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O I L S E A R C H L I M I T E D
Oil Search Profile
Established in Papua New Guinea (PNG) in 1929
Operates all of PNG’s producing oil and gas fields. Current gross production ~33,500 boepd, net share ~18,500 boepd
At December 2010, proven reserves were 337 mmboe, proven and probable 559 mmboe plus 318 mmboe 2C resources, taking 2P reserves and 2C resources to 877 mmboe
PNG Government is largest shareholder with 15%. In early 2009, Govt issued exchangeable bond over shares to IPIC of Abu Dhabi
29% interest in PNG LNG Project, world scale LNG project operated by ExxonMobil. Project in construction, first LNG sales expected 2014
Exploration interests in PNG and Middle East/North Africa
Market capitalisation ~US$8 billion. Listed on ASX (Share Code OSH) and POMSOX, plus ADR programme (Share Code OISHY)
2
Oil Search Locations
3
TunisiaIraq
Yemen
Papua New Guinea
Australia Brisbane
Sydney
Port Moresby(Head Office)
Kutubu Ridge Camp
Dubai
Sana’a
TunisSulaymaniyah
Kumul Terminal
Port Moresby
7°S
Juha
PRL08
PPL240
PRL11
PDL7
PPL239 PDL1
PRL02
PDL2
PDL4PDL3
PRL09
PDL6
PDL5
PRL14
PPL260
APPL249
APPL250
233
PDL9PDL8
PPL233
APPL386
PPL219
LNG Facility
Gulf Offshore
6°S
8°S
9°S
PRL01
PPL234
PRL10
PPL244
Kiunga
Kundiawa
Mt. Hagan
Mendi
Kerema
Pandora
SE Mananda
Uramu
100km
Madang
Daru
Wabag
Gobe
PPL276
PPL338
338
338
338
PPL339
339
339
339
PPL339
339
PPL312
339 339
PPL260
Kopi Wharf
145°E 146°E144°E143°E 147°E
Kimu
PRL3
APPL385
240
240
V.
Key Oil and Gas Fields, PNG
4
Lae
LEGEND
Oil Field
Gas Field
Prospect
Oil Pipeline
Proposed Gas Pipeline
Major Road
P’nyang
Mananda 5 Kutubu, Agogo & Moran
Gulf Onshore
Hides
ExplorationGas Resources
PNG LNG ProjectGas Resources
Non PNG LNG Gas Resources
Barikewa
AngoreKomo Airstrip
Hides GasConditioning Plant
Trapia
Elk/Antelope
OSH Strategies to Create Value
Optimise current oil and gas production:Through improved efficiencies and pursuit of near field opportunities
Maximise value of PNG LNG Project (T1 & T2):By utilising in-country knowledge to assist Operator
Develop LNG and other gas expansion opportunities:Build gas resources for both PNG LNG expansion and standalone LNG project/s
Measured programme of other growth options: Optimise exploration portfolio
Ensure Oil Search’s Sustainability:Operate business in transparent and sustainable manner to ensure long term operating stability and enhance ‘social licence to operate’
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Strong Performance in 1H11
1H 2011 NPAT increased by 117% to US$114.5 millionResult driven by 53% increase in realised average oil price of US$116.89 per barrel, more than offset 10% lower production of 3.56mmboeCash operating margin stable against back drop of inflationary pressure in PNG coupled with adverse currency movements and declining volumes
6
2007 2008 2009 2010
4
6
8
10
12Production (mmboe)
0
2
Oil Price (US$/bbl)
1H 11
40
60
80
100
120
0
20
200
300
400
500
600US$m
0
100
NPAT*
Operating cash flow
EBITDAX Margin
2007 2008 2009 2010 1H 11
83%83%
86%
83%
80%
*NPAT before significant items
World Class Safety Performance
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Total Recordable Injury Frequency Rate of 1.47 in 1H11TR
I /
1,0
00
,00
0 H
ou
rs
01999 2000 2001 2002 2003 2004 2005 20072006 2008 2009 2010 1H 11
2
4
6
8
10
12
Oil Search
Australian Companies (APPEA)
InternationalCompanies
(OGP)3.9 3.1 2.9
2.72.1
4.0
3.6
4.9
5.76.0
1.75
10.69.8 10.7
5.8
1.7
4.7
2.4 2.312.05
1.16
2.04 1.68
5.2
9.1 9.37.8
7.0
7.3
9.4
8.2
6.36.8
