080319 strategy review total final - oil search · 2017. 1. 22. · 5 2002/03 review ¬oil search...
TRANSCRIPT
1
Strategic Review: The Way Forward
March 2008
O I L S E A R C H L I M I T E D
2
Agenda
9:00 Welcome Brian Horwood
9:05 Strategy Overview Peter Botten
9:30 PNG LNG Bob Marcellus
9:50 Financing Nigel Hartley
10:00 PNG Oil Field Optimisation Phil Bainbridge
10:15 Break
10:30 Growth Austin Miller
- PNG Gas growth Bob Marcellus
- PNG Exploration Keiran Wulff
- MENA Portfolio management & exploration Keiran Wulff
11:45 Summary & Questions Peter Botten
12:00 Close
3
Welcome
Brian Horwood: Chairman
4
Strategy Overview
Peter Botten: Managing Director
5
2002/03 Review
Oil Search last conducted a major strategic review in 2002/03. At the time:
− Oil Search’s market capitalisation was ~A$800m− Primary oil assets in decline, due to lack of investment by
Operator− Despite high equities, Oil Search did not control activities
− There were tight financial constraints− Gas commercialisation a focus in a lower price regime - oil
US$30/bbl, gas A$3.00/mcf domestic, US$3.30/mcf international
The implementation of the 2002/03 recommendations, which included taking over operatorship of the PNG assets, was instrumental in the Company's top quartile performance over the past five years
6
Share price out-performance
0
100
200
300
400
500
600
700
Jul-02 Jan-03 Jul-03 Jan-04 Jul-04 Jan-05 Jul-05 Jan-06 Jul-06 Jan-07 Jul-07 Jan-08
OSH ASX 200 ASX 200 Energy
July 2003: Acquisition of Chevron’s PNG Interests
Oct 2004 : PNGGP enters FEED
July 2005: Announcement of AGL GSA and PNGGP equity sale
April 07: Signs Cost Sharing Agreement for LNG project
Aug 2006 : APC withdraws from Australian leg of PNGGP Pipeline
7
TSR Performance
Source: Merrill LynchSource: IRESS
Ranked No.5 TSR Performer amongst current ASX 100 for 5 year period to Dec 2007
53%
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20%
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8
2007/08 Review Environment
The 2007/08 strategic review has taken place in a significantly better environment, but with equal, though different, challenges:− High oil and gas price regime with oil price
>US$100/bbl, Australian East Coast domestic gas price A$4.50/mcf, international gas price US$11.00 mcf plus
− Much higher industry costs, with little evidence of diminishing inflation
− Oil Search controls investment in PNG oil assets− ExxonMobil driving PNG LNG but Oil Search can
influence and add value through oil/gas synergies and PNG landowner management
9
Priority given to ensuring strategic analysis and planning based on best available dataReview of external operating environment
Independent Technical Review undertaken by a range of experts:− PNG production & development programme − PNG exploration− MENA production, development and exploration
Followed up by in-house technical work− Prospect and lead inventory review− Long term oil fields sustaining capital review
Gas Commercialisation Review− Scoping economics completed for multiple development scenarios
based on probabilistic reserve assessments− Infrastructure capacities reviewed
Strategic Review Process
10
Strategic Review Process
Cost Review− In depth historical field, drilling and corporate
operating cost reviews undertaken
Organisation− PNG field organisational / operational structure
review − Organisational effectiveness review
Stakeholder Management− ExxonMobil influence and capacity to add value− PNG Government
11
Key Conclusions of Review
Existing portfolio can deliver superior TSR
Substantial unrealised value exists within Oil Search’s current asset portfolio, capable of generating superior shareholder returns over next five years and beyond
Delivery of PNG LNG alone can deliver 15% plus annual TSR growth with upside exposure to higher commodity prices. PNG LNG is the key future value driver
Further value growth can be delivered through commercialisation of other gas resources. Positioning for longer term growth above initial LNG Project through second phase gas developments is required
Value of PNG gas will increasingly dominate the portfolio over timeDec '07 Dec '08 Dec '09 Dec '10 Dec '11 Dec '12 Dec '13
“Delivering PNG LNG is the Highest Priority”
Oil & Other
PNG LNG
Valu
e
Other Gas
12
Gas Commercialisation the Key to Growth PNG LNG will dominate− A robust economic project ranking well
relative to other possible developments− ExxonMobil led, with strong alignment and
commitment− OSH can add value through:
− In-country contributions− Landowner and stakeholder management− Government and financing coordination−Oil fields gas delivery and synergy development
− Further growth definition
Key Conclusions of Review
13
Management of Cash to Fund LNGFinancial position is strong (net cash of ~$415 million in March ’08)
However, funding of PNG LNG capex (OSH share ~US$3bn) will consume a large proportion of operating cash flow over next 5 years, impacting availability of funds for other activities
Major focus effort to secure project financing. Latest market soundings have confirmed that despite current credit crunch, project financing for PNG LNG is available. Equity funding for PNG LNG will be sourced from a combination of:
− Existing cash balances
− Future operating cash-flows
− Oil financing facilities
Discretionary expenditure will require close management
Hedging and other levers available
Active capital prioritisation across portfolio of opportunities
Key Conclusions of Review
14
Gas Commercialisation the Key to GrowthOther gas developments a priority− Comprehensive strategy to drive growth
− Reserve aggregation through acquisition− Exploration emphasis− Infrastructure and development− Partnering with PNG stakeholders− Range of development opportunities
Significant value can be derived from discovered gas resource in 2008-2012 time frame
Key Conclusions of Review
15
Optimise Cash Generation from Oil FieldsPNG oil is essential part of Oil Search’s business - provides cash flow required to fund LNG development
Easy wins from PNG oil fields have largely been captured, butLife of Field studies have shown that substantial upside potential still remains
− Underpins development programme 2009 & 2010
− Target – to maintain gross PNG production at between 40,000 –50,000 bopd until 2011
A number of initiatives have been identified to enhance cash flow generation progressively from 2008 and beyond with focus on:− Drilling performance and capital costs
