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1
‘‘Showcasing Indian fields Showcasing Indian fields –– OffshoreOffshore’’
S. K. VermaSub-surface Manager
Mumbai High Asset, ONGC Mumbai
April 15, 2010Petroleum Federation of India (PETROFED)
New Delhi
Conference onIOR-EOR : Challenges, Process and Technologies
Session 1 : Indian IOR/ EOR Experience
2
IntroductionIntroduction
Mumbai Offshore BasinMumbai Offshore Basin
Field Development challengesField Development challenges
Major IOR/EOR ProjectsMajor IOR/EOR Projects
IOR/EOR Experience IOR/EOR Experience
Process and TechnologiesProcess and Technologies
Way ForwardWay Forward
Presentation Structure
3
0
20
40
60
80
100
120
140
160
ONGC Western Offshore
Crude Oil Production, MMT Natural Gas Production, BCM
Oil & Gas Production during XI Plan PeriodOil & Gas Production during XI Plan Period
140.06
112.39 BCM
87.2476.91 BCM
4
Mumbai Offshore Basin
Formed due to extensional tectonics at the time of rifting of the Indian plate from Madagascar during late Jurassic-early Cretaceous period
Covers about 148,000 km2 from coast to 200m isobath
Divided into 6 tectonic blocks
Mature source rocks present in lower Eocene-Paleocene Pannaformation
Hydrocarbons established in multiple pay zones in this basin –ranging from fractured basement to middle Miocene
The extensive post-Miocene shale acts as the regional ‘cap-rock’.
Surat depression
Panna depressionRatna depression
Bombay platform
Evidence from radiometric dating indicated that the Earth is about 4.570 billion years old
5
SURATNORTH TAPTI
MID TAPTI
SOUTH TAPTI
SD-4C-24C-26A
DAHANU CDSD-1
SD-14
C-22CA
DAMAN
B-55
B-163
B-15B-188
B-48
B-46
B-45
D-12 B-192AB-192
B-121B-119
PANNA
VASAI
MUKTA
D-1D-18
B-80
NEELAM
HEERA R-15A
B-147
B-51 MUMBAI
MUMBAI HIGH
OIL FIELD
GAS FIELD
LEGEND
Major Oil & Gas fields of Mumbai Offshore
VASAI EAST
Main structures delineated in the Mumbai Offshore Basin
Mumbai High, Ratna, Heera, Panna, Vasai, Neelam, Mukta, Tapti, and other small structures
Success expanded to East Coast with discovery of oil & gas in Godavary, Cauvery offshore
M R83 H84 P86 V88 NM90
6
Mumbai High Field
(As on 01.04.2010)
IOIP, MMt 1659Cumulative Oil, MMt 411Recovered, % 25Oil rate, bopd 2,25,000Water Injection, bwpd 9,00,000
Water-cut,% 69Platforms 113Producing strings 727Gas producers 36Water injection strings 198
7
Heera
(As on 01.04.2010)
IOIP, MMt 305Cumulative Oil, MMt 55Recovered, % 18Oil rate, bopd 56,000Water Injection, bwpd 1,46,000
Water-cut,% 56Platforms 19Producing strings 161Gas producers 7Water injection strings 58
SURATNORTH TAPTI
MID TAPTI
SOUTH TAPTI
SD-4C-24
C-26A
DAHANUCD
SD-1
SD-14
C-22
CADAMAN
B-55
B-163
B-15B-
188B-48
B-46
B-45
D-12 B-192AB-192
B-121B-119
PANNA
VASAI
MUKTA
D-1
D-18
B-80
NEELAM
HEERAR-15A
B-147
B-51 MUMBAI
MUMBAI HIGH
OIL FIELDGAS FIELD
LEGEND
8
Neelam
(As on 01.04.2010)
IOIP, MMt 109Cumulative Oil, MMt 29Recovered, % 26Oil rate, bopd 20,000 Water Injection, bwpd 97,000