6.0
1.96
5.2
1.47
Share Price PerformanceAug 2011
Woodside
Santos
ASX 100
WTI oil
Oil Search
0.00
1.00
2.00
3.00
4.00
5.00
6.00
7.00
8.00
9.00
Jan 06
Share price (rebased to OSH)
Jul 06 Jan 07 Jul 07 Jan 08 Jul 08 Jan 09 Jul 09 Jan 10 Jul 10 Jan 11 Jul 11
US$1.23 billion in cash at end June
Cash invested and actively managed with highly rated bank counterparties
US$275.5 million available from term revolving facility, nil drawn down. Facility doesn’t expire until 2013, will refinance prior to expiry
No oil hedging undertaken during 1H11 or currently in place - realised earnings uplift from 2011 oil price recovery
US$1.32 billion has been drawn down under the PNG LNG project finance facility
2011 interim dividend of two US cents per share to be fully underwritten via DRP
99
Treasury Update - 30 June 2011
Liquidity
10
Outlook updated for first half cash generation, investment spend and forward pricesLiquidity (including escrowed cash) at the end of 1H 2011 ~ $1.5 billionCompany is well placed to meet existing commitments / base business plan with sufficient liquidity to deliver on strategic plan initiatives
Key Assumptions:1. Brent Forward curve pricing as at 1 July 20112. PNG LNG Project on schedule and budget3. Includes T3 pre FEED costs4. Production, operating costs and investment spend based on strategic review business plan 5. Existing oil facility refinanced
US
$m
m
Liquidity (cash plus undrawn bank debt)
020142011
PNG LNG Project Overview
1111
Kumul Terminal
Port Moresby
7°S
145°E
HidesWellsJuha
Facility
EPC3LNG Facility
Kutubu CPF
145°E 146°E144°E143°E
6°S
8°S
9°S
GorokaKundiawa
Mt. Hagan
Mendi
Kerema
EPC5BKomo
Airfield
100km
147°E
Daru
Wabag
LEGENDOil Field
Gas Field
Oil Pipeline
LNG Gas Pipeline
Oil Facility
LNG Facility
Major Road
Lae
EPC2Offshore pipeline
EPC5AOnshore pipeline
and Infrastructure
Gobe PF
Kopi Wharf
C1 Southcomplete
C2Complete
C1 HGCP
EPC4Hides Gas
Conditioning Plant
PNG LNG Project Overview
6.6 MTPA, 2 train development, operated by ExxonMobilOver its 30-year life, PNG LNG expected to produce over 9 tcf of gas and 200+ million barrels of associated liquidsInitial Equities:
ExxonMobil - 33.2% Oil Search - 29.0%Kroton2 (PNG Government) -16.8% Santos - 13.5% Nippon Oil - 4.7% MRDC (PNG Landowners) - 2.8%
Fully contracted to Asian buyers, with continuing strong market interest
Sinopec (China) ~2.0 MTPATEPCO (Japan) ~ 1.8 MTPA Osaka Gas (Japan) ~1.5 MTPACPC (Taiwan) ~ 1.2 MTPA
12
PNG LNG Project Overview
Main EPC contractors:LNG Plant: Chiyoda/JGCOffshore Pipeline SaipemHides Gas Plant CBI/Clough JVOnshore Pipeline SpiecapagInfrastructure McConnell Dowell/CCC JVEarly Works Clough/Curtain JVAssociated Gas (OSH only) Aker Solutions
Different labour environment to Australian LNG projectsFour-year construction period. First LNG sales expected 2014, capital cost US$15 billion
13
Milestones achieved in 1H 2011
Ground-breaking and pouring of first foundations at the LNG plant site
Commencement of welding and burial of onshore pipeline, continued clearing and stringing of pipe along the route
Construction of Caution Bay offshore pipeline support site
Completion of training facilities at Juni in Highlands
Continued early construction activities both in Highlands (incl. earthworks at Hides plant site and Komo airfield, road and bridge upgrades) and at PNG plant site near Port Moresby
Ramp-up in PNG workforce and use of PNG suppliers. Total workforce at end June of 9,300, of which 6,600 were PNG nationals (71%)
1414
Focus items for 2H 2011
Community engagement and downtime management
