Offshore Marginal Field - 23.05.2014 (Ver2)

7/26/2019 Offshore Marginal Field - 23.05.2014 (Ver2)

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Western Offshore Marginalfield Development A

success story

Adesh Kumar

DGM(P), ONGC Mumbai


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1 Introduction

2 Status of Marginal fields

3 Challenges & strategy of In-house Development

4 Producing Western Offshore Marginal fields

Marginal fields projects under implementation5

Presentationoverview

6 Technology intensive marginal field B-193

Summary & conclusions7


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Introduction


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MARGINAL FIELDDefinition

A field that may not produce enough net income to make it worth

developing at a given time; should technical or economic conditions

change, such a field may become commercial.

A field may be categorized as marginal under the following

considerations:

Reservoir size (small volume)

Lack of infrastructure / technology

Inaccessibility to the area- remoteness

Fiscal policyMarket for gas

Cost of development

Introduction


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Worldwide development considerations

In-place Reserves

Recovery

Rate of production

Investment

Profit

Introduction


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Status of Marginal Fields


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SL Status of Western Offshore fields Western Offshore

1 Fields monetized in-house 25

2FR approved/under implementation

(offshore fields)12

5Fields identified for outsourcing(KD, B-51, B-174, D-12, D-31, SD-4,

SD-14, CA, CD, B-80, B-37, D-18, D-33)

13

6Fields under exploration/delineation(KD-1, B-147, B-45, C-37, B-9, NMT, B-15)

7

8 PEL surrendered (RV-1) 1

Total 58

Total Marginal Fields : 165

Western Offshore : 58

Eastern Offshore : 21

Onshore : 86

Statusof marginal fields


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Western Offshore

Total fields : 58

On production : 25

95.7 % of in-place is

accounted for

monetization

Eastern Offshore

Total fields : 21

On production : 5

63.2 % of in-place is

accounted for

monetization

Statusof offshore marginal fields


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52.54 %33.14%

14.32%Western Offshore (Fields 58)

Eastern Offshore (Fields 21)

Onland (Fields 86)

TOTAL INPLACE: 1510.79 MMT (O+OEG)

[ULTIMATE RESERVES : 375.83 MMT (O+OEG)]

Hydrocarbon Distribution: Area-wise


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Challenges & strategy of in-housedevelopment


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Fields are smaller in size with lesser in-place HC

Short producing life

Limited G&G and reservoir data

Logistically difficult, Isolated areas, presence of H2S , CO2

Short life cycle

Overall project economics - marginal

Challenges


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Standalone

Clustering

Grouping close-by fields

Utilizing nearby existing facilities

for fluid processing andtransportation wherever possible

Clubbing with redevelopment of

brown fields

Conversion of old Jack-up rigs as

MOPU

Hiring FPSO

Sharing nearby JV facilities

Strategy of in-house development

MUMBAI HIGH

BASSEIN

HEERA

NEELAM

SCALE

0 k m 1 0 k m 2 0 k m 3 0 k m 4 0 k m

BS-13BS-16

BS-12

PannaField (JV)

MuktaField (JV)

NQO

BHN

ICW

SH

BPA

BPBB-192

B-45

B-46

B-48

B-188

B-105

WO-24

WO-16

WO-15

WO-5

B-121/119

D-1

D-33

D-18

B-15

B-157

B-59 B-127

B-147

B-149

B-55

VASAI EAST (BSE)

B-172

B-178

B-179

B-180

B-173A

B-193

B-37

B-134

B-22

B-80

B-23A

B-28

B-28A

Marginal Fields around Mumbai Highand Bassein Fields

26"GastrunklinetoUran

24"Oil

trunklin

eto r

26"Ga

strunk

lineto

r

30" X203km

Oiltrunklineto

Uran

36"X

231

km

Gas

trunk

lin

eB

assein

toH

azir

a

18"

oilandgaslin

e

42"X

244k

mG

as

trunk

lin

eBPB

toH

azira

BHS

30"X142km

SHP-HEERA

Line

16"X

77km

B-55to

SHG

28" X 78km SH-BPBLine

I

I

I

I

I

##

####

##

##

##

##

SBM

##

##

#

#

#

#

BHE-1

14" OIL

12" GAS

#

#

#


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Producing western offshoremarginal fields


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Marginal fields around B&S Asset

14

Bassein& Around

North Tapti

C-Series

B-55

NBP

Gas Fields: B-55: 1.9 MMscmd

C-Series: 1.5 MMscmd

North Tapti: 1.25 MMscmd

B-22/B-193 : 1.95 MMscmd

(Associated Gas: 1.3 MMscmd)

Oil Fields:

NBP(D-1): 19500 bopd

Vasai East: 5900 bopd

SB-11 Block: 571 bopd

B-22 / B-193: 5000 bopd

Daman


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Marginal fields around Mumbai High