− Appropriate cost base (fit for purpose)
Key Conclusions of Review
16
Re-focus MENAOil Search has successfully built up diversified, value accretive portfolio in MENAExploration activity to date has been disappointing and materiality of some of the licences in context of growing gas portfolio is an issue
Some MENA assets offer the potential to provide a material diversified revenue stream outside core PNG operations
Rationalisation of MENA portfolio is required to release cash and reduce future capital and exploration expenditure commitments, refocus on assets with required level of materiality
MENA portfolio and equity levels to be pro-actively managed on an on-going basis with potential to deliver high materiality regularly assessed
Key Conclusions of Review
17
Exploration an Important Contributor to GrowthIndependent review of portfolio highlights potential for material oil and gas contribution in review period
PNG Highlands potential will be tested. Offshore areas have material gas potential
MENA portfolio management concentrating on material prospects
Strong competition for capital with comprehensive ranking process
Programme of active equity management to optimise equity, risk and capital expenses. A trading mentality
Key Conclusions of Review
19
Achieve superior value growth performance versus peer group, over the next 5 year period by:
• Ensuring PNG LNG project approves FID
• Optimising PNG operating performances to sustain production and cash-flows to first gas
• Managing the MENA portfolio to divest non-material interests & improve short term cash flows
• Positioning OSH with material growth opportunities post LNG Project FID
Maximise operating
performance
Objectives:
Value Drivers:
1. Production optimisation
2. Opex reduction
3. Drilling costs, Rig fleet management
12.PNG Government (support for risk, growth strategies)
13.IPBC Relationship- financing- support for risk, growth strategies
14.DPE Relationships-operations
4.Deliver LNG Project Sanction
5.Incremental PNG Gas Commercialisation accumulation
6.Pursue selective material new ventures
7.Pursue measured exploration programme
9.LNG Project debt strategy and associated initiatives
10.Sell down non material MENA positions
11.Optimise equity levels in exploration licences
15.Structure management accountabilities around priorities
Key Conclusions of Review
Growth deliveryOptimise
Financing and Capital Structure
Maximise influence on key
decisions
Align Organisation to
deliver
18
OtherStakeholder Management− OSH can add value and mitigate risk by
active stakeholder management in PNG− Government and bureaucracy− Partnership with Government instrumentalities− Landowner and community management
Organisation to Optimise Strategy Delivery− Organisation being modified to align to
specific strategy initiatives− Reorganisation impact “Fit for Purpose”
Key Conclusions of Review
20
Focus Areas for Growth
Gas will dominate− PNG LNG first phase growth− Other gas – strategy to develop expansion
opportunities and other projects
Exploration− Material prospectivity remains in PNG portfolio for oil
and gas− MENA portfolio management, with remaining
potential− Active licence trading to optimise equity, risk and
capital exposure
New Business− Continued measured new business activities
concentrating on medium term material contribution
21
PNG LNG Project
Bob Marcellus : Executive General Manager
– Gas
22
Primary driver is to deliver PNG LNG
PNG LNG Project is Oil Search’s primary focus
This development will represent PNG’s cornerstone gas development and will underpin Oil Search’s production and profits for 30+ years
PNG LNG will commercialise over 500 mmboe of Oil Search’s 2P gas resources
Initial development will add ~ 18 mmboe to annual net production
23
Gas Evolution in PNG
For 10 years, PNG to Queensland gas pipeline dominated
When APC faltered in 2006, OSH re-assessed its options
Asian LNG markets had strengthened considerably− Both ExxonMobil and BG seriously interested in PNG LNG− Strong interest from other parties (as participant or buyer)
In January 2007, work ceased on pipeline project, focus turned to LNG
In April, Oil Search joined ExxonMobil to study Hides LNG
In July, Oil Search led Kutubu oil projects into the study
12 months later, ExxonMobil-led PNG LNG Project is FEED-ready− Validates the move to LNG− Paves the way for material growth for Oil Search − Promises a cornerstone gas development for PNG, underpinning GDP
growth
24
PNG LNG Project
25
PNG LNG Project Status
PNG LNG Project is poised to enter FEEDMilestones already reached:
Commercial alignment (JOA) amongst the Project OwnersInitial funding interests pre-Government back-in (Oil Search 34%) Unitisation and agreed redetermination proceduresMarket Representation Agreement & joint marketing of 6.3 mmtpaEndorsed Marketing Plan, Project rolled-out to buyers at GasTechPre-FEED work and updated capital costs; competing technologiesExxonMobil’s and Oil Search’s validation of FEED readinessAgreement on effective oil field interface with LNG
Closure on Gas Agreement issues still outstanding
26
Project Interest Determination
1.2%
1.8%
3.6%
17.7%
34.1%
41.6%
Share of FEED costs
MRDC / State
Nippon
AGL
Santos
Oil Search
ExxonMobil
JV Partners
Methodology agreed for Project Interest determination
Initial Project Interests will be established at FID, taking into account FEED work and actual LNG revenue streams
Periodic re-determination and equalisation processes established
Government has the right to back-in (22.5%) to Hides, Angore and Juha licences
Resulting State participation in PNG LNG Project post back-in, approximately 19%
26%
28%
30%
32%
34%
36%
FEED Interest
PN
G L
NG
Inte
rest
OSH expected post Government back-in final project interest
Oil Search PNG LNG Interest
27
PNG LNG Capex Estimate
ExxonMobil historically has delivered projects on time & on budget First phase capex (2008 – 2014) expected to be between US$10 –11bn (real 2007)Subsequent capex is several years out (additional Hides drilling, Juha development and potential LPG extraction if required) Juha timing depends on Hides and Angore outcomes & performance Further updates to capex estimates from EPC bidsFurther optimisation will occur during dual FEED
Source: ExxonMobil Analyst Briefing 5th March, 2008.