Water-cut, % 85Platforms 13Producing strings 72 Water injection strings 23
SURATNORTH TAPTI
MID TAPTI
SOUTH TAPTI
SD-4C-24
C-26A
DAHANUCD
SD-1
SD-14
C-22
CADAMAN
B-55
B-163
B-15B-
188B-48
B-46
B-45
D-12 B-192AB-192
B-121B-119
PANNA
VASAI
MUKTA
D-1
D-18
B-80
NEELAM
HEERAR-15A
B-147
B-51 MUMBAI
MUMBAI HIGH
OIL FIELDGAS FIELD
LEGEND
9
Bassein
(As on 1.4.2010)
IGIP, BCM : 339
Cumulative Gas, BCM : 187
Recovered, % : 55
Gas rate, MMSCM : 28.2
Number of platforms : 6
Producing gas wells : 49
Producing oil wells : 5
SURATNORTH TAPTI
MID TAPTI
SOUTH TAPTI
SD-4C-24
C-26A
DAHANUCD
SD-1
SD-14
C-22
CADAMAN
B-55
B-163
B-15B-
188B-48
B-46
B-45
D-12 B-192AB-192
B-121B-119
PANNA
VASAI
MUKTA
D-1
D-18
B-80
NEELAM
HEERAR-15A
B-147
B-51 MUMBAI
MUMBAI HIGH
OIL FIELDGAS FIELD
LEGEND
10
0
5
10
15
20
25
1976
-77
1979
-80
1982
-83
1985
-86
1988
-89
1991
-92
1994
-95
1997
-98
2000
-01
2003
-04
2006
-07
2009
-10
Oil,
MM
t
MH HEERA NEELAM B-173 D1 VASAI EAST
Annual oil production from MR fields
11
Initiatives: IOR/ EORInitiatives: IOR/ EOR
IOR/EOR Schemes in 15 major fields of ONGC have been under implementation since 2001
IOR/ EOR campaign & redevelopment projects with investment more than Rs 30,000 Crores
This initiative has helped to arrest the natural decline to great extent and raised the recovery factor from these
fields from 27.5% in 2001 to 32.5% in 2009.
12
Challenges, Process & Challenges, Process &
Technologies Technologies
13
Matured fieldsComplex reservoirs ◦ Large area, shallow
reservoirs◦ Heterogeneous◦ Multilayered◦ Gas cap◦ Thin sweet zones◦ Drilling complications
Water cut increasingAging facilities
Western offshore challenges
14
Multi-layers of Mumbai High
(a) Stratigraphic Sequence in Mumbai High Field
LIII reservoir-multilayered with shale, limestone,
sequence-holds about 94% of the total IOIP
Oil reservoirs :L I, LII, LIII, LIV, LV, Basal Clastics and fractured Basement
Gas reservoir :S1
(b) Sub-Layers of L-III Reservoir
15
Porosity Permeability -derived
Geological Cross Sections Showing Layer wise Porosity and Permeability Distribution
Fracs, vugs, channels, tight zones
16
0
50000
100000
150000
200000
250000
300000
350000
400000
450000
500000
Mar
-76
Mar
-78
Mar
-80
Mar
-82
Mar
-84
Mar
-86
Mar
-88
Mar
-90
Mar
-92
Mar
-94
Mar
-96
Mar
-98
Mar
-00
Mar
-02
Mar
-04
Mar
-06
Mar
-08
Mar
-10
Oil,
BO
PD
0
100
200
300
400
500
600
700
800
No
of S
tring
s
Initial Development
WI, ADBHN & AORP
EORP in South & L-II
BHN Accident
Re-
dev-
Ph-
I ,
Add
ldev
in A
1Gas Lift
Re-
dev-
Ph-
II
PP
M P
roj,
CR
MP
-I &
II
Mumbai High Development History
17
Renewed Development Strategy
Review field development/ redevelopment◦ Integration of data
◦ More accurate modeling◦ MDT approach◦ Target bypassed oil zones/ patches /◦ Infill drilling◦ Well completion ◦ Re-oriented drainage pattern
Best in class technology inductionDomain expertsImproved production practices◦ Conservation of reservoir energy◦ Adequate energy replenishment ◦ Efficient artificial lift system◦ Integrated asset model approach