15

Cluster -7

(9000 bopd)

WO-16A

BHE

(300 bopd)

B-series

(1 MMscmd)

B127-cluster


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Year Production from Offshore Marginal fields

OilProduction

(MMt)

Oil ProductionRate

(bopd)

Gas production(MMm3)

GasProduction

(MMm3/d)

2008-09 0.82 17128.4 101.71 0.279

2009-10 0.98 20470.6 128.71 0.353

2010-11 1.02 21306.1 722.13 1.978

2011-12 0.91 19008.4 1078.85 2.956

2012-13 1.017 21243.4 1767.0 4.841

2013-14 1.374 28700 2367.6 6.487

Annual production for the last 6 years

16

Current production: 40,000 bopd and 9.0 MMm3/d gas


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Marginal field

under implementation


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Under implementation

SL Field/ Fields HC Cum

Oil/gas

RFP Peak Development

Cluster type MMT/

BCM

date Oil,

bopd

Gas,

MMm3/d

Strategy

1 C-series

(Phase-II)

3 Gas 0.5/

6.45

May15 3.00 MoPU & Bassein P/L

2 Cluster-7* 2 oil &gas

9.69/4.493

Mar15 22000 1.57 Hired FPSO, Existingfacilities of MH

3 WO-16

cluster

4 oil &

gas

2.83/

8.58

June14 18000 2.36 Rig S/Samrat MOPU

& MH facilities

4 B-127

cluster

3 gas 1.836/

2.093

Mar15 12000 3.00 Existing EPS &

facilities of MH/B&S

Total 12

* Partially being produced.


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B-193 & B-22 Cluster: case history


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Combined Development of B-22 & B-193 Project

20

Facilities:

Process cum well platform - B-193 A (6 slots)

Liquid handling capacity : 42000 BPD

Gas compression capacity : 1.1 MMSCMD

Gas sweetening facility

Living Quarters on separate deck for 70 persons

Nine unmanned well platforms (8 in Phase-I & 1 in Phase-II)

B-22 A (9 slots) B-23A A (4 slots) - sweet

BS-13 A (4 slots) B-178 A (4 slots) - sour

B-149 A (3 Slots) B-172 A (4 slots)

B-28A A (3 slots) sweet & sour

B-179 A/ B-180 (3 slots) - sour

B-28 A (3 slots) - Ph-II (after 5 yrs)

Wells (34 in Ph-I & 2 in Ph-II) : 36 ( 21 Oil+15 Gas)

Submarine pipelines : 200.6 Km in 13 segments

Modification at BE,BF,BPA,BPB platforms & Tie in ICP-Heera

trunk line


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42X244

B-193A

5 oil wells

B-172 A

3 oil wells

B-28A

2 gas wells

Ph II

B-23AA

3 gas wells

B-28AA

2 oil wells

B-178A

3 oil wells

B-179A

2 oil wells

B-22A

12X23 WF 12X16 WF

12X5.5 WF

8X7.5 WF .10X16.5 WF

12X20 Oil

PLEM

30X142 ICP-Heera Oil T/L

12X27 WF from B-22A

To B-193A

16X25.5 Gas/Cond

From B-193A to BPB

8X27 Water Inj to

Conventional well

Proposed line

12

Schematic layout and pipeline network of B-193

100 KM

BCPB

BPBBC

Gas plus Condensate

Water InjectionWell Fluid Oil wells

Oil to trunk line

Hazira

BPA

BA

36X230

30

BCP-B2

Planned line

Existing line BS-13

BS-149A


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Combined Development

Production Scenario

Projects B-22

Cluster

B-193

Cluster

Combined

(B-22+B-193)

Peak Rate

Oil (BOPD)

Cond (BOPD)

Gas

(MMSCMD)

7900

6680

4.5

28150

1870

1.52

36050

8550

5.9

Cumulative Prod

Oil (MMt)

Cond (MMt)

Gas (BCM)

2.46

1.13

6.56

5.57

0.75

5.12

8.03

1.88

11.68

22

B-193 details:H2S PPM- up to 40000, CO2 %- up to 12

Well completion: 5 horizontal wells & 12 conventional wellsProcess facilities: B-193 Process platform


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B-193: Glimpses of Offshore Construction

B-193 Process Platform: Living Quarter(AQ) & the Process

Platform(AP). The deck weight of B 193 LQ deck is 7800 Tons and process platform

deck is 13500 tons. Both the decks were fabricated in Pasir Gudang

yard of Sime Darby.

The float over installation is normally carried out for the decks

weighing more than 7000 tons.

