101207 - petroleum overview final print · agd66, ans, sutm z54 cpd (18.5m amsl) pdl2 100...
TRANSCRIPT
1
Petroleum Overview
Philip CaldwellEGM LNG – Oil Search
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Health, Safety &Environment
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Safety FirstTR
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Oil Search
Australian Companies (APPEA)
InternationalCompanies
(OGP)
8.5
10.69.8 10.7
5.8
1.7
4.7
2.4 2.31 2.05
1.162.04
3.9 3.1 2.92.7
2.1
4.0
3.6
4.9
5.76.0
1.75
12.7
9.1 9.37.8
7.0
7.3
5.2
9.4
8.2
6.36.8
6.0
1998 1999 2000 2001 2002 2003 2004 2005 20072006 2008 2009 1H 10
1.71
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Protecting the Environment
Oil Search is committed to conducting its activities in an environmentally responsible way, in all areas
Recognising the trend toward higher environmental standards, thecompany decided in 2007 to base its environmental system on the ISO 14001 standard
Full compliance with ISO 14001 achieved in early 2009 Site Specific Environmental Management Plans have been completed for approved Camps, Oil & Gas Facilities and the Marine Terminal.2 surveillance audits have been completed with good outcomes. Several opportunities for improvement are being pursued.
The company is preparing a number of proposals for submission tothe European Carbon Emissions Reduction (CER) market in 2011
The company continues to engage with project area communities to manage potential environmental impacts.
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Flare Reduction
66
Production
7
PDL1
PPL219
PDL2
PDL5PDL6
PPL219
PDL4
PDL3
50km
Angore
Juha Hides
6°S
143°E 144°E
7°S
Oil Search Oil FieldsDevelopment Wells drilled By OSL
31 development wells, no dry holes !
Usano:6 wells
SE Gobe:4 wells
Kutubu:7 wells
Agogo:2 wells
Moran:8 wells
Gobe Main1 well
SE Mananda:3 wells
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OSL Production Performance
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
Pro
du
ctio
n R
ate
(B
op
d)
OSL Operator
Kutubu SEG Wedge,Moran
UsanoKutubuMoran
AgogoMoran
UsanoKutubuMoran
Previous Operator, 2P EUR : 449 million stbOSL 2009, 2P EUR : 546 million stb
9
What Has Worked
Methodical reassessment of zones and wells that had been shut in
Bolder steps – unperforated zones in mature fields –test legacy view on zone quality – discovered that high radioactive mineral content negatively impacted reservoir quality analysis in Gobe Iagifu
Turning around injectors to produce
Challenging the geological model in areas where data is hard to explain
search for new geological interpretations
Redevelopment of poorly performing fields and blocks
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Initial Assumptions-1000
-1000
-150
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-140
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-1400
-1400400
-1300
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00
-1100
-1100
-1000
-1600
-1600
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-1500
-1800
-1900
-1700
-1700
Hedinia 1X
Hedinia 1XST1
Hedinia 3X
Hedinia 3XST2
Hedinia 7X
IDD 1
IDD 3
IDD 4
IDT 1
IDT 11
IDT 12
IDT 13
IDT 14
IDT 15
IDT 16
IDT 17
I
IDT 19ST1
IDT 2
IDT 20
IDT 21
IDT 3
IDT 4
IDT 5
IDT 6
IDT 7
IDT 8
IDT 8ST1
IDT 9
IHT 1IHT 1A
IHT 2
IHT 3
IHT 4
IHT 5
IST 1
IST 2
IST 3A
IST 4
IST 5
IWT 1
Iagifu 4X
Iagifu 6X
Iagifu 6XST1
Iagifu 7X
UDT 1
Gas in Centre
Top
-1000
-1000
-150
0
-140
0
-1400
-1400400
-1300
-130
0
-1300
-1300
300
-1300
-1200
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00
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-1600
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-1500
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-1900
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-1700
Hedinia 1X
Hedinia 1XST1
Hedinia 3X
Hedinia 3XST2
Hedinia 7X
IDD 1
IDD 3
IDD 4
IDT 1
IDT 11
IDT 12
IDT 13
IDT 14
IDT 15
IDT 16
IDT 17
I
IDT 19ST1
IDT 2
IDT 20
IDT 21
IDT 3
IDT 4
IDT 5
IDT 6
IDT 7
IDT 8
IDT 8ST1
IDT 9
IHT 1IHT 1A
IHT 2
IHT 3
IHT 4
IHT 5
IST 1
IST 2
IST 3A
IST 4
IST 5
IWT 1
Iagifu 4X
Iagifu 6X
Iagifu 6XST1
Iagifu 7X
UDT 1
Gas in Centre
Top
-180-19
-1600
-1100
-1100
-1400
-1400
-1400
-1400
-1400
-1400
-1300
-1300
-1300
-1300
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-1300
-1200
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-1500
