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

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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

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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

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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

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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