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1/15
EPT
delivering breakthrough solut ions
TGL GroupT
Group
Reservoir
Engineering
May 2010
8/12/2019 TGL Reservoir Engineering Eng
2/15
2TGroup
Petrophsical
evaluation (PP)
Structure (PS)
Static Model
Data
Integration
Production Data
Pressure Data
1000
1010
1020
1030
1040
1050
1060
1070
1080
1090
1100
4 0 00 5 0 0 0 6 0 0 0 7 0 0 0 8 0 0 0 9 0 00 1 0 0 00 1 1 0 0 0 1 2 0 0 0 1 3 00 0 1 4 0 0 0
F o rm t i o n r u r (K )
TVDSS
(m)
J -
J -
J -
J -
J -3
J -
J -7
J -
J -
C fr m l
Sep-90
July-97
Nov-96
Rja-1:Jan-88
Rja-4:Nov-90
Originalwater lin
Points legend:
Thepoints linedwithred:UG-1
Thepoints linedwithredandshadowed:UG-2
Thepoints linedwithblue:UG-3
OWC =1051.9 m
igure.
Completions
Available Data
Output
-
.7
.
.
.7.
.
.
.
.
.
.7
.
.
7.......7.
.7.......7.
.
RE Dynamic model
Input
PT: Well designWE
Surface engineering
One mapable
seismic horizon
Faults
x-trap analysis
QCed raw logs
calculated logs facies analysis
OWCs
Core
8 00 0 8 40 0 8 80 0 9 200 96 00 10 00 0 1 04 00 1 08 00 1 12 00 1 16 00 1 20 00 1 240 0
8 00 0 8 40 0 8 80 0 9 200 96 00 10 00 0 1 04 00 1 08 00 1 12 00 1 16 00 1 20 00 1 240 0
-2000
-1800
-1600
-1400
-1200
-2000
-1800
-1600
-1400
-12
00
TidalChannelSandShaleDiamectiteGLSand
FluvialSandGFSandSheetFloodSandGDSand
SandyDiamectiteMuddyDiamectiteGLMudALS-10H1
ALS-9H1ALS-8H1ALS-7H1ALS-6H1
ALS-5H1ALS-4H1ALS-3H1ALS-2H1
ALS-1H1
W-E F acies X-Section
Structural modelling
Stratigraphic framework
Facies modellingProperty modelling
Uncertainty management
Volumetrics
SWS
Dip meter data
AnaloguesExternal studies
Reservoir Engineering Workflow
8/12/2019 TGL Reservoir Engineering Eng
3/15
3TGroup
cores
logs
w
elldata
sedimentologypetrographyRCALSCAL
porosityoil saturationreservoir delineation
depositional units
reservoir quality distribution
geological trendscomputer mapping &
modelling
reservoir simulator
Reservoir characterization
geological modelling
seismicstructure topsvolumesFaultsmaps
Data Base,Paradigm
Software
8/12/2019 TGL Reservoir Engineering Eng
4/15
4TGroup
reserves
$/bbl
Modelling
Geological model
(static)
Reservoir Simulation
model (dynamic)
production
forecast
recompletions
new wells
optimisedwater flood
core analysis
log interpretation
structural modelling
property modelling
3D seismic
log correlation
reservoir subdivision
flow modelling
production history
SCAL
Fluid properties
Pressure data
Well test analysis
Petrel modules Eclipse
8/12/2019 TGL Reservoir Engineering Eng
5/15
5TGroup
declineanalysis
$/bbl
PPT Tools
Production optimization
Production Analyst
Block analysis
production
forecast
materialbalance
reporting
optimised
water flood
flow modelling
production history
Productionhistory,
Fluid properties
Pressure history
Well test analysis
OFM, Topaze MBal
8/12/2019 TGL Reservoir Engineering Eng
6/15
6TGroup
Candidate selection process
Capture and
characterize
opportunities
Capture and
characterize
opportunities
Study, screen
and filter out
unfeasible
opportunities
Plan and work
out executable
options
Approve
opportunities
for realization
Needed:
Tools
Standards
Planning
Work process
Identify promising areas
Pool of candidates
Data gathering
Initial block/well review
Initial candidate list
Mechanical assessment
Macro screening
from the candidates
pool (ranking tools)
Surveillance plan
(Pr & inclination)
Micro screening
(BA, MBAL,
FrontSim, Geol. &
dynamic modeling))
Final candidate list
proposal
Approve final
candidate list
Agreed program
signed off
Performance
review
Lessons learned
Surveillance execution
(feed micro screening)
Well approval
Execution program
Execution
Training
End of well report
Client reps.