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-1000
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-800
-110
0
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-1700
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-1600
-1600
-1900
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-1800
Hedinia 1X
Hedinia 1XST1
Hedinia 3X
Hedinia 3XST2
Hedinia 7X
IDD 1
IDD 3
IDD 4
IDT 1
IDT 11
IDT 12
IDT 13
IDT 14
IDT 15
IDT 16
IDT 17
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IDT 19ST1
IDT 2
IDT 20
IDT 21
IDT 3
IDT 4
IDT 5
IDT 6
IDT 7
IDT 8
IDT 8ST1
IDT 9
IHT 1IHT 1A
IHT 2
IHT 3
IHT 4
IHT 5
IST 1
IST 2
IST 3A
IST 4
IST 5
IWT 1
Iagifu 4X
Iagifu 6X
Iagifu 6XST1
Iagifu 7X
UDT 1
Water in Centre
Base
-180-19
-1600
-1100
-1100
-1400
-1400
-1400
-1400
-1400
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-1800
Hedinia 1X
Hedinia 1XST1
Hedinia 3X
Hedinia 3XST2
Hedinia 7X
IDD 1
IDD 3
IDD 4
IDT 1
IDT 11
IDT 12
IDT 13
IDT 14
IDT 15
IDT 16
IDT 17
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IDT 19ST1
IDT 2
IDT 20
IDT 21
IDT 3
IDT 4
IDT 5
IDT 6
IDT 7
IDT 8
IDT 8ST1
IDT 9
IHT 1IHT 1A
IHT 2
IHT 3
IHT 4
IHT 5
IST 1
IST 2
IST 3A
IST 4
IST 5
IWT 1
Iagifu 4X
Iagifu 6X
Iagifu 6XST1
Iagifu 7X
UDT 1
Water in Centre
Base
Static Oil
Moving WaterStatic Oil
Moving Water
Strong aquiferTilted contact
Conceptual map
First years of production - dynamic aquifer model preferredDynamic aquifers have been seen elsewhereNot an unreasonable interpretation for Kutubu at that time, based on available data
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Challenging the model
Highest producing well on structure hadn’t seen gas in a gas drive system – difficult to explainThere was no water production in centre of field near where dynamic aquifer might beOther fields were demonstrating compartmentalisation – Gobe Main, SE GobeNew mapping and seismic interpretation was identifying more faulting across the fieldSimulation suggested oil in the centre of the fieldNew model emerging - untapped pool of oil in centre of field, probably compartmentalised
Drill some wells………
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-1100
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-1300
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-1400
-1400-1400
-900
-900
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-800
-700
-700
-1500
-1100
-1100
-1700
-1600
-1500
Hedinia 1X
Hedinia 1XST1
Hedinia 3X
Hedinia 3XST2
Hedinia 7X
IDD 1
IDD 3
IDD 4
IDT 1
IDT 11
IDT 12
IDT 13
IDT 14
IDT 15
IDT 16
IDT 17 IDT 19ST1
IDT 2
IDT 20
IDT 21
IDT 3
IDT 4
IDT 5
IDT 6
IDT 7IDT 7ST1
IDT 8
IDT 8ST1
IDT 9
IDT 9ST2
IHT 1IHT 1A
IHT 2
IHT 3
IHT 4
IHT 5
IST 1
IST 2
IST 3A
IST 4
IST 5
IWT 1
Iagifu 4X
Iagifu 6X
Iagifu 6XST1
Iagifu 7X
UDT
IDT 23IDT 23
IDT 22IDT 22IDT 4ST1IDT 4ST1
Oil in Centre
IDT 23ST2IDT 23ST2
Toro C Structure
Existing Well - Toro C PenetrationExisting Well - Toro C Penetration
NN
New Well (Oil) - Toro C PenetrationNew Well (Gas) - Toro C Penetration
Proving the new model
Drilled IDT 4ST1, IDT 22, IDT23 and IDT 23ST2New model proved correct –untapped oil pool in separate compartmentsOne well found gas – IDT23 – but subsequently sidetracked to oil filled compartmentDynamic aquifer model looking increasingly unlikely
Compartmentalised System
OWCOWC
OWC
Compartmentalised System
OWCOWC
OWC
Compartmentalised
IDT 24
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Usano Redevelopment
Pre-OSL Usano had a poor production historyLow recovery factor (12% in main block)History of collapsed casingHistory of fractures and early gas breakthroughStructurally complex overburden
Production well, offline
Production well, online
Gas injection well, online
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-1600
-1600
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-1600
-1800
-2000
-1400
-2200
-1200
-1600
-1600
-1800
Hedinia 2X
UDT 3AST1
UDT 3A
UDT 12
Arakubi 1A ST1
UDT 2
UHT 1
UDT 1
Arakubi 1A
UDT 4A
UDT 8
UDT 10
UDT 9
UDT 6
UDT 7 ST1
UDT 7
UDT 11
746000 746500 747000 747500 748000 748500 749000 749500 750000 750500 751000 751500 752000 752500 753000
746000 746500 747000 747500 748000 748500 749000 749500 750000 750500 751000 751500 752000 752500 753000
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0 250 500 750 1000 1250m
Country
Datum/Projection
Elev. ref.
