-injector’s design, PUNQ field, WAG injection
• Optimising life-time production
delivers significant improvements
• Chosen economic model is the
critical factor.
Deliverables planned late 2013:
Work flow
Optimisation Guidelines
Economic parameter sensitivity
ICD/AICD/ICV recovery comparison
Project 4: ICV/ICD/AICD Design
based on Life-time Production
Achievements:
ICD
AICD
ICV
Project 6: Further Development of
Temperature Transient Analysis
T & P zone-by-zone analysis workflow developed
1.E+02
1.E+03
1.E+04
1.E+05
1.E+06
1.E+07
1.0E-03
1.0E-02
1.0E-01
1.0E+00
1.0E+01
1.0E+02
1000 10000 100000
d(B
HP
i-B
HP
)/d
ln(e
lap
se
d tim
e),
ba
r /
ln(s
)
dB
HT
/dln
(ela
ps
ed
tim
e),
K / ln
(s)
elapsed time, s
zonal temperature derivative over logarithm of elapsed time
zonal pressure derivative over logarithm of elapsed time
1/2 slope
0 slope
T & P transient interpretation methods being developed
-0.2
-0.18
-0.16
-0.14
-0.12
-0.1
-0.08
-0.06
-0.04
-0.02
0
0 5000 10000 15000 20000 25000 30000
time from the beginning of drawdown, sec
tem
pera
ture
ch
an
ge,
K
toe zone temperature change
straight trend line
Linear flow regime
ETR
Deliverables: Methodology
developed &
tested
SPE 164868: Some Case Studies of Temperature and Pressure Transient Analysis in Horizontal, Multi-zone, Intelligent Wells
Project 7: Advanced Methods of Downhole Data
Interpretation from Multiple Measurement Devices
Multi-zone I-well
File: Case-Three Zone-Oil-Incomplete Wellbore.tpl
PT [psia] (Zone-2) "Pressure"gfedcb PT [psia] (Zone-1) "Pressure"gfedcb PT [psia] (Zone-3) "Pressure"gfedcb
Time [s]600,000500,000400,000300,000200,000100,0000
ps
ia
5800
5750
5700
5650
5600
5550
5500
5450
5400
5350
5300
5250
5200
5150
File: Case-Three Zone-Oil-Incomplete Wellbore.tpl
TM [F] (TUBING.PIPE-1.10) "Fluid temperature"gfedcb TM [F] (ANNULUS.PIPE-1.10) "Fluid temperature"gfedcb TM [F] (ANNULUS.PIPE-2.10) "Fluid temperature"gfedcb
Time [d]76.565.554.543.532.521.510.50
F
212
210
208
206
204
202
200
198
196
194
P Data
Temperature Measurement
(steady state & transient)
Pressure Measurement
(steady state & transient) Data analysis using all
available measurements Objective:- Maximise
Information content for a
minimum measurement effort
• “Deliberately disturbed well
tests”
1
2 3
DTS data from multi-
zone measured during
I-well multi-rate tests
T Data
8900
9100
9300
9500
9700
9900
175 185 195 205 215
Temperature, F
MD
, ft
Twellbore
Tgeothermal
Twellbore 6000
Twellbore 8000
Twellbore 6000 (2)
Deliverables: Workflow & examples for “Minimum measurement effort”
monitoring during multi-rate flow tests using either ICVs or wellhead choke
Interaction between ESP Artificial lift & Downhole Flow Control Devices
Requires proper design, operation & ability to adapt to changing
production conditions
courtesy of Welldynamics
ESP Performance Plot
Operating
Point
Project 8: Interference of I-well & ESP
Production Control Strategies
Deliverables: Two ESP-ICV/ICD/AICD design methods
proposed, tested, reported & published (see also Project 10)
courtesy of Weatherford
Project 10: Heavy Oil production
with IWFsT & ESP
Deliverables: Snap-shot design
completed
During 2013 1. Dynamic modelling
2. Effect of gravel
pack
Pilot study: Heavy-oil production with an AICD completion:
“Snap-shot” performance of Integrated completion modelled
AWC simulation results ESP selection routine
ESP-AICD design A ESP-AICD design B
0.90
0.91
0.92
0.93
0.94
0.95
0.96
0 50 100 150 200
No
rma
lise
d T
ota
l Oil
Pro
du
ced
Iteration No.