Execute ST,
completion
Client reps. & TGL
Execution planning
Drilling
Completion
Optimization
Stimulation
TGL Group ClientTGL Group
8/12/2019 TGL Reservoir Engineering Eng
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7TGroup
Field life performance
Field performance analysis no water injection (depletion decline)
Water fill-up period (catching up on reservoir pressure and compensation)
Waterflood analysis in mature fields (after water break through) Buckley-Leverett, Welge
Waterflood life
Oilp
roductionrate
Injectionstart
Depletion Initial
fill-up
Secondary oil
Primary oil
5% 5-10% 15-30%0-10%
Production decline
period
Production
incline period
Water
Total fluid
% Recovery
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8TGroup
Field life phases/Ranking
1. Depletion decline phase (no water injection)
Arps
Fetkovich
Material balance
2. Fill-up phase (no water break through)
WF design (Craig, Buckley-Leverett-Welge,
Dykstra-Parson)
Composite performance plots
Compensation
French decline
Monitor reservoir pressure
3. Waterflood phase (water break through, production
history)
Composite performance plots
Compensation
WF decline curve (log(WOR) vs. cum. oil)
Conformance plots
Recoverable reserves
Current oil rate per block/well
Recoverable oil per well
Recovery dynamic percentage - Current
Production/ Remaining Reserves
Compensation
Reservoir pressure
Well count (P/I ratio)
Water cut
Mechanical/Well Integrity
Field life phases Ranking criteria
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9TGroup Goals of toolkit & process
Goal Process Tool
Reservoir energy assessment Material balance
MBAL
Excel Mat. balance
OFM Mat. balance
OOIP and recoverable
reserves assessment Decline curve analysis
OFM
Excel
Production & injection history Composite plotsOFM
Excel
Volumetric and displacement
sweep efficencyConformance plots
OFM
Excel
Theoretical and actualreservoir behavior comparison
Welge and kro/krw based on WOR OFMExcel
Forecast of WF optimization
effects
Log WOR vs. cumulative oil, decline
analysis
OFM
Excel
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10TGroup
Waterflood management process
Deliverables:
- Conversions
- Fix P/I- New drilling
Completion data
Petrophysical
data
Production ,
Injection data
Well testing,
pressure survey
Geological
data, reserves
PVT data, Cap
press, rel. perms
Collect/Assess
input data
Rank reservoirs/
Fields
Database
Criteria:
Recoverable Reserves
by Field
Recoverable Reserves
by Reservoir
Recoverable
reserves
evaluation
Block division/
analysis/ranking
Deliverables:- Candidate blocks/
wells
- Incremental
Production
Cum copmens. By
block
>100%
Curr. reservoir
pressure
100%
Fix injection
Not first priority
Conformanceplots
WOR vs Np
Compensation
Areal sweep
efficiency
Displacement
sweep efficiency
(Net waterinjected/MOPV
Fractional flow
analysis
WF decline curveanalysis
Oil rate vs. cum
oil
WOR vs MOPV
Deliverables:
- Candidate blocks/wells
- Changing WF patterns- Improve sweep (gel
bright water)
Deliverables:
- Candidate blocks/wells
- Infill/New drilling areas- Incremental Production
Water in the
ground
I/P ratio
Water break
through
Process after water break through
NO
YES
Deliverables:
- Candidate blocks/wells- Incremental Production
1. Arps
2. Fetkovich curvematch
3. Material balance
Criteria:
WC >50%
HCPVI>25%Stable well count
Stable production/
injection
Depletion decline
Deliverables:
- Candidate blocks/wells
- Incremental Production
1. Craig
2. Buckley-Leverett-Welge
3. Dykstra-Parson4. Composite
performance plots4. Compensation
Water fill-up Mature WF phase
Criteria:Recoverable reservesCurrent oil rate per block/well
Compensation
Reservoir pressure
Well count (P/I ratio)
Applicable Compositeperformance plots,
petrophysics, geology
Plots of Liquid/oil rate
vs. time
Semilog plot GOR,WOR vs. time
Plot of Cumulative oil/water vs. time
Plot of injection water
vs. time
Effectcalculation
Acceleration/Improve
compensation
Log WOR vs.cum oil
RFimprovement/
more producers
Change sweep
efficiency
Deliverables:
- Oil incremental
- Economical effect- Financial
memorandum
11
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11TGroup
0
1
2
3
4
5
2010201220142016201820202022202420262028203020322034203620382040
Yearlyoilproduction(millionm
3)
Vertical lines represent P10 & P90 forecasts
Uncertainty analysis
Identify parameters with uncertainties
eological model Hydrodynamic model
Analysis of reservoir data
Uncertainty analysis of prognoses
Compare parameter impactsModel prognoses
0
5
10
15
20
0.00 0.05 0.10 0.15 0.20 0.25 0.30 0.35 0.40 0.45 0.50
Oil production (k tonne)
Probability
010
203040
506070
8090
100
20 22 24 26 28 30 32 34 36 38 40
Initialwatersaturation
porosity %
Intial water saturation trend
Type Parameters Principal
Impact Comment Low Median High
Horizontal perm multiplier Rates poro-perm trends 0.80 1.00 1.20Vertical / hz l p erm ratio Recovery analogue marine reservoirs 0.030 0.065 0.150
Pore compressibility (kPa 10-6
) Recovery analogue 3.2 4.0 4.8
OWC (m) OIIP well test data 855 861 865
oil viscosity (c P) Rates oil samples 140 217 280
Residual oil saturation Recovery SCAL 0.24 0.28 0.32
skin Rate horizontal PTA's 0 0 3
effective producting length (m) Rate horizontal PTA's 300 600 1000
effective productive time Rate Estimates from analogue 0.70 0.90 0.95
Well
Geological
Dynamic
Select best plan from
probabilistic prognoses
12
8/12/2019 TGL Reservoir Engineering Eng
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12TGroup
Value of water injected
Log WOR vs. cum oil can be used to forecast value of oil recovery acceleration
Increased volume of water will increase volume of oil based on mass balance principle
Field oil and liquid rates
0
5000
10000
15000
20000
25000
30000
35000
18-Feb-82 11-Aug-87 31-Jan-93 24-Jul-98 14-Jan-04 6-Jul-09 27-Dec-14 18-Jun-20 9-Dec-25
Oilandliquid
srates
Oil rate (T/d)
Liquids rate (m3/d)
Forward oil rate (T/d)
Forward liquids rate (m3/d)
Increased Tot liq (m3/d)
Increase oil rate (T/d)
13
8/12/2019 TGL Reservoir Engineering Eng
13/15
13TGroup
Benefits calculation
WF Analyses
finished
Injection
Efectivness
Improve
production
efficiency
Fill-up
phase
Depletion Fill-up Waterflooding
Injectors Producers
Yes No
Neighborhood
characteristics
Fetkovich
Darcy
Fetkovich
Hyperbolicdecline
WOR vs.