The integrated deck is fabricated in the yard and towed out to the pre-

installed jackets and then floated between the jacket legs until the

mating points between the deck and the jacket are aligned. The deck

is then lowered onto the jacket by ballasting the barge and adjusting

hydraulic jacks by which the deck load is progressively transferred

from the barge to the jacket. The barge moves between the jacketduring high tide and after installation of deck and transfer of load on

jacket , it is taken out during low tide. This process of moving the deck

into position over the jacket is a very precise & slow operation and

takes around 12 hours to accomplish.


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B-193 (AQ) Float over installation

Integrated LQ Deck stationed near pre-installed Jacket


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Positioning of Barge between Jacket legs for process of load transfer



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Barge leaving after completion of float over operation



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B-193 (AP) Float over

28


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29


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30


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B-193 Process Complex


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B-193 Well cum Process Platform:Living Quarter (AQ) & Process Platform (AP) were installed on 16.12.2012 &

27.12.2013 respectively by float-over method-First time in Western Offshore.

Installation of structure is completed on 30.01.2013. Hook up & commissioning job

completion: 31.05.2013

20/34


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Summary & conclusions

S & l i


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Summary & conclusions

ONGCsapproach of offshore marginal field developmentis at par with international practices.

96% of inplace reserves are accounted for in the in- house

development of Western Offshore Marginal fields

Majority of fields have been put on production and all thepossible in-house monetization efforts for 37 fields will be

completed by March 2015.

The current production is 40,000 bopd and 9 MMscmd of

gas in Western Offshore. The technology induction (floatover and sour gas

processing) will go a long way in future developments.


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hank You


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Production & investment details

Field/ No of HC type Peak oil Peak gas Oil Gas Life CAPEX

Cluster fields bopd MMm3/d MMt BCM Years Rs crores

D-1 1 oil 36059 1.37 13.96 0.54 20 2670

SB-11 1 oil 3000 0.07 0.47 0.17 5 220

V-East 1 oil 11890 1.93 4.66 6.22 15 2476

B-134 1 oil&gas 1600 0.25 0.31 0.24 8 ~ 200

C-series* 3 gas 10290 3.19 4.90 15.14 15 3886

C-26 cluster 3 Gas 3.00 0.50 5.94 15 2592

B-193/28 cluster 8 oil&gas 30000 1.52 6.32 5.12 158554

B-22 cluster 4 oil&gas 14900 4.52 3.59 6.50 10

B-46 cluster 4 gas 2893 1.64 1.30 5.27 13 1457

North Tapti 1 gas --- 2.00 --- 4.12 10 756

Cluster 7 2 oil&gas 21913 1.57 9.73 4.52 16 2614

WO cluster 4 oil&gas 18178 2.36 2.83 8.58 12 3385B-127 cluster 3 gas 12000 3.00 1.836 2.093 12 2666

BHE 1 oil 2500 0.10 0.45 8 ~ 168

37 20.52 48.52 68.45 31644

Opex = 4887Revenue: Oil18.37 Billion $, Gas -


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Fields under monetization

Sl Field/ Fie

lds

HC IOIP/ RFP Peak Development

Cluster type IGIP date Oil,bopd

Gas,MMm3/d

Strategy

1 NBP-D1 1 oil Feb06 3600

0

1.37 MOPU/FPSO,

Tanker

2 SB-11 1 oil Jul07 3000 0.07 Existing BPA

facilities

3 Vasai

East

1 oil May0

8

1200

0

1.93 New processing at

existing BPA

facilities

4 C-series

- Ph-I

- Ph-II

3

3

gas

Apr,13

May15

1050

0

3.19

3.00

Existing facilities at

NQMoPU & Bassein P/L

5 B-134 1 oil Jun

10 1600 0.25 Integrated with

Heera facilities

6 B-46

cluster

4 gas Jul12 2900 1.64 Existing facilities at

MHN

7 B-193Cluster

8 oil &as

Dec13

30000

1.52 New Processing &with Bassein field


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Fields under monetization

Sl Field/ Fields HC IOIP/ RFP Peak Development

Cluster type IGIP date Oil,

bopd

Gas,

MMm3/d

Strategy

9 North

Tapti

1 gas Oct12 --- 2.00 Sharing existing JV

facilities

14 SB-14 1 Oil

10

Cluster-7 2

oil &gas

Apr

1322000 1.57

Hired FPSO, Existingfacilities of MH

11 WO-16

cluster

4 oil &

gas

Jan14 18000 2.36 Rig S/Samrat MOPU

& MH facilities

12 BHE &

BH-35

1 oil Apr13 2500 0.10 Existing facilities ofMH Asset

13 B-127cluster

3 gas Mar15 12000 3.00 Existing EPS &facilities of MH/B&S

Total 38 165500 23.52 Cum oil-

Cum gas

Investment-

Documents

Offshore Marginal Field - 23.05.2014 (Ver2)