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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
B-193 (AQ) Float over installation
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Barge leaving after completion of float over operation
B-193 (AQ) Float over installation
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B-193 (AQ) Float over installation
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B-193 (AP) Float over
28
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B-193 (AP) Float over
29
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B-193 (AP) Float over
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
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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-