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1
February 2008
O I L S E A R C H L I M I T E D
2007 Full Year Results
A new dawn for Oil Search
2
2007 Full Year Results Agenda
2007 Performance Summary Peter Botten
Financial Overview Nigel Hartley
Strategy Review Update Peter Botten
PNG LNG Project Update Peter Botten
Operations Review Phil Bainbridge
Outlook Peter Botten
3
2007 Performance Summary
4
2007 Performance Metrics
Record revenue of US$718.8 million, +12% on 2006
Slightly lower production (-4%) more than offset by 16% increase in oil price
Record EBITDAX of US$598.2 million, +10% on 2006
Costs affected by industry pressures and exchange rates
Net profit after tax (before significant items) of US$140.8 million, -32% on 2006
First NPAT fall in 5 years
Impacted by higher exploration expense, higher non-cash items and higher effective tax rate
Oil Search Board has declared a final dividend for 2007 of four US cents/share, making eight US cents/share for the year, the same as in 2006
5
Safety performancecontinues to improve
Total Recordable Incidents (TRIs) 1998 – 2007
TR
I /
1,0
00
,00
0 H
ou
rs
1998 1999 2000 2001 2002 2003 2004 20050
2
4
6
8
10
12
14
2007
APPEAOSH OGP
Oil Search
Australian Companies
8.5
10.6 9.8 10.7
5.8
1.7
4.7
2.4 2.312.05
12.7
9.1 9.37.8
7 7.3
5.2
6.8
4.0 3.052.92
9.4
8.2
8.3
2006
International Companies
6
Indexed Share Price Performance
1.58
5.08
OSH
STO
WPL
ASX200Energy
WTI
2.08
2.58
3.08
3.58
4.08
4.58
Jan-05 Jul-05 Jan-06 Jul-06 Jan-07 Jul-07 Jan-08
Sh
are
pri
ce (
reb
ase
d t
o O
SH
)
7
ASX 200 Peer Ranking
232% 66 86% 67 10% 96 AWE
136% 96 77% 76 (2%)136 ROC
164% 87 80% 71 47% 30 Santos
340% 48 166% 46 36% 42 Woodside
736% 26 184% 41 48% 29 Oil Search
TSRRankTSRRankTSRRank
5 yearsto 31 Dec 07
3 yearsto 31 Dec 07
1 yearto 31 Dec 07
Source: IRESS
8
Financial Overview
9
2007 Full Year Performance
Oil Sales (mmbbl)Realised oil price (US$/bbl)(US$’m)RevenueCash ExpensesEBITDAXExploration ExpenseNPAT
2006
8.7177.78
718.8(121.3)
598.2(163.3)140.8*
2007
10%
9.1867.18
644.5(103.8)
544.8(46.8)207.5*
* In 2006, excludes profit of US$258.4 million on sale of licence interests to AGL and net impairment losses of US$53.9 million. In 2007, excludes net impairment losses of US$3.6 million
Cash operating earnings before exploration expense and tax 10% higher, driven by stronger oil prices
Exploration expense up US$116.5 million on 2006, reflecting significant increase in exploration programme
32%
12%
10
2007 Core Profit Drivers
Cash opex impacted by global industry cost pressures and resurgent Australian dollar, fuel costsUS$65.2 million (40%) of total 2007 exploration expense incurredin MENA with no associated tax benefit. Primary driver of effective tax rate of 56%
0
100
200
300
2006
Amor
tisat
ion
US$m
2727
(117)(117)
(33)(33)
(11)(11)
1414
141141
(37)(37)
9797
207207
Oil Pric
eOil
Sale
sOth
er R
ev.
Cash
Opex
pr
e FX
Expl
. Exp
.