28
Schedule
Milestones: − JOA signed - March 08 − Gas Agreement target signing - end March 08 − FEED entry following Gas Agreement− Financing Information Memorandum – 4Q 08− Buyer support (HOA’s / SPA’s) – 2008/09− EPC bids – 2Q 09− FID - 4Q 09− Financial Close - end 09− Target first LNG cargo - end 2013
29
PNG LNGA Robust Project
PNG LNG Project
− LNG demand & prices remain strong
− Certified reserves are in place (2P - 9.5 TCF)
− Well-placed geographically to capture Asian markets
− Acceptable Project Economics
− Alignment amongst the participants
− Project compares well with regional competition
− Competing projects face their own hurdles and alignment issues
− Additional Oil Search value arises from our positioning
− Leveraging oil fields
− Future gas growth potential
30
Oil Search’s Unique Contribution
Oil Search is well positioned to play its part in PNG LNG delivery:
− Supportive Joint Venture participant
− In-country expertise, well connected, well respected
− Supporting ExxonMobil on:− Landowner Benefits Sharing Agreement− Business Development opportunities− Training and localisation− Providing in country project management skills
− Financing:− Coordinating key parts of the project debt finance process with
ExxonMobil − Co-ordination with Government for equity funding options
− FEED on gas-related Oil Field facilities− Optimise oil and gas synergy value within the gas delivery obligation
31
Economic Importanceto PNG
ACIL Tasman Report 6 February 2008− “Affects economy of PNG and its balance of trade situation
profoundly”− GDP will more than double − Oil & gas exports increase 4 fold− Up to 7,500 jobs in initial phase, 20% by nationals; 850 full
time positions, developing national workforce over time− Huge cash flows to Government – national and provincial -
and landowners through tax, royalties, levies and equity participation
Builds initial infrastructure for national gas developmentCreates an industrial precinct near Port Moresby Step change for PNG’s credibility internationally
32
Capturing PNG LNG
FEED entry in the near term is highest priority
− 1Q 2008
Thereafter focus shifts to achieving Sanction in late 2009 by:
− Securing market off-take
− Securing debt and state equity funding
− Achieving agreements on benefit sharing
Operator’s efforts will be complemented by Oil Search experience and skills
− Delivering Oil Search’s component of the upstream FEED
− Optimising value between the oil fields and gas fields as the oil fields operator within the parameters of the gas supply arrangement
33
Road to Sanction
Project fundamentals are positive:− ExxonMobil has publicly stated PNG LNG is one of 2
regionally important projects− JV is aligned on delivery − Project is economically attractive − Host country is supportive− Well positioned against competing projects− Strong LNG market
Challenges can be managed and include:− Cost control/optimisation− Benefits Sharing Agreement across a range of
community interests − Financing likely to be critical path
34
PNG LNG ProjectFinancing
Nigel Hartley : Chief Financial Officer
35
Financing Objectives
Ensure LNG debt funding is maximised and achieves:− Competitive terms− Minimal recourse to Oil Search− Alignment with State financing objectives− Offtake leveraged− No delay to financial close
Ensure LNG equity funding is met “optimally”− Preserve cash flow via focussed cash management and
allocation of funds− Leverage balance sheet via oil refinancing− Utilise hedging if required to protect cash flow and
optimise borrowings
Avoid recourse to the market
36
PNG LNG Debt Financing Plan
Project has settled on joint financing approach, led by a Finance Committee, co-ordinated by ExxonMobil, with key input from Oil Search and other parties based on respective skill sets and experience
Joint financing provides strong security package for lenders as ties up whole project under one borrowing entity, as well as fully co-ordinated approach to debt markets
Credit quality of rated sponsors improves blended project risk and should translate into lower borrowing costs, better covenants, reduced sponsor recourse and maximised borrowing
Extremely strong alignment across all JV partners will also present united front to lenders and optimise result
37
PNG LNG Debt Financing Approach
Joint debt requirement likely to be around US$9.9 billion nominal (OSH share around US$2.9 billion)
Potential funding sources will include classic ECA loans; untied ECA loans; bank debt, both covered by political risk insurance and uncovered; partner co-lending; and potentially debt capital markets
Updated view on capacity from advisors and sponsors, notwithstanding current credit crunch, indicates more than sufficient capacity to meet debt requirement
Majority of funding likely to come from “sovereign sources” not impacted by sub-prime; and transaction being in right region and funding the right commodity, supported by old fashioned repayment mechanisms - eg reserves and committed long term LNG contracts -further validates advisors’ view of capacity
38
PNG LNG Debt Financing Timeline
Joint Finance Plan now approved by LNG Operating Committee
Plan will be actioned with effect from 1 April, 2008