Working with new Government to ensure continued alignment and delivery of obligations
Wellpad and Hides spine road development
First stage of Associated Gas project at CPF (successfully completed)
Commencement of work on Kumul rejuvenation following completion of fabrication of new Single Point Mooring (SPM) for Kumul loading terminal
Onshore pipeline installation
Commencement of offshore pipelay
Continued progress at LNG Plant site
Rig mobilisation and arrival and site preparations
Strong A$15
Timetable
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2010 2011 2012 2013 2014
FinancialClose
•Complete pipe lay•Ongoing drilling•Complete Hides plant•Commission LNG plant with Kutubu gas
•Ongoing procurement and mobilisation
•Airfield construction•Drilling mobilisation•Start offshore pipeline construction
•Onshore line clearing and laying
•Start LNG equipment installation
•Continued early works•Detailed design•Order long leads and place purchase orders
•Open supply routes•Contractor mobilisation•Commence AG construction
First Gas from Train 1,
then Train 2
•Complete AG •Continue onshore pipe lay
•Complete offshore pipe lay
•Start Hides plant installation
PNG LNG Project– Onshore Pipeline Construction
17
Completed Mubi River crossing
Kopi Scraper Station
Pipeline stringing, onshore pipeline
PNG LNG Project– Onshore Pipeline Construction
18
Pipe Lowering-in
Pipe Welding
Firstweld
PNG LNG Project
19
Drilling Rig 702 -Ribbon cutting ceremony, Houston Texas
Hides Conditioning Plant -Pioneer camp construction
PNG LNG Plant Site
20
February 2011
July 2011
PNG LNG Plant Construction
21
Marine jetty piling
Process pipe rack construction
Gas Growth and Exploration
Key strategic priority for Oil Search is to grow gas business in PNG
Pursuing two pronged strategy:PNG LNG Expansion
Gulf Area LNG
PNG near field oil exploration
High graded exploration outside PNG
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Drilling Programme
Embarking on one of the largest drilling programmes ever undertaken, starting 4Q11 continuing through 2012, into 2013
Multi-TCF risked potential for gas and several hundred millions of barrels of oil potential
Appraisal and development drillingHides
P’nyang
Kutubu, Moran and likely Mananda
ExplorationTrapia (PRL 11)
Near field oil exploration
Gulf Area drilling, subject to final seismic results
Taza, Kurdistan
Potential to underwrite continued gas commercialisation and short-medium term oil production
2323
PNG LNG Expansion
Integrated exploration and appraisal drilling programme in the HighlandsResults by mid/late 2012Upside in Associated Gas fields:
Detailed evaluation ongoing by Oil SearchTargeting alignment with PNG LNG Co-Venturers in 2012
Hides Gas Water Contact Well:Hides development drilling scheduled to commence in late 2011, Gas:Water Contact well planned early in drilling sequenceOptimisation with logistics and construction (Komo and HGCP)
P’nyang and Trapia (formerly Huria) wells targeted for 4Q11 and 1Q12 spud respectively
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Kumul Terminal
Port Moresby
7°S
Juha
PRL08
PPL240
PRL11
PDL7
PPL239 PDL1
PRL02
PDL2
PDL4PDL3
PRL09
PDL6
PDL5
PRL14
PPL260
APPL249
APPL250
233
PDL9PDL8
PPL233
APPL386
PPL219
LNG Facility
Gulf Offshore
6°S
8°S
9°S
PRL01
PPL234
PRL10
PPL244
Kiunga
Kundiawa
Mt. Hagan
Mendi
Kerema
Pandora
SE Mananda
Uramu
100km
Madang
Daru
Wabag
Gobe
PPL276
PPL338
338
338
338
PPL339
339
339
339
PPL339
339
PPL312
339 339
PPL260
Kopi Wharf
145°E 146°E144°E143°E 147°E
Kimu
PRL3
APPL385
240
240
V.