Optimal Case Evolution
Extra Project 11: Optimum workover schedule for wells in a sector of a real field
GA for proactive workover scheduling (4 wells, total 12 zones)
Performance Comparison
Deliverables: Workflow &
MEPO add-on for proactive,
work-over scheduling
2% recovery increase
by choosing
optimum schedule
nn
i
N
ni
iBHP
ndPJ
WCJP
WC
)1(
1
-40
-30
-20
-10
0
10
20
01/10/2018 13/02/2020 27/06/2021 09/11/2022
ICV
3 P
osi
tio
n
Cri
tica
l W
ate
r C
ut-
Cu
rre
nt
Wat
er
Cu
t, %
Date
Well1, ICV3 control criteria
WC Difference ICV Position
Open
Closed
Valve Open Zonal WC higher than Critical WC
Zonal WC less than Critical WC Valve Closed
1500
2000
2500
3000
3500
4000
4500
5000
1 6 11
Oil
Pro
du
ctio
n, S
TB/d
ay
Choke Position
Qoil vs Choke Position
10
20
30
40
50
60
70
80
90
100
0
WCT WCT WCT WCT WCT WCT WCT WCT WCT WCT WCT WCT WCT WCT WCT WCT WCT WCT WCT WCT WCT WCT
Extra Project 12: The Critical Water-Cut concept:
Application Area of ON/OFF ICV Reactive Control
Deliverables: CWC concept
systematically analysed + tested using
several synthetic & real field models.
On/Off valves optimal in 90% cases:
- For reactive control of vertical
wells with fixed THP only
- No gas inflow
- Not for viscous oil
Optimum valve position found based
on the zonal, Critical Water Cut (CWC
criterion):
Extra Project 13: Real-field case study combining
reactive & proactive production optimisation methods
-50
0
50
100
150
200
250
2014
2019
2025
2030
2036
2041
NPV
Dif
fere
nce,
MM
$
Date
Difference in NPV wrt basecase for I-Well non-optimised
Difference in NPV wrt basecase for I-Well optimised
A large, real-field model used as a production optimisation test-bed for:
1. Several proactive well control methods &
2. CWC reactive control (CWC is fast, robust without the convergence
problems often experienced by commercial optimisation simulators)
First Level:
• Genetic Algorithm optimisation
• Zonal control by optimising ICVs
Second Level:
• Eclipse well prioritization option
• Control production from all wells with a
total oil production rate constraint
Deliverables: Real-field control studies by developing & testing:
1. Reactive Control (commercial optimisers & CWC)
2. Proactive Control (optimal control, GA).
DTS response to zonal water break-through in a long horizontal
well has been evaluated using the HWU simulator
Early production Temperature profile
(clear water influx signature observed)
Late production Temperature profile
(T-profile should be smoothed)
Extra Project 14: Evaluate the application of DTS
in an AICD-equipped, heavy oil production well
Deliverables: DTS system’s long-term resolution
requirement defined by this real well feasibility study
Extra Project 15: Comparison &
Design of Inflow Control Systems (ICS)
Aspect
ICD vs.
cased
hole
ICD vs.
ICV
AICD vs.
ICV
Uncertainty in Reservoir Description ICD ICV AICD
More Flexible Development ICD ICV ICV
Length of Control Interval ICD ICD AICD
Tubing Size = ICD AICD
Value of Information = ICV ICV
Control of Lateral = ICV ICV
Control within Lateral ICD ICD AICD
Commingled Production ICD ICV ICV
Long Term Equipment Reliability Conv ICD ICV
High Formation Permeability ICD ICD =
Mid-to-Low Formation Perm. ICD ICV =
Aspect
ICD vs.
cased
hole
ICD vs.
ICV
AICD vs.
ICV
Modelling Tool Availability Conv ICV ICV
Reservoir Isolation Barrier = ICV ICV
Acidizing / Scale Treatment ICD ICV ICV
Improved Well Clean-Up ICD ICV ICV
Equipment Cost ICD ICD AICD
Installation Complexity ICD ICD AICD
Installation Risk Conv ICD AICD
Installation Time ICD ICD AICD
In-situ Gas Lift Conv ICV ICV
Gas
Fields
Gas Inflow Equalisation ICD ICD AICD
Water Production Control Conv ICV AICD
Comprehensive review & comparison of Inflow Control Systems:
Nodal analysis based ICD & AICD design & sizing workflow developed & tested
Deliverables: Comprehensive comparison of ICS & optimum (A)ICD design.