Approximately 18 months required to execute, including development of standard terms, presentations, and negotiation of documents with banks, PRI providers, and ECAs
In parallel will initiate rating agency discussions with a view to obtaining a rating in the event a debt capital market issue is pursued
Finance plan completion not strictly on critical path but interdependencies with marketing, contract and procurement strategy and environmental plan will drive to a 4th quarter 2009 final investment decision, with financial close to follow early in 2010
39
PNG LNG Equity Plan
Current debt strategy aims to maximise debt, leaving US$1.0-US$1.3 billion to be injected as OSH equity contribution
Based upon current modelling, OSH is targeting to meet equity requirements from existing cash (US$415m), oil cash flows, and “corporate” borrowing from oil base refinancing
Key levers include judicious cash management and oil price hedging, supported by cost optimisation and other levers
Modelling based upon reasonable oil price estimates (well below current forward curve). If necessary, cash flows may be secured by appropriate oil price hedging, which may also be utilised to enhance oil base borrowing
40
Oil Refinance
Current oil facility of US$42m following expiry of 4 year US$100m revolver on 31/12/07Target approximately US$400m facility to be negotiated on club basis around mid April, with closing around mid yearMarket soundings indicate adequate capacity despite current liquidity issues – Project is in the right region and the right industry with excellent long term bank relationshipsWhilst margins have increased, Oil Search’s reference point is a 2003 financing. When combined with lower US$ LIBOR base rates, expect improvements compared to existing termsIntent will be to optimise (“refinance”) facility after two years, if necessary with use of hedging to improve bankers’ oil reference price
41
PNG Oil Operations
Phil BainbridgeExecutive General Manager
- Operations
42
Providing Cash for Growth
Primary objective for oil operations:
To optimise PNG oil cash generation over the next 5 years to support PNG LNG Project funding requirements, by balancing work programmes, production outcomes and efficiency measures while maintaining our safety performance and reputation as a competent Operator
43
Oil Operations - Context
Excellent safety record
Good relationships with stakeholders (Landowners, Government, NGO’s)
Existing oilfields are mature (decline rate of ~20%)
− Track record of adding reserves and value− 2008 programme delivers 2P resource base “plus” and
is commercially robust− 2009+ programme to target incremental reserves in
excess of 2P
Significant cost pressures
− Need to reduce drilling costs and operating costs
The oil / gas interface creates value. Risks need to be managed
44
PNG Oil Field Reserves(OSH Net)
Oil Search’s own 1P and 2P estimates are similar to those independently estimated by NSA, although Oil Search believes there may be some additional upside from the 2008 well programme in Kutubu
During Strategic Review, undertook Life of Field (LOF) studies. LOF reserves are based on high graded contingent resource estimates which have not been included in the NSA 1P/2P reserves figures
65.757.937.7TOTAL
0.30.20.2Gobe Main
2.51.71.2SE Gobe
0.81.30.8SE Mananda
32.229.917.5Moran
29.924.918.0Kutubu
Life of Field2P1P
Oil Search (Risked)Netherland Sewell & AssociatesRemaining Reservesfrom 31/12/07
(mmstb)
PNG Gross Oil Production
0
10,000
20,000
30,000
40,000
50,000
60,000
70,000
80,000
2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012
Oil
Rat
e (b
opd)
PNG Oil Actuals Base Hides GTE Fcst 2008 Program Life of Field Hides GTE Actuals Decline Before OSL
Oil Searchtakeover
operatorship
Added over45mmstbcompared
to Chevron
P50ContingentResources-
LOF
P50 2008Programme
HidesGTE
P50Base
46
Production Forecasting
Base forecast from existing wells & facilities. Assumes uncertainty in :•Reservoir behaviour•Well performance•Facilities efficiency
Incremental production from a “hopper” of opportunities (contingent resources) high graded on commercial and technical input
Forecasting tool statistically samples options taking into account dependencies
Incremental production based on a firm new capital. Assumes uncertainties in •Contribution•Schedule
P90P50P10
P90P50P10
P90P50P10
47
PNG Net Production (LOF)
20206090140Approximate Net Capex (US$M)
1 sidetrack
1 well
1 sidetrack
4 wells6 wells
2 sidetracks
9 wells
14 workovers
Activities
Kutubu
Moran
Gobe Main
SE Gobe
SEM
Hides GTE
0
1,000
2,000
3,000
4,000
5,000
6,000
7,000
8,000
9,000
10,000
2008 2009 2010 2011 2012
NET P
rod
uct
ion
(M
stb
)
48
PNG Oil – Capex
Context:− Majority of oil business capex is drilling and workovers
− Need to reduce capex through drilling performance improvements, drilling cost reductions, new technologies and optimised rig strategy
− Transition continues through first half 2008
Initiatives:− Rigorous cost control of contracts, materials and logistics
− Improvements in contractor performance culture
− New technology:− Rig 103 and 104 with leapfrog capability− Hydraulic workover unit to provide lower cost workover and
“incremental” drilling capability− Rig strategy:
− Requirement for 2 rigs per year− Actively working with other Operators in PNG− Rig 103 and 104 preferred option:
− Efficiency gains − Standardisation benefits− Flexibility
49
PNG Oil - Opex
Focus areas for cost reduction:
Organisational Review:
− Remove duplication and minimise support costs
− Improve accountability and speed of decision making
− Promote ongoing localisation
Contractor Management:
− Continue to rationalise our contractor base to fewer longer term contracts
Work Programme:
− Continue rigorous discipline to ensure work is limited to that which is essential for production, reliability and reputation
PNG Controllable Costs / Barrel
0
1
2
3
4
5
6
7
8
US
$/
bb
l
Other
Marine
Telecommunications
Catering Services
Services & Fees
Fuels, Chemicals,Materials & Supplies
Transportation
Labour
50
Oil and Gas Interface
Context:
Oil Search remains operator of the oil fields and for the oil field component of the PNG LNG Project will manage:
− oil field FEED and construction
− on-going oil and gas operations
Oil Search will support ExxonMobil in certain areas:
− Community and Government interface
− Support for the Project Benefits Sharing Agreement (BSA)
− Secondees with relevant PNG planning and project execution expertise
51
Oil and Gas Interface
Value enhancing opportunities:
− Operating cost sharing
− Potential for reduced tax on oil production
− Incremental and revised pipeline tariffs
− Incremental condensate
− Abandonment deferrals
Risks to manage:
− Access to skilled staff (requires training plan)
− Landowner issues for the integrated project
− Simultaneous operations
52
Other Issues/Events
Extend Hides Gas To Electricity Contracts:− Porgera Joint Venture (PJV) keen to extend power supply contract beyond
2011
− Likely to maintain Hides Joint Venture and continue to sell gas to PJV power generation facilities
− Value upside and maintains stability of production operations during LNG construction phase
Abandonment Planning:− Gobe, SE Gobe and SE Mananda may require provisioning for abandonment
within next 5 years. Timing depends on:− Oil price, costs, LNG project, commercial terms
Facilities Life Extension:− Surveys have confirmed asset integrity of the pipeline, storage tanks and
production facilities
− 2007 programmes upgraded selected infrastructure (accommodation, supply base and mess facilities)
− Key focus for 2008/2009 is export loading system life extension project
53
Summary
Oil fields continue to generate strong cash flows, to be utilised for PNG LNG Project
Based on Life of Field studies, gross production expected to remain between 40,000 – 50,000 bopd through 2011, through both acceleration of production and new reserves
Capex required by oil fields expected to decline over next five years
54
Additional Growth
Austin MillerExecutive General Manager –
Commercial
55
Additional Growth Opportunities
PNG LNG Project delivery is Oil Search’s core growth driver
− A material, world class and organic source of growth for a number of years
The PNG LNG Project also sets the stage for additional growth opportunities and our approach to new investment
− Provides a base for second and third phase gas opportunities
− New opportunities need to be considered in a framework of being material for a US$5bn+ company
− Capital management approach dictates a disciplined approach on prioritising opportunities and optimising higher risk/high reward exposures
56
Additional Growth Opportunities
Incremental PNG gas aggregation and second phase gas commercialisation adds significant value− The highest value, lower risk opportunities for OSH− Builds on PNG LNG Project infrastructure − Builds on our existing strengths of licence positions, technical
understanding, capabilities and relationships− Prioritisation of opportunities to optimise long term gas position − Appraisal, exploration activity as well as acquisitions of static gas
Material and select exploration opportunities− Potentially high value, but higher risk exposure in PNG and
internationally − 2 main drivers
− Source of material incremental longer term growth − Financial discipline to deliver PNG LNG Project
− PNG LNG Project allows a different approach than most competitors
− Secure and then mature opportunities. Actively manage the portfolio through capex heavy PNG LNG Project development phase. Maintain material exposures
57
New Business
New Business activities tailored to complement core corporate strategy of growth through PNG LNG Project delivery
− “Equity is Gold” approach means Oil Search more a buyer than seller
Have reviewed opportunities to add pre-First Gas production
− There has been an active, but disciplined M&A search process
− Current environment challenging in face of strong competition for assets, high corporate share prices, value proposition against OSH value and prospects
− AGL sale process pre-emptive
Longer term potential to deliver growth through international expansion as PNG LNG Project progresses
59
Oil Search Vision
1st Phase Growth from Gas is secured by PNG LNG Project delivery
2nd Phase Growth from Gas adds material value
− From subsequent LNG trains/plants
− From gas diversification− Concurrent with pipeline completion− Capture smaller value projects− Other industries− Regionally − Including Domestic Gas projects
Oil Search will lead Phase 2 Growth from Gas and additional waves of gas development in PNG