PNG LNG Expansion
25
Lae
LEGEND
Oil Field
Gas Field
Prospect
Oil Pipeline
Proposed Gas Pipeline
Major Road
P’nyang
Mananda 5 Kutubu, Agogo & Moran
Gulf Onshore
Hides
ExplorationGas Resources
PNG LNG ProjectGas Resources
Non PNG LNG Gas Resources
Barikewa
AngoreKomo Airstrip
Hides GasConditioning Plant
Elk/Antelope
Trapia
PDL 1, PDL 7 and PDL 8Hides & Angore
26
Hides Nogoli Camp
GTE PL 1 Hides GTE Plant
PDL 1 – Hides Field8 New Wells
Drilling 2011+
36.81%16.66%24.03%20.50%2.00%
PDL 1ExxonMobilOil SearchSantosPNG GovtGas Resources Gigira Ltd.(L/O)
36.81%40.69%20.50%2.00%
PDL 7ExxonMobilOil Search PNG GovtGas Resources Hides No.4 Ltd.(L/O)
36.812%40.69%20.50%2.00%
PDL 8ExxonMobilOil SearchPNG GovtGas Resources Angore Ltd. (L/O)
PDL 7 – South HidesHides Gas Conditioning Plant
Construction 2012/13
PDL 8 – Angore Field2 New Wells10km
PNG LNG Expansion
P’nyang (PRL 3) ExxonMobil 49%, Oil Search 38.5%, JX Holdings 12.5% Appraisal well scheduled for 4Q11Targeting southern fault block Aim is to move 3C to 2C and increase 1C resourcePotential 2C of ~2 tcf
27
Kumul Terminal
Hides
Kutubu
P’nyang 100km
SE Gobe
7°S
6°S
8°S
145°E144°E143°E142°E
Moran
Agogo
Juha
Angore
PNG LNG Expansion
28
Trapia 1 (PRL 11)Oil Search 52.5%, ExxonMobil affiliates 47.5% Exploration well scheduled for 1Q12
Series of prospects in area:
Reasonable seismic but structural uncertainty remainsMulti-tcf potential in areaPartial dependency. Exploration potential remains in event of success or failure at Trapia
Kumul Terminal
Hides
Kutubu
PRL11
10km
SE Gobe7°S
6°S
8°S
145°E144°E143°E142°E
Moran
Agogo
Juha
Angore
Gulf Area LNG Opportunity
29
PPL260
Kumul Terminal
PRL01
PPL234
PRL10
9°S
145°E 146°E144°E
Pandora
Gobe
Uramu
PPL276
PPL312
PPL338
PPL339
PPL339
339
339
338
338
338
339
339
339
3398°S
7°S
339
PPL244
50km
3D Seismic Regions
3D Seismic Regions
2D Seismic Lines
2D Seismic Lines
Multi-licence, multi play type, multi well opportunity being developed
Large, modern 3D seismic dataset acquired to unlock potential of Gulf
Processing of data almost all complete and being interpreted. Results of initial interpretation are encouraging
2D onshore in PPL 338 and 339 complete and being processed
Rig options and timing being assessed
Long lead item procurement process commencing
Elk/Antelope
Flinders
Gulf Area LNG Opportunity
Prospectivity:Targeting 4Q for initial assessment of prospectivity across all licencesFinal views by year end
Partnering:Discussions initiated and ongoing with potential strategic farm-in partners
Drilling:Planning ongoing:
Well design commencedLong lead item procurement process commencedSite survey planning Rig selection and sourcing discussions ongoing
Timing:Targeting 2012. Timing dependent on:
ProspectivityRig selection and availabilityStrategy selected Status of partnering discussions
30
31
Analogue Comparison Kokomo Prospect - Gulf of Papua vs.
Sequoia Field - Nile Delta
6 km
Sequoia FieldNile Delta, Offshore Egypt
British Gas9Tcf
Kokomo ProspectGulf of Papua, PNG
Oil Search
Sediment flow-direction
ChannelSands
High Amplitude Anomalies
32
Kokomo Prospect Reservoir Lower Channel
6 km
Amplitude HL
Map view of horizon slice
Kurdistan - Taza PSC
PSC signed after exercising Option Agreement
Oil Search entry as Operator in extremely active Kurdistan Region of Iraq
Very prospective location adjacent to three fields
Large, simple 4-way dip closure identified from 2010 seismic
Well scheduled to spud in 1H12
3333
TazaProspect
Kor MorGas Field
PulkhanaOil Field
JamburOil Field
Tunisia
2010 seismic evaluation completeLarge structures mappedProven plays present and new deep gas play developedPrime prospect in Tajerouine permit has potential for >100 mmstb oil and >400 bcf gasFiscal regime favourable
Prospect sizes commercially attractive
Exploration well in Tajerouine to be drilled in late 2012
3434
~10km
35
Oil Search Production
2008 2009
8.607.66
2010
8.12
2011
6.2-6.7
2012 2013 2014 2015 2016 2018
25Net Production (mmboe)
0
5
10
15
20
MENAHides GTESE ManandaSE GobeGobe MainMoranKutubu
2017
2011 Production Outlook