cum oil
Fetkovich
Hyperbolicdecline
Non matureflooding
Matureflooding
Log WOR
vs. cum oil
Injectors /
producer
Water break
through
14
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14TGroup
Recommended practices for different levels for WFoptimization
Chart/plot Reservoir Block Pattern Well
Composite reservoir perfromanceplots (current and cumulativeproduction/injection, GOR, WC, WOR,pressure vs. time) X X X
ABC plot X X
Production heterogeneity index X X
Cumulative compensation vs. time X X X
Oil rate vs. cumulative oil X X X
WC vs. cum oil X X X
Liquid rate vs. cumulative liquid X X
Log WOR vs. cum oil X X X X
RF vs. MOPV X X X
RF vs. HCPVI X X X
RF vs. PVI X X X
PVI vs. time X X X
WC vs. PVI X X X
Cum. Water injected vs. cum. Totalfluid X X X
Volumetric sweep efficiency X X X
Hall plot X X
WF optimization process
RFbreakthrough
Field oil and liquid rates
0
5000
10000
15000
20000
25000
30000
35000
18-Feb-82 11-Aug-87 31-Jan-93 24-Jul-98 14-Jan-04 6-Jul-09 27-Dec-14 18-Jun-20 9-Dec-25
Oilandliquidsrates
Oil rate (T/d)
Liquids rate (m3/d)
Forward oil rate (T/d)
Forward liquids rate (m3/d)
Increased Tot liq (m3/d)
Increase oil rate (T/d)
Material balance
Value of injection
Conformance plots
Welge technique
Decline analysisCompensation
Recommendations
1 1 144 (2388) ;60
3/ (10 3 10)
2 1 149
3 1 152 ,
4 1 155 ,
5 1 165 ,
6 1 171
7 1 176 , ,
8 1 145 .
9 1 153
10 1 170 .
11 1 167
.
2413 .
. (2396)
12 1 178 . ( 2396)
13 1 180 (2374,5-2381,5 )
14 1 182,155 - (- 182, 155)
15 1 (13,14)
(1,6,11 )
16 1 (.
144,171,176,149,187,155)
15
8/12/2019 TGL Reservoir Engineering Eng
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15TGroup
01
02
03
0405
06
0708
09 10
1112
13
1415
16 17
1819
20
2122
23
24
2526
27
28
29
30
31
32
33 34
35
36
37
1300
1269
725
721
717
344
-40
496182
165
463486
301
-22
536
296506
424
254
2535
-107185
-49
365
30
580
341
155
504
-9
-37
849
310 660
906
369
470
011300- -.
01
02
03
0405
06
0708
09 10
1112
13
1415
16 17
1819
20
2122
23
24
2526
27
28
29
30
31
32
33 34
35
36
37
1300
1269
725
721
717
344
-40
496182
165
463486
301
-22
536
296506
424
254
2535
-107185
-49
365
30
580
341
155
504
-9
-37
849
310 660
906
369
470
011300- -.
Recommendations
1 1 144 (2388) ; 60
3/ (10 3 10 )
2 1 149
3 1 152 ,
4 1 155 ,
5 1 165 ,
6 1 171
7 1 176 , ,
8 1 145 .
9 1 153
10 1 170 .
11 1 167
.
2413 .
. ( 2396)
12 1 178 . ( 2396)
13 1 180 ( 2374,5-2381,5 )
14 1 182, 155 - (- 182, 155 )
15 1 (13,14 )
(1, 6, 11 )
16 1 (.144, 171, 176, 149, 187, 155)
Water injection redistribution Blocks ranking
Specific recommendation on well by well basis
14891490
1491
1492
1494
1496
1497
232
233
234
317
318
319
321
322
325
327
329
330
331
332
341
363
364
433
443
444
445
446
447
448
450
451
452
453
454
495
497
511
527528
529
530
531
Perspective areas identification