Projectised IOR / RedevelopmentEOR pilots
18
0.0
5.0
10.0
15.0
20.0
25.0
80-8
182
-83
84-8
586
-87
88-8
990
-91
92-9
394
-95
96-9
798
-99
00-0
102
-03
04-0
506
-07
08-0
910
-11
12-1
314
-15
16-1
718
-19
20-2
122
-23
24-2
526
-27
28-2
9
MM
t
0
10
2030
40
50
60
7080
90
100
Per
cent
age
40% Rec plan Revised FR Phase II% recovery Water Cut %
25%411 MMt
Life cycle rolling development plan approach
Rolling development plan to be conceived based on experience and new data of each plan and induction of evolving technologies
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ChallengeTo locate by passed oil in highly heterogeneous Carbonate Reservoir
ApproachImproved modeling through Seismic to SimulationIntegration
-140
-1400
-1400
-1350
-1350
1
1Z
2
33Z
4
5
5Z
66Z
7
7Z
8H
99Z
1
2
3
4
5
67H
8H
9
7P
2Z8P
1
2
3
4
5
67
1
56
78
1
2
3
4
5
6
78 92Z
8Z
1
2
3
4
5
6
7
8
9
1Y
1Z
2Z
3Z6Z
1
2
3
45
67
8
9
1
2
3
4
5
6
7
8
9
10H
11H
8ZH
1
2
3
4
5
6
7
8
9
1Z
2
3
5
6
7
95Z
1H
1
23
4
5
6
3Z
3
4
7
7H1
2
3
4
5H
7H6H
P1H
P
1
2
3
4
56
5Z
1
2
3
4
56
9H
1
Z
1
3
4
5
6
1Z
1
2
5
2Z
1
2
34
5
6
1
2
3
4
5
6
7
8
98ZH
2ZH
12H
9H
L1L2
L1L2
BH-12
BH-35
BH-5
BH-52
-55
BH-D
ED
EE
IE
II
IJ
IK
IL
IM
IN
IT
IW
S1-4
S1-6
SG
SH
SU
SV
SW
SY
748000 749000 750000 751000 752000 753000 754000 755000 756000 757000 758000 759000 760000 761000 762000 763000 764000
748000 749000 750000 751000 752000 753000 754000 755000 756000 757000 758000 759000 760000 761000 762000 763000 764000
2126
000
2128
000
2130
000
2132
000
2134
000
2136
000
2138
000
21260002128000
21300002132000
21340002136000
2138000
0 500 1000 1500 2000 2500m
1:70000
MHS : B Top Structure Contour Map
Studies for field redevelopment
20
Scheme Forecast, MMt % RF by 2030
Base 134.9 25.0MH NorthPhase-I
Scheme 158.2 29.2
Base 286.7 29.3MH SouthPhase-I
Scheme 320.6 32.8
Base 156.9 29.0MHN A1 Layer
Scheme 160.4 29.7
IOR Schemes Western Offshore Fields
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IOR Schemes Western Offshore Fields
Scheme Forecast, MMt % RF by 2030
Base 158.4 29.3MH NorthPhase-II
Base 318.4 32.5
SchemeRCE
337.6
Scheme 178.2 32.2
34.5
MH SouthPhase-II
Base 25.0 20.2HeeraRedevelopment
Scheme 35.7 28.9
22
Reserves Improvement: Mumbai High
0.001
0.010
0.100
1.000
10.000
0 25 50 75 100 125 150
WO
R
Cum.Oil, MMt
Water Oil Ratio Vs. Cum Production
Start of Redevelopment Phase-I
MHN:Oil rate vs Oil production
0
20000
40000
60000
80000
100000
120000
140000
0 25 50 75 100 125 150 175 200
Np, MMt
BO
PD
Start of Redevelopment Phase-I
0.001
0.010
0.100
1.000
10.000
0 50 100 150 200 250 300Cum.Oil, MMt
WO
R
Water Oil Ratio Vs. Cum Production
Start of Redevelopment phase
MHS: oil Rate Vs cummulative production
0
50000
100000
150000
200000
250000
300000
350000
400000
0 50 100 150 200 250 300 350 400
Np, MMt
BO
PD
23
050000
100000150000200000250000300000350000400000450000500000
Mar
-76
Mar
-79
Mar
-82
Mar
-85
Mar
-88
Mar
-91
Mar
-94
Mar
-97
Mar
-00
Mar
-03
Mar
-06
Mar
-09
Mar
-12
Mar
-15
Mar
-18
Mar
-21
Mar
-24
Mar
-27
Mar
-30