Production in 1H of 3.56 mmboe, solid performance with underlying production from oil fields generally consistent with expectationsGas injection well at Usano, UDT 13, drilled successfully. Providing support to key production well in Usano EastIDT 25 development well successfully drilled in Kutubu Main Block Toro:
Good indications of hydrocarbons in Toro reservoirWell deepened to exploration target in Koi Iange horizon, with hydrocarbon indications - will be flow tested in 4Q11
2H11 production will be impacted by:Two week shutdown for tie-in of Associated Gas facilities (successfully completed)Natural declineRepairs to HP compressor at APF
Workover programme using the Hydraulic Workover Unit (HWU) underway at GobeFull year estimate remains consistent with guidance (6.2 – 6.7 mmboe)Production out to first LNG broadly flat, subject to success of work programmes
36
Near Field Exploration
Detailed review of “near field” exploration potential in and around existing producing fields as part of 2010 strategic reviewMore than 25 opportunities currently identifiedPotential:
125 mmboe net (approximately half oil, half gas)
Higher risk than historical development drilling:Difficulty imaging Untested reservoir properties Complex geology
Risk management:Integrating with existing pads and wells to reduce costFall back of safer, conventional proven targetsStep wise approach, building out from known positions
37
38
Near Field Exploration
Focused on:Deeper Koi-Iange play:
Potentially underlies all producing reservoirsPenetrated by IDT 25, due to be tested in 4Q 2011
Forelimb play:ADT 2 look alikes Currently drilling Hedinia 10 forelimb Agogo 6 well in 4Q
38
Footwalls Forelimbs
Deeper targets e.g.Koi Iange
Play extensions:Based on detailed remapping and 2011 seismic Potentially SE Mananda and Kube Kabe(north of Kutubu)
Footwall targets:Hedinia, Moran, Mananda
2H11 Drilling Activity
39
Hedinia 10 targeted ADT2 lookalike forelimb structure under producing Hediniafield within Kutubu. Well found thin oil column in Toro reservoir, successfully proving structural model. Well now being sidetracked updip to appraise size of discoveryAgogo 6 is follow-up to ADT2 targeting Agogo Toro forelimb and extent of Digimuforelimb
AgogoForelimb
HediniaForelimb
ST1
ST2
ST3
2011/12 Development & Near-Field Appraisal Drilling Activity
40
PRL08
PPL240
PRL11
PRL12
PPL239 PDL1
PPL233
PPL219
PRL02
PDL2
PDL5PDL6
PRL09
PRL14
PPL260
APPL386
PDL4
PDL3
PDL4
PRL12
50km
AngoreJuha
Hides
SE Mananda
Barikewa
Kimu
Cobra
Iehi
PPL240
PPL233
APPL350
6°S
143°E 144°E
7°S
Usano:2011 : 1 well, 1 workover2012 : 1 well
Kutubu:2011 : 1 well, 1 workover
Agogo:2011 : 1 well2012 : ±1 well
Moran:2012 : 1-2 wells
SE Gobe:2011 : 3-4 workovers
Gobe Main:2011 : 1 workover
Mananda 5
41
2H11 Focus Areas
Maintain OSH’s industry-leading safety performance in high activity environment
Strong commitment to cost effectiveness
PNG LNG Project commitments driving operational developments:
Deliver the Associated Gas Project as planned
Improved reliability and long term integrity
Life extension programmes for facilities
Upgrade of key systems and processes
Enhanced development of personnel
Continued focus on capturing additional in-field and near field reserve opportunities
41
42
Mananda 5 Discovery
25 mmboe discovery, ~50:50 oil:gasConfirmed oil in Toro A, B & C Ambiguous in Imburu & Digimu Location application lodged with DPE
Subsurface, engineering and in-country issues evaluation ongoingDecision on development or further appraisal by end 2011
0 2 4 61 Km %,''''
1''''
ª
ª'ªª'''
ªªk
k
µY
ª'
ª''ªª'
''''' 'ªªªª'
ªªª'1'
11 '''
PDL 2
PDL 6 PDL 5
APPL 350
PPL 219
PPL 287
PPL 233
APFAHT 2
AHT 1ADT 2
ADT 1ADD 3
Moran 9
Moran 8Moran 6X
Moran 4X
Moran 14Moran 13 Moran 12
Moran 10
Moran 14AMoran 12A
Mananda 5
NW Moran 1
Mananda 4X
Mananda 3XMananda 2S
SE Mananda 5SE Mananda 4SE Mananda 3SE Mananda 2X
SE Mananda 1X
Mananda 3XST1
143°5'E143°0'E142°55'E
6°10'S
6°15'S
6°20'S
PotentialPipeline Route
0 2 4 61 Km
SE MANANDA
MORAN
AGOGO
PNG Operating Environment
PNG has built enviable investment record of fiscal stability in resources sector over past 15 years
Unprecedented investment now taking place in oil, gas and mining, encouraged by attractive fiscal policy and stability
History of constructive dialogue between industry and Government to manage issues and expectations
