Western Offshore Marginal field Development – A A success story Adesh Kumar DGM(P), ONGC Mumbai
Presentation overview 1
Introduction
2
Status of Marginal fields
3
Challenges & strategy strategy of In-house Development Development
4
Producing Western Western Offshore Marginal fields
5
Marginal fields projects under implementation
6
Technology echnol ogy intensive marginal field – B-193
7
Summary & conclusions
Presentation overview 1
Introduction
2
Status of Marginal fields
3
Challenges & strategy strategy of In-house Development Development
4
Producing Western Western Offshore Marginal fields
5
Marginal fields projects under implementation
6
Technology echnol ogy intensive marginal field – B-193
7
Summary & conclusions
Introduction
Introduction MARGINAL FIELD – Definition
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 policy Market for gas Cost of development
Introduction Worldwide development considerations •
In-place Reserves
Recovery
•
•
Rate of production
Investment
Profit
•
•
Status of Marginal Fields
Status of marginal fields Total Marginal Fields Western Offshore Eastern Offshore Onshore SL 1 2
: 165 : 58 : 21 : 86
Status of Western Offshore fields Fields monetized in-house FR approved/under implementation (offshore fields)
Western Offshore 25 12
Fields identified for outsourcing 5 6 8
(KD, B-51, B-174, D-12, D-31, SD-4, SD-14, CA, CD, B-80, B-37, D-18, D-33)
Fields under exploration/delineation (KD-1, B-147, B-45, C-37, B-9, NMT, B-15)
13 7
PEL surrendered (RV-1)
1
Total
58
Status of offshore marginal fields 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
Hydrocarbon Distribution: Area-wise TOTAL INPLACE: 1510.79 MMT (O+OEG) [ULTIMATE RESERVES : 375.83 MMT (O+OEG)]
14.32% Western Offshore (Fields 58)
33.14%
52.54 %
Eastern Offshore (Fields 21) Onland (Fields 86)
Challenges & strategy of in-house development
Challenges • 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
Strategy of in-house development •
##
B-105
Standalone
B-55
B-15
G S H t o 5 5 B k m 7 7 X " 1 6
B-188 B-48 B-46 •
Clustering Grouping close-by fields
NQO
B-157#
SBM
a i r z a H i ra to a z i n H e s to s a B B B P e e li n i n k k l n n tr u r u s s t a G G a m m k 1 4 k 3 2 24 X X " 6 " 3 42
B-59 B-127
BHN
–
MUMBAI HIGH •
WO-24
Utilizing nearby existing facilities
–
–
–
–
for fluid processing and transportation wherever possible
12" GAS
Mukta Field (JV)
BHE-1
Panna Field (JV)
SH
B-45 –
14" OIL
ICW BHS
B-149 B-147 B-192
2 8" X
Clubbing with redevelopment of brown fields
7 8 k m
BPA
#
#
Conversion of old Jack-up rigs as MOPU
WO-15
D-33
B-22# BPB S H - B PB L i ne
B-80 3 0 " X 1 4 2 k m B-23A S H B-28## P - H ## E E WO-16 R A L in e
3 0 "
BASSEIN
BS-12
##
B-178
2 6 " G a s t 2 0 r u n k 3 k l i n e m
X
t o O i U r l t r a n u n k l i n e ## B-172 t o U r a n
B-173A# ##
B-193
##
B-179
##
B-180
I ##
B-28A
Hiring FPSO Sharing nearby JV facilities
#
BS-13 BS-16
B-121/119
WO-5
VASAI EAST (BSE)
I
B-37#
I
B-134 D-1
NEELAM
Marginal Fields around Mumbai High D-18 and Bassein Fields
e l i n s a g r d t o n a l in e i l o u n k " r i l t r 8 " O o 1
2 4
SCALE 0 km
1 0k m
2 0k m
3 0k m
4 0k m
HEERA
2 6 "
t l in e u n k s t r G a
I
I
Producing western offshore marginal fields
Marginal fields around B&S Asset
Gas Fields:
B-55:
1.9 MMscmd
C-Series:
1.5 MMscmd
North Tapti: 1.25 MMscmd
B-22/B-193 : 1.95 MMscmd
North Tapti
Daman C-Series
(Associated Gas: 1.3 MMscmd)
Oil Fields:
NBP(D-1):
19500 bopd
Vasai East:
5900 bopd
SB-11 Block:
B-22 / B-193: 5000 bopd
B-55 Bassein & Around
571 bopd
NBP
Marginal fields around Mumbai High
B-series (1 MMscmd)
Cluster -7 (9000 bopd)
B127-cluster
BHE (300 bopd)
WO-16A
Annual production for the last 6 years Year
Production from Offshore Marginal fields Oil Production (MMt)
Oil Production Rate (bopd)
Gas production (MMm3)
Gas Production (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
Current production: 40,000 bopd and 9.0 MMm3/d gas
Marginal field – under implementation
Under implementation SL
Field/
Fields
Cluster
HC
Cum Oil/gas
RFP
type
MMT/ BCM
date
1
C-series (Phase-II)
3
Gas
0.5/ 6.45
May’15
2
Cluster-7*
2
oil & gas
9.69/
Mar’15
Peak Oil, bopd
Development
Gas, MMm3/d
Strategy
3.00
MoPU & Bassein P/L
22000
1.57
Hired FPSO, Existing facilities of MH
4.493
3
WO-16 cluster
4
oil & gas
2.83/ 8.58
June’14
18000
2.36
Rig S/Samrat MOPU & MH facilities
4
B-127 cluster
3
gas
1.836/ 2.093
Mar 15
12000
3.00
Existing EPS & facilities of MH/B&S
Total
12
* Partially being produced.