Conference papers:
1. IPTC-15215 Use of Distributed Temperature for Zonal Flow Rate and Pressure Estimation, IPTC 2011, Bangkok
2. Temperature Monitoring and Interpretation in Intelligent Wells, 3rd International Oil Production Intensification Conference, Jul 2011, Tomsk, Russia
Scientific papers:
1. Application of inflow control devices to heterogeneous reservoirs – JPSE published Volume 78, Issue 2, August 2011, pp 534-541
2. SPE 131642 - Novel Analytical Methods of Temperature Interpretation in Horizontal Wells- SPE Journal, Vol. 16, No. 3, September 2011, pp 637-647
IWFsT JIP Achievements (2011-2013) Publications 2011
Conference papers:
1. SPE 150138 - Temperature Transient Analysis in a Horizontal, Multi-zone, Intelligent Well; SPE Intelligent Energy, March 2012
2. SPE 150195 - Review, Analysis and Comparison of Intelligent Well Downhole Monitoring Systems, SPE Intelligent Energy, March 2012
3. SPE 154472 - A Novel Optimisation Algorithm for Inflow Control Valve Management; SPE EUROPEC, June 2012
4. Review, Analysis and Comparison of Intelligent Well Downhole Monitoring Systems, SPE JPT, pp 75-79, September 2012
Scientific papers: 1. Linear Non-adiabatic Flow of an Incompressible Fluid in a Porous Layer –
Review, Adaptation and Analysis of the Available Temperature Models and Solutions; J. of Petroleum Science and Engineering
2. Early-time Asymptotic, Analytical Temperature Solution for Linear Non-adiabatic Flow of a Slightly Compressible Fluid in a Porous Layer; Transport in Porous Media
3. Temperature Transient Analysis Application Workflow, Problems and Advantages; Journal of Petroleum Science and Engineering
IWFsT JIP Achievements (2011-2013) Publications 2012
Conference papers: 1. SPE 164868 - Some Case Studies of Temperature and
Pressure Transient Analysis in Horizontal, Multi-zone, Intelligent Wells, SPE Europec, June 2013
2. SPE 166603 - Role of Artificial Lift in Wells With Downhole, Flow Control Completion, SPE Offshore Europe, Sep 2013
3. Field management by proactive optimisation of Intelligent wells – a practical approach submitted to Intelligent Energy, Dubai, Oct 2013
Theses: 1. “A Comprehensive Approach to the Design of Advanced Well
Completions” by Faisal Al-Khelaiwi
2. “Intelligent Well Transient Temperature Signal Reconstruction” by Manoel Feliciano da Silva Junior
3. 2 further theses expected during 2013
IWFsT JIP Achievements (2011-2013) Publications 2013
Research, Design & Value Demonstration of
many aspects of Advanced Completions has
been done using Sponsor’s Real Field Models
Field Case Studies:
a) S Field
b) NH Field
c) BG Field
d) Ch Field
e) BP Field
f) H Field
g) N Field
h) N2 Field
i) E Field
j) C-gas-field
k) U-field
l) ...
Project Evolution The IWFsT project is steered by the sponsors, continuously evolving by
responding to research leads, technology developments & sponsor insights
Three projects started in 2008 were completed during 2011-2013
# Title Description Deliverales
A Added value of Uncertainty Minimisation
Evaluate the “Increased Added Value” of IWFsT by reducing the production uncertainty
Guidelines, Techniques & Workflow
B IWFsT & Water Injection Management Develop integrated waterflood management Guidelines & New Technique
C Online optimisation of Intelligent Well &
Field Systems
Develop an online optimiser based on model update
via a feedback decision loop for optimising njection
Online Controller & Optimiser
Projects finished by 2010
...contributed to the current projects
(2011-2013)
...and formed the basis for the
proposed 2014-2016 projects
1 Inflow Control System Comparison (ICV vs. ICD)
Inflow Control Systems Compared (ICV/ ICD/AICD)
• Reservoir types suitable for (A)ICD • I-well design for multilaterals
2 Advanced well modelling ...is the integral, ever developing part of all JIP studies: current and proposed
3 Automatic optimisation of ICV settings Results provide a the base case control scenario in reactive well control studies
4 Online Well Control Inspired the field controller (#1 below) -
5 Reconcile short-term optimisation & long-term management
Inspired the reactive vs. proactive control studies
• Multi-objective optimisation • Controls for different Reservoir types
6 Integrate downhole T & P data into well modelling
• Fundamental solution to extend the Pressure and Temperature Transient Analysis • Well modelling experience used in the Active Monitoring studies
7 Field case studies: H & SH Fields Modelling and analysis experience applied to E, N, N2, PUNQ, AINSA II models
Modelling experience to be applied to the case studies
8 Evaluate Clean-up techniques Experience with dynamic flow modelling
9 Value & application envelope of IWFsT I-well designs suited to Reservoir types
10 I-well value as a source of information Reconciled active monitoring &control