60
Phase 2 Gas Growth:Strategic Review Activities
Strategic Review examined in detail the economic potential for secondary gas developments:
− Review of PNG gas prospectivity
− Economics across a range of field development and supply scenarios
− Configurations based on existing resources and identified prospects/leads
− Consideration of infrastructure synergies
− Need for alignment
58
Growth Through Gas
Bob MarcellusExecutive General Manager –
Gas
61
Phase 2 Gas Growth:Strategic Review Activities
Results highlighted:− Growth could come from subsequent Project LNG trains,
new LNG, petrochemicals supply, fertilisers and domestic gas opportunities in PNG
− Most valuable is an expansion train for PNG LNG project
− Gas resources outside the PNG LNG fields provide a platform for growth from gas for Oil Search
− Future growth requires a combination of gas aggregation and consolidation, exploration & appraisal, marketing, and development initiatives
62
Phase 2 Gas Growth:Strategic Review Activities
Strategic Review also highlighted:−Need for additional contractible gas
−Desirability of control (operatorship, preferred partners)
−Opportunity to add value by driving gas aggregation and consolidation
− Importance of government in infrastructure and broad gas development plan
−Need to deliver domestic gas development programmes
63
Oil Search will be the catalyst for Phase 2
Material value additions are available for Oil Search
Strong licence position across PNG
Gas resources outside PNG LNG dedications are significant (~400 mmboe net)
Opportunity to lead consolidation, alignment and E&A
Strong commercial and social drivers to deliver a range of industries
LNG infrastructure establishes accessibility
Experienced operator
Focused on aggregating gas and delivering multiple projects over time
Strong alignment with Government
Portfolio of partners and potential projects for PNG
64
PNG has a significant discovered gas resource base…
(Deutsche Bank Energy Seminars – March 2008)
Almost a third of the gas reserves are held in the Hides field (which has been producing a very small amount of gas since 1991)When the other fields that are earmarked to supply it are added in, the PNG LNG project accounts for approximately half of PNG’s discovered gas resource
Stanley0.1%
Barikew a4%
Pasca1%
Angore7%Juha
6%
P`nyang10%
Pandora A7%
Kutubu Area8.3%
Hides (Technical Reserve)
30%
Kimu4.8%
Elevala3%
Douglas3%
Elk3%
Ketu2.3%
Uramu2%
Gobe Area2%
Moran1%
Kuru1%
Koko0.1%
Bw ata0.3%
SE Mananda0.1%
Iehi1%
Pandora B2%
Hides (Technical Reserve) Kutubu Area AngoreJuha P`nyang Pandora AKimu Barikew a ElkDouglas Elevala KetuPandora B Uramu Gobe AreaMoran Kuru PascaIehi Bw ata KokoSE Mananda Stanley
Technical Reserves
0
1000
2000
3000
4000
5000
6000
Hid
es (T
echn
ical
Res
erve
)
P`ny
ang
Kutu
bu A
rea
Pand
ora
A
Ango
re
Juha
Kim
u
Barik
ewa Elk
Dou
glas
Elev
ala
Ketu
Pand
ora
B
Ura
mu
Gob
e Ar
ea
Mor
an
Kuru
Pasc
a
Iehi
Bwat
a
Tota
l Gas
Res
erve
s (b
cf)
PNG LNG Project (key fields)
PNG LNG Project
Technical Gas ~ 17,000 bcfTechnical Gas ~ 17,000 bcf
PNG LNG Project
Source: Wood Mackenzie Path Finder
PNG discovered gas reserves by field
65
150204225
771583829
1858
4844
390 269 325 274 229 243 227
35.8
0
1000
2000
3000
4000
5000
6000
7000
Oil
Sea
rch
Exx
onM
obil
San
tos
Inte
rOil
Cor
pora
tion
AG
L E
nerg
y
Talis
man
Min
istry
of E
con
Trad
e&In
dust
.
PN
G G
ovt (
MR
DC
)
Rift
Oil
PLC
Aus
tral P
acifi
c E
nerg
y
Nip
pon
Oil
Cor
pora
tion
Mos
aic
Oil
Cue
Ene
rgy
Res
ourc
es
Che
etah
Oil
and
Gas
Cai
rn E
nerg
y
Mer
rill L
ynch
Com
mod
ities
Tota
l Rem
aini
ng G
as (b
cf)
Technical Gas (bcf) Commercial Gas (bcf)
Source: Wood Mackenzie Path Finder (format amended by Oil Search)
Technical Gas ~ 17,000 bcfTechnical Gas ~ 17,000 bcf
PNG discovered gas reserves by company
Wood Mackenzie estimates of gas ownership in PNG
(Deutsche Bank Energy Seminars – March 2008)
6352
66
Angore
Barikewa
Uramu
Pandora
Juha
P’nyang
Kimu
Iehi Elk
Hides
Flinders
PPL234
Elevala
Douglas
Phase 2 Gas Growth:Resource Overview
PNG has substantial discovered gas resourcesGas for PNG LNG Project−Hides, Juha, Angore, Kutubu,
Moran, Gobe−Presently 9.5 tcf certified 2P−Approx 3 tcf Oil Search share−about 60% of OSH’s
discovered gas resources
The Company has ~2 tcf of discovered gas outside PNG LNGPNG has a further est. 3-4 tcf of discovered gas resources spread across many fields & ownersGeographic & company ownership spreads leads to many consolidation opportunities & challenges
67
Western Forelands Hub
Western Corridor & Forelands gas hub provide opportunities for cluster developments (smaller fields) & long-distance connection of more remote resources
Kimu (0.8 tcf)− OSH @ 60.7%
Farm-in & consolidation opportunities in nearby licenses
Gas aggregation from other fields & producers − Douglas− Elevala
Western Corridor may stretch up to P’nyang
Potential for pipeline to Daru
Angore
Uramu
Pandora
Juha
P’nyang
Iehi Elk
Hides
Flinders
PPL234
Elevala
BarikewaKimu
Douglas
68
Eastern Forelands Hub
Established gas that could be material in LNG planning or domestic gas use
Could use PNG LNG infrastructure, if available
Barikewa (~800 Bcf)− OSH @ 42.6%
SE Gobe (small)− Not part of PNG LNG
at present
Opportunities with other producers − Elk (?)− Antelope (?)