’
B-193 & B-22 Cluster: case history
Combined Development of B-22 & B-193 Project Facilities: •
Process cum well platform - B-193 A (6 slots) Liquid handling capacity Gas compression capacity Gas sweetening facility
: 42000 BPD : 1.1 MMSCMD
•
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
Schematic layout and pipeline network of B-193 B-28A 2 gas wells Ph II
B-28AA 2 oil wells
B-179A 2 oil wells
Hazira
8”X7.5 WF . 12’’
10”X16.5 WF
36”X230 B-23AA 3 gas wells
12”X23 WF
B-193A 5 oil wells
12”X16 WF
30”
B-178A 3 oil wells
BA
BPA
16”X25.5 Gas/Cond
From B-193A to BPB
12”X5.5 WF 12”X20 Oil
100 KM
B-172 A 3 oil wells PLEM
8”X27 Water Inj to
Conventional well
30”X142 ICP-Heera Oil T/L
Existing line Planned line Proposed line
BC
BPB 42”X244 BCPB
BCP-B2 12”X27 WF from B-22A
To B-193A
B-22A
BS-149A BS-13 Gas plus Condensate Water Injection Well Fluid Oil wells Oil to trunk line
Combined Development Production Scenario B-22
B-193
Combined
Cluster
Cluster
(B-22+B-193)
Oil (BOPD)
7900
28150
36050
Cond (BOPD)
6680
1870
8550
4.5
1.52
5.9
Projects Peak Rate
Gas (MMSCMD) Cumulative Prod Oil (MMt)
2.46
5.57
8.03
Cond (MMt)
1.13
0.75
1.88
Gas (BCM)
6.56
5.12
11.68
B-193 details: H2S PPM- up to 40000, CO2 %- up to 12 Well completion: 5 horizontal wells & 12 conventional wells
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 preinstalled 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 jacket during 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.
B-193 (AQ) Float over installation Integrated LQ Deck stationed near pre-installed Jacket
B-193 (AQ) Float over installation Positioning of Barge between Jacket legs for process of load transfer
B-193 (AQ) Float over installation Barge leaving after completion of float over operation
B-193 (AQ) Float over installation
B-193 (AP) Float over
B-193 (AP) Float over
B-193 (AP) Float over
B-193 Process Complex
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
Summary & conclusions
Summary & conclusions • ONGC’s approach of offshore marginal field development • •
• •
is 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 the possible 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.
Production & investment details Peak gas
∑Oil
∑Gas
Life
CAPEX
bopd
MMm3/d
MMt
BCM
Years
Rs crores
No of
Cluster
fields
D-1
1
oil
36059
1.37
13.96
0.54
20
SB-11
1
oil
3000
0.07
0.47
0.17
5
V-East
1
oil
11890
1.93
4.66
6.22
15
B-134
1
oil&gas
1600
0.25
0.31
0.24
8
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
15
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
3385
B-127 cluster
3
gas
12000
3.00
1.836
2.093
12
2666
BHE
1
oil
2500
0.10
0.45
20.52
48.52
37
HC type
Peak oil
Field/
8 68.45
2670 220 2476 ~
200
8554
~
168
31644
Opex = 4887 Revenue: Oil – 18.37 Billion $, Gas -
Fields under monetization Sl
Field/
Fie lds
Cluster
HC type
IOIP/
RFP
Peak
IGIP
date
Oil, bopd
Gas,MM m3/d
Development Strategy
1
NBP-D1
1
oil
Feb 06
3600 0
1.37
MOPU/FPSO, Tanker
2
SB-11
1
oil
Jul 07
3000
0.07
Existing BPA facilities
3
Vasai East
1
oil
May 0 8
1200 0
1.93
New processing at existing BPA facilities
Apr,13 May’15
1050 0
3.19 3.00
Existing facilities at NQ MoPU & Bassein P/L
4
C-series - Ph-I - Ph-II
gas 3 3
5
B-134
1
oil
Jun 10
1600
0.25
Integrated with Heera facilities
6
B-46 cluster
4
gas
Jul 12
2900
1.64
Existing facilities at MHN
7
B-193
8
oil &
Dec 1
3000
1.52
New Processing &