Tax
2007
(7)(7)
FX I
mpa
ct
11
Cash Earnings Growth
Revenue OperatingCash Flow
CoreNet Profit
US$m
350.8
416.3
664 644.5
718.6
239.1
330
554.3 544.8598.2
191.3
276.7
357.7
399
326.8
85.7
107.3
200.2 207.5
140.8
0
100
200
300
400
500
600
700
800
2003 2004 2005 2006 2007
EBITDAX
12
Treasury Review
US$344 million in cash at year end, no debtCurrent cash position of ~US$410 million, following receipt of proceeds from cargoes lifted in DecemberUS$100 million tranche of corporate facility expired at year-end. Remaining undrawn bank lines of US$42 millionIntention to refinance corporate facility in 1H08, increasing funding commitment to ~US$400 million and group liquidity to in excess of US$700 millionScoping study of financing options for the PNG LNG Project identified large potential pools of funding capacity across bank, debt capital market and export credit agency productsNo oil hedging currently in place
13
2008 Capital Outlook
US$’m 2007Actual
2008*Outlook
*Subject to amendment following completion of strategic review
**2007 final dividend only
Investing :ExplorationGas (incl. PNG LNG)Development/ProductionCorporate (inc rigs)
Financing :Dividends
202209576
90
14075
16020
45**
14
Other 2008 Drivers
2008 effective tax rate dependent on MENA exploration success
Further upward pressure on capital costs and increased development capital expenditure will translate into higher amortisation/site restoration rates (~10% increase on 2007 rates)
2008 operating cashflow likely to include US$20 million final payment for 2006 tax year (no P&L impact)
15
Strategic Review Update
16
Strategic Review Update
2002/2003 Strategic Review laid foundations for major Company growth. Work helped deliver top quartile returns over 2003 – 20072007 Strategic Review, designed to define corporate objectives for next five years, nearing completion Strategy discussion with market scheduled for mid March. Initial findings:
PNG LNG will be a key NPV driver. Focus is to ensure timely development and maximise value of discovered gas resources, oil fields and infrastructure to ensure maximum value potential is achieved PNG oil fields – review has identified and quantified significant opportunities within existing fields. Focus on implementation of initiatives and optimising performanceOptimisation of PNG and MENA licence portfolios. Focus on assets that have potential to add materially to OSH as value of gas portfolio increases. Need for portfolio managementEnsure OSH has right expertise and cost base to deliver
17
PNG LNG Project Update
18
Existing gas fields, gas
exploration and appraisal opportunities
Barikewa
Uramu
Pandora
Juha
Iehi
Hides
Moran
Kutubu
Gobe
Flinders
Kimu
Angore
19
PNG LNG – ExxonMobil Operated
Kopi
Kutubu & Agogo
Gobe
Hides & Angore
Juha
Port Moresby
75km
Hides-Kopi pipeline
250 mmscfd (nominal)
960 mmscfd Conditioning Plant
66 km 14-inch gas line
8-inch condensate line
~400km subsea gas line to LNG Plant at
Konebada, Port Moresby
LNG Facility - 6.3MTA Capacity
20
Oil Field Gas Facilities for LNG
Port Moresby
Gobe Main
Moran
20km
Kutubu
Agogo
SE Gobe
LNG Project Gas Pipeline
Existing Oil Pipelines
GOBE GAS PRODUCTION
KUTUBU GAS PRODUCTION
AGOGO/MORAN GAS PRODUCTION
Gas Dehydration
Gas Dehydration
Gas Dehydration
21
PNG LNG Project Update
Significant progress through 2007 on the ExxonMobil-led 6.3 mmtpa PNG LNG project
FEED Entry – status report:Pre-FEED technical studies completed. Current preference is 6.3 mmtpa LNG plant, located near Port Moresby. Both ConocoPhillips Optimized Cascade and APCI C3/MR processes likely to be considered during FEED
Bottom-up rebuild of expected capital costs and peer review process nearing completion
Coordinated Development and Operating Agreement (CDOA), covering gas supply arrangements, unitisation principles and voting, in final documentation stage
22
PNG LNG Project Update