Anticipate that this will continue with new Government, led by Prime Minister Peter O’Neill
43
PNG Operating Environment
Rapidly changing economic and social landscapeChanges in traditional tribal culture
Increased expectations and opportunities
Education and communications
Focus on improving benefits distribution system, transparency and service delivery
Strong support from landowner leaders and key institutions
44
Managing Operating Risk
Oil Search has increased its focus on managing in-country issues
Seen as key way to mitigate operating risk
Expanded Sustainability Group is focusing on:Government/regulatory
Promoting transparencySovereign wealth funds Supporting benefits distribution processProviding support to PNG Government bodies, when appropriate
Relationship building between Government, Landowners and other businesses
Oil Search Health Foundation:Expanding the successful OSH model for health programmes to other areas of PNGNominated as Principal Recipient for grants from The Global Fund to deliver HIV and malaria programmes
4545
Summary
Delivery of PNG LNG underway:
Robust project
Outside crowded Australian LNG space, conventional onshore gas, limited technical risks
High quality Operator, making good progress towards first sales in 2014
Largest ever drilling programme
Oil fields generating strong cash flows. Production impacted by associated gas construction in 2H, but expect production to remain flat in 2012/13 despite field maturity
PNG challenging environment, increased focus on managing risk
Balance sheet remains strong, ample liquidity to meet LNG obligations and to mature expansion activities
46
47
Appendix
2011 Full YearGuidance Summary
Production:6.2 – 6.7 mmboeSimilar performance in 2012 and 2013, subject to success in planned work programmes
Operating costs US$19 - 21/boe (incl corporate costs)Impacted by:
Lower production volumesMajor workover programme to maximise oil recoveriesbefore gas productionFOREXPNG inflation Associated Gas activitiesSustainability initiatives
Depreciation, depletion and amortisation:US$7 - 9/boe
4848
49
2011 Capital Outlook Update
49
US$’m
Investing :Exploration inc gas growthPNG LNGProductionCorporate (inc rigs)
Financing :Dividends
* Dividend fully underwritten
160-180
1,200-1,400
130-150
10
0*
2011
110-130
600-800
70-90
7
0*
2H 11
54
595
57
3
0*
1H 11
50
Other Key Players in PNG
Talisman and Sasol have significant acreage in Western Forelands. InterOil has strong position in Eastern ForelandsOSH strategy focused on core PNG LNG Foldbelt acreage and Gulf - viewed as offering greatest potential for large gas discoveriesPort Moresby
8°S
6°S
146°E142°E
Juha
100km
Hides & Angore
Gobe
Kutubu & Agogo
Petroleum Licences
Oil Search Equity Participation
Port Moresby100km
Juha
Gobe
Kutubu & Agogo
Hides & Angore
8°S
6°S
146°E142°E
Talisman Equity Participation NGE & Interoil Equity Participation
NGE
Interoil
Port Moresby
Juha
Gobe
Kutubu & Agogo
Hides & Angore
8°S
6°S
146°E142°E
100km
DISCLAIMER
While every effort is made to provide accurate and complete information, Oil Search Limited does not warrant that the information in this presentation is free from errors or omissions or is suitable for its intended use. Subject to any terms implied by law which cannot be excluded, Oil Search Limited accepts no responsibility for any loss, damage, cost or expense (whether direct or indirect) incurred by you as a result of any error, omission or misrepresentation in information in this presentation. All information in this presentation is subject to change without notice.
This presentation also contains forward-looking statements which are subject to particular risks associated with the oil and gas industry. Oil Search Limited believes there are reasonable grounds for the expectations on which the statements are based. However actual outcomes could differ materially due to a range of factors including oil and gas prices, demand for oil, currency fluctuations, drilling results, field performance, the timing of well work-overs and field development, reserves depletion, progress on gas commercialisation and fiscal and other government issues and approvals.
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