Angore
Pandora
Juha
P’nyang
Hides
Flinders
PPL234
Elevala
Kimu
Douglas
Uramu
Iehi Elk
Barikewa
SE Gobe
69
Offshore Hub
Offshore fields could tie into PNG LNG pipeline, if available or have standalone facilities
Established gas at Uramu (0.4 tcf)− OSH @ 49.5%
Pandora (~1 tcf)− 3D seismic
scheduled to firm up resource size
Near Field Exploration opportunities to be tested− Flinders− PPL 234− APPL 293
Angore
Juha
P’nyang
Iehi Elk
Hides
Elevala
Barikewa
Kimu
Douglas
Flinders
PPL234
Pandora
APPL293
Uramu
70
Value of Non-Project Gas
PNG LNG 3rd Train Other LNG Non-LNG
Pro
ject
Re
turn
(%
)
Highest value from PNG LNG 3P upside scenario:− Significant field, pipeline & plant synergies obtained
Returns from Non-Project LNG fields highly variable depending on combination of assumed gas resources and infrastructure access outcomes
Subsequent LNG offers highest net-back values, however, other gas commercialisation opportunities can offer attractive returns and potentially earlier delivery (enhances NPV)
Targeted exploration & appraisal programme 2009 plus to augment existing resource base
71
Developing Domestic Industry
Smaller, non-LNG developments create interim value and diversity for PNG and Oil Search
Fundamentals are similar−Bring the reserves together
− Acquire/consolidate interests in key fields on commercial terms to align interests
− Common operator in Oil Search− Gas aggregation through gas purchases
−Prove more Reserves− Further exploration & appraisal
− Barikewa, other Eastern Corridor fields− 3D seismic and drilling – Offshore Corridor− Kimu, Elevala, Douglas, other Western Corridor fields
−Align with Government & others on infrastructure and domestic gas development needs
−Progress domestic opportunities, in parallel with high value export opportunities
72
Phase 2 Gas Growth:Resource Overview
Hides Gas To Electricity for Porgera
−Needed for Porgera mine life extension
Petrochemicals-methanol/DME
− US$300-500m NPV likely depending on gas source
Daru gas development & infrastructure
− Port and infrastructure may include gas pipeline & developments
Power generation in POM and elsewhere
− Smaller projects catering to the needs of communities & industry
73
The Next Steps
LNG will dominate value and longer term
Oil Search will develop a coordinated business plan with other key stakeholders for delivery of successive projects
− Review reserves opportunities
− Review early infrastructure investment
− Mature development options for a range of projects
Finalise investment strategy for next 4 years leading to multi “in country” developments from PNG LNG infrastructure spine
Frame Joint Venture Agreement(s) with aligned parties
74
Exploration and Organic New
Business
Keiran WulffExecutive General Manager –
Business Development
75
Summary
Portfolio optimisation across all exploration assets− Divestment of less material MENA assets as packages of
production/exploration to attract maximum interest− Focus on assets that have material potential impact on OSH
− Prudent farm down of exploration over-exposures in PNG− Likely packaged to attracted aligned partner
− Acquisition of new areas linked to regional strategy and materiality− PNG - increasing focus on gas build complemented with near facility oil
exploration & occasional “paradigm changers”− New Business - fewer but more material positions in proven petroleum
systems−Stronger “entrepreneurial trading” approach to manage costs
Single exploration budget pool allocated on basis of value and strategic impact on OSH− Centralised control − Competition for capital
76
Context
PNG LNG will command capital above exploration and new businessOSH’s last 2 years’ exploration results have been disappointing−5 small discoveries in MENA but lacking materiality for OSH size and
direction −remaining potential in some areas small while other areas highly
attractive−PNG well costs very high, drilling challenging with limited success
Despite large gas reserves already discovered, PNG has considerable remaining gas potential −OSH has identified 3 hubs plus additional frontier exploration areas
Strong international demand for assets in MENA region−OSH has a solid 1st generation portfolio built in highly competitive
environment−Some OSH assets valued more highly by regional players
OSH has strong international operational credibility & regional knowledge from which to selectively pursue material opportunities
77
Strategy - Exploration
PNG
1. Gas build− Build on existing gas portfolio for
additional major growth controlled by OSH
− 3 hubs identified along development corridor
−Central Fold belt, Eastern Forelands, Offshore Gulf of Papua)
− Seismic & studies 2008− Active drilling 2009+
2. Oil Exploration− High grade remaining prospects in close
proximity to infrastructure− Consider deeper Jurassic plays− Farm down high equity oil exploration
3. Frontier “paradigm changer”− Generally PNG exploration focused few
plays− Potential to open up new areas with
selective, albeit high risk, drilling− Large hinterland structures reliant on younger
reservoirs− Offshore fans and toe thrusts− Foreland extensional fault blocks
MENA & INTERNATIONAL
1. Existing acreage optimisation− Material opportunities adjacent to fields
e.g. Yemen Blocks 3 & 7− Pre-drill POS can be realistically >20%
through technology or quality of acreage, e.g. Yemen 3, 7. Libya Area 18, Kurdistan
2. World class petroleum systems − manageable above ground risk with very
large potential, e.g.. Kurdistan − New plays with large, albeit higher risk
upside & ability to farm down exposure e.g.. Tunisia deep gas plays
3. Actively maintain and build on core regional relationships− Key strategic advantage of OSH is ability
to operate at a local level
78
PNG Gas Growth
Strong licence position along the infrastructure corridor in each of the:
• NW Highlands Hub
• Forelands Hub
• Offshore Hub
1+TCF
0.5 - 1+TCF
0.3 - 2+TCF 0.2 -0.6+TCF
Pursue multiple play types with seismic control (typical prospect size)
79
MENA Permits 2003 – 2008Likely evolution
Sana’a Office
Dubai Office
Block 35
Block 15
2003
Concept to provide revenue through organic success to support production pre original gas project−LNG world different in materiality & capital requirements
−Mixed 1st generation exploration
−Time right for portfolio refocus
Solid portfolio of 15 licences built from scratch in ~5 years against hyper-competition−Portfolio is value accretive based on assessed value & peer comparison but
− Discoveries in Egypt and production in Yemen not material enough