FEED Entry – status report continued: Marketing Representation Agreement signed. Owners will market LNG jointly for the initial 6.3 mmtpa development, with Operator, ExxonMobil, as marketing representative. Marketing to officially commence post FEED decision
Licence renewal terms under discussion, and expected to be resolved for FEED entry
Progress on Fiscal Agreement slower than expected but still targeting to make FEED decision by end 1Q08
Total commitment and alignment by Project partners (with ExxonMobil as operator) and the PNG Government to close remaining issues
23
PNG LNG Project Update
Objectives during FEED:2008
Execute downstream (LNG plant) FEED contractInitiate and progress marketingIssue Information Memorandum to banks, lenders
2009Complete Upstream/Downstream FEED activitiesCommit to long lead time items and early infrastructureSecure Sales & Purchase AgreementsComplete financing plan
Final Investment Decision expected in 2H09First LNG sales late 2013/early 2014
24
Operations Review
25
2007 Performance
Safety:Excellent year in PNG and Egypt
Production:9.78mmboe, within revised forecast range
PNG Costs:Field costs per barrel increased from US$5.87/bbl to US$6.96/bbldue to ongoing industry cost pressures and exchange rate movements over lower production base
PNG Drilling:
Transition continues with two new rigs commissioned and operating
Reserves and resources2P reserves down 10% to 73.5 mmboe, reflecting 2007 production offset by minor reserves additions in PNG and MENA. 2P resources (gas and assoc liquids) largely unchanged with audit to take place in mid-2008. Total 2P reserves & resources of 1,025.5mmboe
26
2007 Performance
Exploration:Disappointing year in both PNG and MENA:
PNG:Juha 5 confirmed gas water contact. Juha 4 discovered new field area, Juha North. 2P volumes remain unchanged but did not realise anticipated upsideKutubu 2x, Korobosea and Arakubi unsuccessful. Arakubi is a potential water injector well with possible oil in deeper reservoirs to be tested
MENA: Discoveries in East Ras Qattara. Shahd and Ghardbrought onstream end 2007, testing reservoir potential, Rana waiting for Govt approvalsExploration unsuccessful in Area A and Yemen (Blocks 15, 49 and 35)
27
2008 Look Forward
Production outlook for 2008 of 9.0 – 9.5 mmboe
PNG production subject to results of:
Drilling campaign at Usano (5 wells) and Moran (3 wells), workover campaign (5 in Kutubu and 1 in Moran)
Field uptime availability and ongoing reservoir management
MENA focus remains on Area A, Nabrajah and ERQ
Increased focus on costs and capital efficiency
28
2008 Look Forward
Exploration PNG:
Material wells NW Paua (PPL 233) and Cobra (PPL 190) currently drilling
Potential for Wasuma (PPL 219) in 2008 or possibly early 2009
MENA:
Shahd SE, re-drill of Salma in ERQ (timing to be determined), 3D seismic and then potential further exploration or appraisal
3D seismic in Yemen Block 3 (current)
Caliph well in Libya (3Q08)
Portfolio optimisation expected. Valuable assets but changing materiality will drive new focus
29
Outlook
30
Outlook
Production outlook for 2008 of 9.0 – 9.5 mmboe
Exploration spend 35–40% lower than in 2007 at US$130 – 140 million, development spend of US$180 million and U$75 million on gas inc LNG FEED. Funded from cash flows and existing cash position
FEED decision on PNG LNG expected soon. Post FEED objectives for 2008 include marketing activities, execution of FEED contract
Detailed review of outcome of 2007 Strategic Review planned for mid March
31
Summary
PNG LNG Project and commercialising remaining gas will drive Company value. Rising NPV over time, as cash flows get closer and project de-risks
Core PNG oil business remains robust, with stable production and cost outlook, provides cash flows to support LNG and other development options
Exploration activities wound back from 2007 high levels, but material prospects still to be drilled in both PNG and MENA
Strategic focus on organic and acquisition growth options, to provide diversification and build production pre and post gas
32
O I L S E A R C H L I M I T E D