Initial Development
WI, ADBHN & AORP
EORP in South & L-II Re-dev Ph-I
Re-dev Ph-II
Production Enhancement - Mumbai High
MH North Phase-I
(RFR) Phase-II MH South Phase-I (RFR)
Phase-II (RCE)
Capex, Rs Cr 3239.43 7133.39 Capex, Rs Cr 6579.25 8813.41
Incr Oil, MMt 23.25 17.35 Incr Oil, MMt 33.85 18.31
Incre.Oil 57.10 MMt
Incre.Oil 35.66 MMt
24
0
100000
200000
300000
400000
500000
600000
700000
800000
900000
Mar
-76
Mar
-78
Mar
-80
Mar
-82
Mar
-84
Mar
-86
Mar
-88
Mar
-90
Mar
-92
Mar
-94
Mar
-96
Mar
-98
Mar
-00
Mar
-02
Mar
-04
Mar
-06
Mar
-08
Mar
-10
BO
PD
, BLP
D
0
50
100
150
200
250
300
350
400
450
Cum
Oil
(MM
t)
BLPD BOPD Cum Oil (MMt)
Production Performance – MH field
25
Production Performance – Heera field
0
20000
40000
60000
80000
100000
120000
140000
Mar
-84
Mar
-85
Mar
-86
Mar
-87
Mar
-88
Mar
-89
Mar
-90
Mar
-91
Mar
-92
Mar
-93
Mar
-94
Mar
-95
Mar
-96
Mar
-97
Mar
-98
Mar
-99
Mar
-00
Mar
-01
Mar
-02
Mar
-03
Mar
-04
Mar
-05
Mar
-06
Mar
-07
Mar
-08
Mar
-09
Mar
-10
BO
PD
, BLP
D
0
10
20
30
40
50
60
70
80
90
100
Cum
Oil
(MM
t)
BLPD BOPD Cum Oil (MMt)
26
Production Performance – Neelam field
0
20000
40000
60000
80000
100000
120000
140000
160000
180000
200000
Mar
-90
Mar
-91
Mar
-92
Mar
-93
Mar
-94
Mar
-95
Mar
-96
Mar
-97
Mar
-98
Mar
-99
Mar
-00
Mar
-01
Mar
-02
Mar
-03
Mar
-04
Mar
-05
Mar
-06
Mar
-07
Mar
-08
Mar
-09
Mar
-10
BO
PD
, BLP
D
0
5
10
15
20
25
30
35
40
45
50
Cum
Oil
(MM
t)
BLPD BOPD Cum Oil (MMt)
27
Technologies Inducted
Hi-tech wells -Horizontal, Multilateral, ERDRotary steerable system (RSS) to increase drilling efficiencyGlycol & Synthetic Oil Base (SOBM) mud for efficient drillingHGS for drilling/ workover of depleted zonesEnzyme breaker for horizontal drain hole clean upPerforated liner completion for stability of horizontal drainholesCTU friendly completionSegmented, Level-3 well completion
Continued…
28
Technologies Inducted
Relocation of poor producers through variety of sidetracksCHFR Modular rigsLogging while drilling (LWD) Real time operation (RTO) monitoringGeo-steering in thin zones‘Smart’ well platforms
Continued…
29
Improved Reservoir Model
◦ 3D-4C API
◦ Fracture delineation & extent mapping for tracking of Reservoir fluid movement and placement of wells optimally
Improved well completion for prolonged oil productivity
Electrical submersible pumps for efficient liquid lifting
Integrated asset management (IAM) for real time surveillance and control, OCC
Platform mounted modular rigs
EOR
Improved Technology Induction planned
30
Summary
Absorption of technological advancements in G & G, engineering, drilling and completion of hi-tech wells has boosted the production and improved recovery.
Life cycle approach has helped to continue production and recovery improvement from the matured offshore fields.
With integration of the experience gained and leveraging state-of-the art technology, it is envisioned that it will be possible to improve performance and further enhance the oil recovery.
31
Thanks for Kind Attention