− Some licenses considered immaterial for OSH going forward but require ongoing capital investment
− Some areas still have significant upside that can be evaluated & derisked
OSH is well respected in MENA as competent operator with strong local relationships
East Ras Qattara
Mesaha
Sana’a Office
Cairo Office
Dubai Office
Tajerouine
Le Kef
Area 18
Area A
Bina Bawi
2007Block 3
Block 7
Block 35Block 43
Block 49Block 74 Block 15
Sana’a Office
Dubai Office
2008Block 3
Block 7
Tajerouine
Le Kef
Area 18
Bina Bawi
Kurdistan
80
MENA - Divestment
Consideration was given to full exit versus high grading approach
Following extensive external review, decision made to proceed with high grading based on:
−Quality and potential of parts of the portfolio to deliver a material diversified revenue stream vs. PNG
−Need for growth opportunities post the delivery of PNG LNG alongside other PNG gas opportunities and PNG oil exploration
−Acknowledgement of the value of relationships developed
−Long lead times inherent in new business activities
−Preference to grow by exploration vs. large scale acquisition
81
MENA Divestment Process
Composition of divestment portfolio (still to be finalised) will likely include:− Exploration/Production - Yemen− Exploration (near field and frontier)/development/production – Egypt− Farm down frontier acreage – Tunisia− Possibly Libya
Extensive interest in portfolio since “divestment announcement”
− >40 companies expressed interest− Companies will be high-graded with 20-24 selected for data room access
Advisor appointed – Harrison Lovegrove & Associates− Invitation letters to interested companies out end March − Information Memorandum being finalised
− data rooms planned in Dubai during April to early May
− Anticipated transaction effective date: Mid 2008
Operatorship transition through Q3 2008Estimated completion date: early 4Q 2008
82
Strategy – New Business
Dedicated team identifies candidates that meet key investment criteria
Utilise strong relationships & operating credibility to acquire positions− Proven world class petroleum systems but with challenges that can be managed by OSH
expertise (i.e. operating credibility/developing country expertise/politically challenging)
− Risks need to be manageable
Develop strong entrepreneurial approach with rapid turnover of assets− A more ruthless approach to trading built on solid technical & commercial evaluations
Delineation of core areas with following attributes:− Proven petroleum system with material hydrocarbon potential
− Gas close to infrastructure or regionally strategic locations
− Manageable above ground risks
− Opportunity to de-risk technically ahead of drilling through 3D or other technology
Whole portfolio ranking of opportunities− No urgent requirement with strong 2008 – 2010 programme
− Coordinated approach to fund highest quality opportunities
83
OSH 3 Year Forecast Drilling Programme
More balanced drilling programme – less lumpyGreater lead-up time for deriskingManageable budget yet material opportunities
m j j a s o n d j f m a m j j a s o n d j f m a m j j a s o n dPNG
NW Paua
offshore
YemenBlock 3Block 7
LibyaArea 18
TunisiaTajerouineLe Kef
KurdistanBina Bawiprovisional
Man AtticBarikewa
PPL239onshore
Cobra
Wasuma Wage?
Iwa?
PPL244
3
FlindersPPL234
2
1 optional
1 2
1
2008 2009 2010
Oil Search 3 Year Forward Drilling programme forecast - Exploration
Country Area
84
Retained Exploration Portfolio Potential
US$80/bblUS$60/bbl
Key criteria in determining retained areas include:− Possibility of material discoveries with nearby analogues− Potential to substantially increase POS in immature but high
potential acreage− Untested but realistic plays− Proven petroleum systems− Able to utilise and build on OSH core operational expertise− Maintains core relationships
85
Conclusions
Reduced yet focused spend on more material opportunities
Greater focus on portfolio management & trading
− PNG & MENA
Increased internal competition for funding
− Allocation on value and strategic basis
− US$80-100m total exploration budget/yr for next 3-4 years
Increasing focus on:
− PNG gas exploration
− Material new plays in proven hydrocarbon systems
MENA divestment process targeting end 2Q 08
86
Strategy Summary
Peter Botten: Managing Director
87
Oil SearchThe Next 5 Years
The Company at a cross roads –− Potential to multiply value by delivering PNG LNG and
Other Gas Opportunities
Three distinct phases over the next 5 years− Phase I – PNG LNG to FID 2008-09
Cash conservation , positioning− Phase II – PNG LNG construction 2010-13
Cash consumption, progressive delivery− Phase III – First Gas and Beyond 2013-
The legacy asset arrives
Shifting focus of priorities over period
88
The Immediate Focus
Phase I – PNG LNG to FID 2008-2009− Support for Operator
− Oil Search Specific value delivery
− Oil operations synergies, oil fields gas FEED
− Government and landowner management
− Financing
− Reorganisation to deliver
− Positioning for further growth
− Other gas developments, lay the foundations
− Measured exploration, with active trading
− Cash conservation – Strong competition for capital
89
The Medium Term
Phase II – PNG LNG Construction 2010-2013− Massive impact on PNG− Oil Search specific value delivery
− Oil fields gas construction− Manage stakeholders/landowners− Mitigate impacts on oil business
− Further growth− Mature other gas options for 2013 delivery− Measured exploration – some value delivery− Prepare for legacy asset contribution – A New
Direction?− Major Cash Consumption
90
The Long Term
Phase III – First Gas and Beyond 2013 –− Further growth opportunities
− Debottlenecking
− New train development
− Other gas developments off new infrastructure
− Major cash generation – Legacy Asset Delivery – A New Oil Search
91
The Focus in 2008-2009
Reorganising Management and Teams for Specific Value Delivery− PNG LNG Delivery Group
− JV support
− Oil operations synergies and interface
− In-country landowner management
− PNG LNG Financing Group
− Debt and equity financing co-ordination
− Gas New Business Group
− Concentrate on new gas developments
− Corporate reorganisation to “Fit for Purpose” Group based on new priorities
92
Overall Conclusions
Latent value in existing portfolio of assets is sufficient to deliver superior value delivery to shareholders over the next 5 years− Opportunities are well defined
− Challenges can be managed
− Company is well positioned to deliver
“It is Time”
93
Questions
Peter Botten: Managing Director