License
Contour inc
Date
PNG
AGD66, ANS, SUTM Z54
CPD (18.5m amsl)
PDL2
100
22/10/2009
Toro A Structure - Original Contacts
OSL Development Well
Injection
Overcoming uncertainty
Full field remap and simulationDevelopment strategy encompassed 6 additional production wells, and conversion of one well to injection5 wells are horizontal using intelligent completions to optimisestand-off from contacts and reduce structural uncertaintyHigher grade casing with liner lap extending over high risk interval
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Usano: a rejuvenated field
0
2,000
4,000
6,000
8,000
10,000
12,000
1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009
Oil
Rate
(b
op
d)
Usano Main BlockUsano East Block
UDT 7
UDT 8, 9
UDT 10,12
UDT 11
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Maximising Remaining Oil
Many Subsurface Opportunities Still ExistNew Sub-Thrust Pools (Agogo / Kutubu?)Workovers of existing wells – new zonesBlock extensions (Moran)Secondary Targets (Kutubu)
Available target pool sizes for new wells are reducing: ~ 1mmstbTarget objectives have increasing riskCommercial thresholds are increasingly dependent on costs andoil priceFurther improvement in drilling performance will assist
As pool size decreases for wells and workovers, there is an increasing need for simulation with higher resolution
Thin layers separated by hard streaks are controlling how gas and water move through the reservoir
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Facilities Optimisation
CPF to GPF crude oil transferBy transferring oil from CPF to GPF storage prior to a ship arriving, existing storage is maximisedReduced risk of tank tops and associated well shut-ins, maximise productionFewer well issues related to shut-in and start upReduced demurrage due to higher pumping rates
APF OptimisationSecond lower pressure flowline, reduces slugging, maximises production from low GOR, lower pressure wellsDebottlenecking Moran HP compressionIncrease peak injection rates and maximise injection to optimise voidage and provide flexibility to inject gas on block by block basisAPF optimisation (dehydration, CO2, inlet de-bottlenecking).Exploring options to reduce SEM flowing pressure to enhance production and reserves
Gobe & Kutubu OptimisationUpgraded LP and HP compressor capacityDebottlenecked gas injection lines
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Integrity, Life Extension &
Preparing For Gas
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Integrity & Life Extension
Introduction of Process Safety / Well Integrity ProgrammesManage corrosion and pressure integrityImprove integrity monitoring, test and inspection programmesAdditional Non-destructive testing of pipeworkHigh Profile reporting requirements
Corrosion & SRB ManagementInstall new pigging facilities and run intelligent pigs on export lines to KumulplatformReplace corroded water injection lines at CPFNew line provides for pigging and improved SRB controlImproved SRB monitoring and treatment has reduced SRB corrosion risk
Closer Monitoring Of Maintenance Effort / Downtime / Production Loss
Facilities & Support Infrastructure going beyond initial design lifeOngoing management of obsolete equipment Support infrastructure, camps, industrial park, warehouses overhauled
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Associated Gas Scope
Associated Gas DeliveryEnhanced dehydration by replacing existing gas driers to improve gas quality and reduce emissionsEnhanced gas cooling for spec commissioning gas to LNG PlantAG Gas Management System by automating various wells for remote operation and upgrading plant inlet gas management systemNew and upgraded metering to manage gas reserves
Condensate StorageAdd value to the LNG Project by the Receipt, storage and export condensate from LNG Project HGCP with high reliabilityUpgrading of pipework to allow inline mixing, loss prevention (particularly fire management) and control systems
Commissioning GasInstallation of skids to allow early commissioning gas for the LNG Plant
UtilitiesImprovements to ESD system and new control roomTie ins for new equipment into existing and improved utilities
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AGRP Changes to the - CPF
22
PL2 Life Extension Scope
Objective is to provide a highly reliable export route for oil and gas condensate liquids for the next 30 years
Installation of a new CALM buoy, tanker loading line and PLEM ata new location 7.7km south of the platform in a water depth of 35m
Allows uninterrupted tanker loading whilst the new facilities are installed
Major life extension work on Kumul platformReplacement of most of the major equipmentRepair / replacement of piping and some structural steel
Inspection, engineering assessment and maintenance to existing export line from CPF to Kumul
Primarily for fatigue life management
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A View of The Future
PNG LNG transforms production profile, adding ~18 mmboe pa to OSH at plateau in 2015 onwards. 30 year Project life
T3 could add an additional ~9 mmboe pa, with T4 of similar magnitude
Net
Pro
du
ctio
n (
bo
ep
d)
0
10,000
20,000
30,000
40,000
50,000
60,000
2010 2012 2014 2016 2018 2020 20262022 20282024 2030
LNG GasLNG Gas
PNG DevelopmentPNG Development
70,000
80,000
Potential T3 LNG GasPotential T3 LNG Gas
LNG CondensateLNG Condensate
90,000
Potential T3 LNG CondensatePotential T3 LNG Condensate
2424
Questions
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Disclaimer
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.